In situ recovery from a hydrocarbon containing formation using barriers

• US 20030192691A1
• Filed: 10/24/2002
• Published: 10/16/2003
• Est. Priority Date: 10/24/2001
• Status: Active Grant

• Current Assignee: Shell Oil Company (Shell Plc)
• Original Assignee: Shell Oil Company (Shell Plc)
• Inventors: McKinzie,, Billy J. II, Vinegar, Harold J., Wellington, Scott Lee, Stegemeier, George Leo, Watkins, Ronnie Wade, Maher, Kevin Albert, Ward, John Michael, Palfreyman, Bruce Donald, Aymond, Dannie Antoine Jr.
• Granted Patent: US 7,077,198 B2
• Time in Patent Office: Days
• US Class Current: 166/250.12
• CPC Class Codes: B09C 1/02 Extraction using liquids, e.g. washing, leaching , flotation
• CPC Class Codes: B09C 1/06 thermally
• CPC Class Codes: B09C 2101/00 In situ
• CPC Class Codes: C10G 45/00 Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
• CPC Class Codes: C10G 9/24 by heating with electrical means
• CPC Class Codes: E21B 17/0285 characterised by electrically insulating elements
• CPC Class Codes: E21B 43/168 Injecting a gaseous medium
• CPC Class Codes: E21B 43/24 using heat, e.g. steam injection
• CPC Class Codes: E21B 43/2401 by means of electricity
• CPC Class Codes: E21B 43/243 Combustion in situ
• CPC Class Codes: E21B 43/305 comprising at least one inclined or horizontal well
• CPC Class Codes: E21B 47/0224 using seismic or acoustic means
• CPC Class Codes: G01V 3/26 operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device with electromagnetic waves G01V3/30
• CPC Class Codes: Y02P 30/00 Technologies relating to oil refining and petrochemical industry
• CPC Class Codes: Y02P 30/40 Ethylene production
• CPC Class Codes: Y10S 210/901 Specified land fill feature, e.g. prevention of ground water fouling
• CPC Class Codes: Y10T 137/0391 Affecting flow by the addition of material or energy

Abstract

A method is described for inhibiting migration of fluids into and/or out of a treatment area undergoing an in situ conversion process. Barriers in the formation proximate a treatment area may be used to inhibit migration of fluids. Inhibition of migration of fluids may occur before, during, and/or after an in situ treatment process. For example, migration of fluids may be inhibited while heat is provided from heaters to at least a portion of the treatment area. Barriers may include naturally occurring portions (e.g., overburden, and/or underburden) and/or installed portions.

Claims

1. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected section of the formation is less than about 375°

C.; and

producing a mixture from the formation.

2. The method of claim 1, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

3. The method of claim 1, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

4. The method of claim 1, wherein the one or more heaters comprise electrical heaters.

5. The method of claim 1, wherein the one or more heaters comprise surface burners.

6. The method of claim 1, wherein the one or more heaters comprise flameless distributed combustors.

7. The method of claim 1, wherein the one or more heaters comprise natural distributed combustors.

8. The method of claim 1, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

9. The method of claim 1, further comprising controlling a pressure within at least a majority of the selected section of the formation with a valve coupled to at least one of the one or more heaters.

10. The method of claim 1, further comprising controlling a pressure within at least a majority of the selected section of the formation with a valve coupled to a production well located in the formation.

11. The method of claim 1, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

12. The method of claim 1, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity(C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

13. The method of claim 1, wherein allowing the heat to transfer from the one or more heaters to the selected section comprises transferring heat substantially by conduction.

14. The method of claim 1, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

15. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

16. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

17. The method of claim 1, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

18. The method of claim 1, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

19. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

20. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

21. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

22. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

23. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

24. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

25. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

26. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

27. The method of claim 1, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, and wherein the hydrogen is greater than about 10% by volume of the non-condensable component and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

28. The method of claim 1, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

29. The method of claim 1, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

30. The method of claim 1, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

31. The method of claim 1, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H₂ within the mixture greater than about 0.5 bars.

32. The method of claim 31, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

33. The method of claim 1, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

34. The method of claim 1, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

35. The method of claim 1, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

36. The method of claim 1, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

37. The method of claim 1, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

38. The method of claim 1, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

39. The method of claim 1, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

40. The method of claim 1, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

41. The method of claim 40, wherein at least about 20 heaters are disposed in the formation for each production well.

42. The method of claim 1, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

43. The method of claim 1, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

44. The method of claim 1, further comprising separating the produced mixture into a gas stream and a liquid stream.

45. The method of claim 1, further comprising separating the produced mixture into a gas stream and a liquid stream and separating the liquid stream into an aqueous stream and a non-aqueous stream.

46. The method of claim 1, wherein the produced mixture comprises H₂S, the method further comprising separating a portion of the H₂S from non-condensable hydrocarbons.

47. The method of claim 1, wherein the produced mixture comprises CO₂, the method further comprising separating a portion of the CO₂ from non-condensable hydrocarbons.

48. The method of claim 1, wherein the mixture is produced from a production well, wherein the heating is controlled such that the mixture can be produced from the formation as a vapor.

49. The method of claim 1, wherein the mixture is produced from a production well, the method further comprising heating a wellbore of the production well to inhibit condensation of the mixture within the wellbore.

50. The method of claim 1, wherein the mixture is produced from a production well, wherein a wellbore of the production well comprises a heater element configured to heat the formation adjacent to the wellbore, and further comprising heating the formation with the heater element to produce the mixture, wherein the mixture comprises a large non-condensable hydrocarbon gas component and H₂.

51. The method of claim 1, wherein the minimum pyrolysis temperature is about 270°

C.

52. The method of claim 1, further comprising maintaining the pressure within the formation above about 2.0 bars absolute to inhibit production of fluids having carbon numbers above 25.

53. The method of claim 1, further comprising controlling pressure within the formation in a range from about atmospheric pressure to about 100 bar, as measured at a wellhead of a production well, to control an amount of condensable hydrocarbons within the produced mixture, wherein the pressure is reduced to increase production of condensable hydrocarbons, and wherein the pressure is increased to increase production of non-condensable hydrocarbons.

54. The method of claim 1, further comprising controlling pressure within the formation in a range from about atmospheric pressure to about 100 bar, as measured at a wellhead of a production well, to control an API gravity of condensable hydrocarbons within the produced mixture, wherein the pressure is reduced to decrease the API gravity, and wherein the pressure is increased to reduce the API gravity.

55. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least the portion to a selected section of the formation substantially by conduction of heat;

pyrolyzing at least some hydrocarbons within the selected section of the formation; and

producing a mixture from the formation.

56. The method of claim 55, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

57. The method of claim 55, wherein the one or more heaters comprise electrical heaters.

58. The method of claim 55, wherein the one or more heaters comprise surface burners.

59. The method of claim 55, wherein the one or more heaters comprise flameless distributed combustors.

60. The method of claim 55, wherein the one or more heaters comprise natural distributed combustors.

61. The method of claim 55, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

62. The method of claim 55, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1.0°

C. per day during pyrolysis.

63. The method of claim 55, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

64. The method of claim 55, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

65. The method of claim 55, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

66. The method of claim 55, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

67. The method of claim 55, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

68. The method of claim 55, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

69. The method of claim 55, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

70. The method of claim 55, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

71. The method of claim 55, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

72. The method of claim 55, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

73. The method of claim 55, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

74. The method of claim 55, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

75. The method of claim 55, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

76. The method of claim 55, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

77. The method of claim 55, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

78. The method of claim 55, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

79. The method of claim 55, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

80. The method of claim 55, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

81. The method of claim 80, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

82. The method of claim 55, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

83. The method of claim 55, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

84. The method of claim 55, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

85. The method of claim 55, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

86. The method of claim 55, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

87. The method of claim 55, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

88. The method of claim 55, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

89. The method of claim 55, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

90. The method of claim 89, wherein at least about 20 heaters are disposed in the formation for each production well.

91. The method of claim 55, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

92. The method of claim 55, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

93. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

94. The method of claim 93, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

95. The method of claim 93, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

96. The method of claim 93, wherein the one or more heaters comprise electrical heaters.

97. The method of claim 93, wherein the one or more heaters comprise surface burners.

98. The method of claim 93, wherein the one or more heaters comprise flameless distributed combustors.

99. The method of claim 93, wherein the one or more heaters comprise natural distributed combustors.

100. The method of claim 93, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

101. The method of claim 93, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

102. The method of claim 93, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

103. The method of claim 93, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

104. The method of claim 93, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

105. The method of claim 93, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

106. The method of claim 93, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

107. The method of claim 93, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

108. The method of claim 93, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

109. The method of claim 93, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

110. The method of claim 93, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

111. The method of claim 93, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

112. The method of claim 93, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

113. The method of claim 93, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

114. The method of claim 93, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

115. The method of claim 93, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

116. The method of claim 93, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

117. The method of claim 93, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

118. The method of claim 93, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

119. The method of claim 93, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

120. The method of claim 119, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

121. The method of claim 93, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

122. The method of claim 93, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

123. The method of claim 93, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

124. The method of claim 93, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

125. The method of claim 93, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

126. The method of claim 93, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

127. The method of claim 93, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

128. The method of claim 93, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

129. The method of claim 128, wherein at least about 20 heaters are disposed in the formation for each production well.

130. The method of claim 93, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

131. The method of claim 93, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

132. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected section of the formation is less than about 370°

C. such that production of a substantial amount of hydrocarbons having carbon numbers greater than 25 is inhibited;

controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least 2.0 bars; and

producing a mixture from the formation, wherein about 0.1% by weight of the produced mixture to about 15% by weight of the produced mixture are olefins, and wherein an average carbon number of the produced mixture ranges from 1-25.

133. The method of claim 132, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

134. The method of claim 132, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

135. The method of claim 132, wherein the one or more heaters comprise electrical heaters.

136. The method of claim 132, wherein the one or more heaters comprise surface burners.

137. The method of claim 132, wherein the one or more heaters comprise flameless distributed combustors.

138. The method of claim 132, wherein the one or more heaters comprise natural distributed combustors.

139. The method of claim 132, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

140. The method of claim 132, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

141. The method of claim 132, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

142. The method of claim 132, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

143. The method of claim 132, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

144. The method of claim 132, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

145. The method of claim 132, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

146. The method of claim 132, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

147. The method of claim 132, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

148. The method of claim 132, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

149. The method of claim 132, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

150. The method of claim 132, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

151. The method of claim 132, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

152. The method of claim 132, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

153. The method of claim 132, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

154. The method of claim 132, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

155. The method of claim 132, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

156. The method of claim 132, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

157. The method of claim 132, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

158. The method of claim 157, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

159. The method of claim 132, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

160. The method of claim 132, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

161. The method of claim 132, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

162. The method of claim 132, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

163. The method of claim 132, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

164. The method of claim 132, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

165. The method of claim 132, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

166. The method of claim 165, wherein at least about 20 heaters are disposed in the formation for each production well.

167. The method of claim 132, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

168. The method of claim 132, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

169. The method of claim 132, further comprising separating the produced mixture into a gas stream and a liquid stream.

170. The method of claim 132, further comprising separating the produced mixture into a gas stream and a liquid stream and separating the liquid stream into an aqueous stream and a non-aqueous stream.

171. The method of claim 132, wherein the produced mixture comprises H₂S, the method further comprising separating a portion of the H₂S from non-condensable hydrocarbons.

172. The method of claim 132, wherein the produced mixture comprises CO₂, the method further comprising separating a portion of the CO₂ from non-condensable hydrocarbons.

173. The method of claim 132, wherein the mixture is produced from a production well, wherein the heating is controlled such that the mixture can be produced from the formation as a vapor.

174. The method of claim 132, wherein the mixture is produced from a production well, the method further comprising heating a wellbore of the production well to inhibit condensation of the mixture within the wellbore.

175. The method of claim 132, wherein the mixture is produced from a production well, wherein a wellbore of the production well comprises a heater element configured to heat the formation adjacent to the wellbore, and further comprising heating the formation with the heater element to produce the mixture, wherein the produced mixture comprise a large non-condensable hydrocarbon gas component and H₂.

176. The method of claim 132, wherein the minimum pyrolysis temperature is about 270°

C.

177. The method of claim 132, further comprising maintaining the pressure within the formation above about 2.0 bars absolute to inhibit production of fluids having carbon numbers above 25.

178. The method of claim 132, further comprising controlling pressure within the formation in a range from about atmospheric pressure to about 100 bars absolute, as measured at a wellhead of a production well, to control an amount of condensable fluids within the produced mixture, wherein the pressure is reduced to increase production of condensable fluids, and wherein the pressure is increased to increase production of non-condensable fluids.

179. The method of claim 132, further comprising controlling pressure within the formation in a range from about atmospheric pressure to about 100 bars absolute, as measured at a wellhead of a production well, to control an API gravity of condensable fluids within the produced mixture, wherein the pressure is reduced to decrease the API gravity, and wherein the pressure is increased to reduce the API gravity.

180. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute; and

producing a mixture from the formation.

181. The method of claim 180, wherein controlling the pressure comprises controlling the pressure with a valve coupled to at least one of the one or more heaters.

182. The method of claim 180, wherein controlling the pressure comprises controlling the pressure with a valve coupled to a production well located in the formation.

183. The method of claim 180, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

184. The method of claim 180, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

185. The method of claim 180, wherein the one or more heaters comprise electrical heaters.

186. The method of claim 180, wherein the one or more heaters comprise surface burners.

187. The method of claim 180, wherein the one or more heaters comprise flameless distributed combustors.

188. The method of claim 180, wherein the one or more heaters comprise natural distributed combustors.

189. The method of claim 180, further comprising controlling a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

190. The method of claim 180, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

191. The method of claim 180, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

192. The method of claim 180, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

193. The method of claim 180, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

194. The method of claim 180, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

195. The method of claim 180, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefms.

196. The method of claim 180, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

197. The method of claim 180, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

198. The method of claim 180, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

199. The method of claim 180, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

200. The method of claim 180, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

201. The method of claim 180, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

202. The method of claim 180, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

203. The method of claim 180, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

204. The method of claim 180, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

205. The method of claim 180, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

206. The method of claim 180, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

207. The method of claim 180, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

208. The method of claim 180, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

209. The method of claim 208, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

210. The method of claim 180, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

211. The method of claim 180, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

212. The method of claim 180, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

213. The method of claim 180, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

214. The method of claim 180, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

215. The method of claim 180, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

216. The method of claim 180, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

217. The method of claim 180, wherein producing the mixture from the formation comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

218. The method of claim 217, wherein at least about 20 heaters are disposed in the formation for each production well.

219. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected section of the formation is less than about 375°

C.; and

producing a mixture from the formation.

220. The method of claim 219, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

221. The method of claim 219, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

222. The method of claim 219, wherein the one or more heaters comprise electrical heaters.

223. The method of claim 219, wherein the one or more heaters comprise surface burners.

224. The method of claim 219, wherein the one or more heaters comprise flameless distributed combustors.

225. The method of claim 219, wherein the one or more heaters comprise natural distributed combustors.

226. The method of claim 219, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

227. The method of claim 219, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

228. The method of claim 219, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

229. The method of claim 219, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

230. The method of claim 219, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

231. The method of claim 219, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

232. The method of claim 219, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

233. The method of claim 219, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

234. The method of claim 219, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

235. The method of claim 219, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

236. The method of claim 219, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

237. The method of claim 219, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

238. The method of claim 219, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

239. The method of claim 219, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

240. The method of claim 219, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

241. The method of claim 219, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

242. The method of claim 219, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

243. The method of claim 219, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

244. The method of claim 219, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

245. The method of claim 219, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

246. The method of claim 219, wherein controlling the heat further comprises controlling the heat such that coke production is inhibited.

247. The method of claim 219, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

248. The method of claim 247, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

249. The method of claim 219, further comprising altering the pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

250. The method of claim 219, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

251. The method of claim 219, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

252. The method of claim 219, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

253. The method of claim 219, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

254. The method of claim 219, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

255. The method of claim 219, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

256. The method of claim 219, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

257. The method of claim 219, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

258. The method of claim 219, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

259. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

producing a mixture from the formation, wherein at least a portion of the mixture is produced during the pyrolysis and the mixture moves through the formation in a vapor phase; and

maintaining a pressure within at least a majority of the selected section above about 2.0 bars absolute.

260. The method of claim 259, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

261. The method of claim 259, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

262. The method of claim 259, wherein the one or more heaters comprise electrical heaters.

263. The method of claim 259, wherein the one or more heaters comprise surface burners.

264. The method of claim 259, wherein the one or more heaters comprise flameless distributed combustors.

265. The method of claim 259, wherein the one or more heaters comprise natural distributed combustors.

266. The method of claim 259, further comprising controlling the pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

267. The method of claim 259, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

268. The method of claim 259, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

269. The method of claim 259, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

270. The method of claim 259, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

271. The method of claim 259, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

272. The method of claim 259, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

273. The method of claim 259, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefms.

274. The method of claim 259, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

275. The method of claim 259, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

276. The method of claim 259, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

277. The method of claim 259, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

278. The method of claim 259, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

279. The method of claim 259, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

280. The method of claim 259, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

281. The method of claim 259, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

282. The method of claim 259, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

283. The method of claim 259, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

284. The method of claim 259, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

285. The method of claim 259, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

286. The method of claim 259, wherein the pressure is measured at a wellhead of a production well.

287. The method of claim 259, wherein the pressure is measured at a location within a wellbore of the production well.

288. The method of claim 259, wherein the pressure is maintained below about 100 bars absolute.

289. The method of claim 259, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

290. The method of claim 289, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

291. The method of claim 259, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

292. The method of claim 259, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

293. The method of claim 259, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

294. The method of claim 259, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

295. The method of claim 259, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

296. The method of claim 259, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

297. The method of claim 259, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

298. The method of claim 259, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

299. The method of claim 259, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

300. The method of claim 259, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

301. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

maintaining a pressure within at least a majority of the selected section of the formation above 2.0 bars absolute; and

producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity higher than an API gravity of condensable hydrocarbons in a mixture producible from the formation at the same temperature and at atmospheric pressure.

302. The method of claim 301, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

303. The method of claim 301, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

304. The method of claim 301, wherein the one or more heaters comprise electrical heaters.

305. The method of claim 301, wherein the one or more heaters comprise surface burners.

306. The method of claim 301, wherein the one or more heaters comprise flameless distributed combustors.

307. The method of claim 301, wherein the one or more heaters comprise natural distributed combustors.

308. The method of claim 301, further comprising controlling the pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

309. The method of claim 301, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

310. The method of claim 301, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

311. The method of claim 301, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

312. The method of claim 301, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

313. The method of claim 301, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

314. The method of claim 301, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

315. The method of claim 301, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

316. The method of claim 301, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

317. The method of claim 301, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

318. The method of claim 301, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

319. The method of claim 301, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

320. The method of claim 301, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

321. The method of claim 301, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

322. The method of claim 301, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

323. The method of claim 301, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

324. The method of claim 301, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

325. The method of claim 301, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

326. The method of claim 301, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

327. The method of claim 301, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

328. The method of claim 301, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

329. The method of claim 301, wherein a partial pressure of H₂ is measured when the mixture is at a production well.

330. The method of claim 301, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

331. The method of claim 301, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

332. The method of claim 301, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

333. The method of claim 301, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

334. The method of claim 301, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

335. The method of claim 301, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

336. The method of claim 301, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

337. The method of claim 301, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

338. The method of claim 337, wherein at least about 20 heaters are disposed in the formation for each production well.

339. The method of claim 301, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

340. The method of claim 301, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

341. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

maintaining a pressure within at least a majority of the selected section of the formation to above 2.0 bars absolute; and

producing a fluid from the formation, wherein condensable hydrocarbons within the fluid comprise an atomic hydrogen to atomic carbon ratio of greater than about 1.75.

342. The method of claim 341, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

343. The method of claim 341, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

344. The method of claim 341, wherein the one or more heaters comprise electrical heaters.

345. The method of claim 341, wherein the one or more heaters comprise surface burners.

346. The method of claim 341, wherein the one or more heaters comprise flameless distributed combustors.

347. The method of claim 341, wherein the one or more heaters comprise natural distributed combustors.

348. The method of claim 341, further comprising controlling the pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

349. The method of claim 341, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

350. The method of claim 341, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

351. The method of claim 341, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

352. The method of claim 341, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

353. The method of claim 341, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

354. The method of claim 341, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

355. The method of claim 341, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

356. The method of claim 341, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

357. The method of claim 341, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

358. The method of claim 341, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

359. The method of claim 341, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

360. The method of claim 341, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

361. The method of claim 341, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

362. The method of claim 341, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

363. The method of claim 341, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

364. The method of claim 341, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

365. The method of claim 341, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

366. The method of claim 341, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

367. The method of claim 341, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

368. The method of claim 341, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

369. The method of claim 341, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

370. The method of claim 341, further comprising altering the pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

371. The method of claim 341, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

372. The method of claim 341, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

373. The method of claim 341, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

374. The method of claim 341, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

375. The method of claim 341, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

376. The method of claim 341, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

377. The method of claim 341, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

378. The method of claim 341, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

379. The method of claim 341, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

380. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

maintaining a pressure within at least a majority of the selected section of the formation to above 2.0 bars absolute; and

producing a mixture from the formation, wherein the produced mixture comprises a higher amount of non-condensable components as compared to non-condensable components producible from the formation under the same temperature conditions and at atmospheric pressure.

381. The method of claim 380, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

382. The method of claim 380, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

383. The method of claim 380, wherein the one or more heaters comprise electrical heaters.

384. The method of claim 380, wherein the one or more heaters comprise surface burners.

385. The method of claim 380, wherein the one or more heaters comprise flameless distributed combustors.

386. The method of claim 380, wherein the one or more heaters comprise natural distributed combustors.

387. The method of claim 380, further comprising controlling the pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

388. The method of claim 380, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

389. The method of claim 380, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

390. The method of claim 380, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

391. The method of claim 380, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

392. The method of claim 380, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

393. The method of claim 380, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

394. The method of claim 380, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

395. The method of claim 380, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

396. The method of claim 380, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

397. The method of claim 380, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

398. The method of claim 380, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

399. The method of claim 380, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

400. The method of claim 380, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

401. The method of claim 380, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

402. The method of claim 380, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

403. The method of claim 380, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

404. The method of claim 380, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

405. The method of claim 380, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

406. The method of claim 380, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

407. The method of claim 380, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

408. The method of claim 380, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

409. The method of claim 380, further comprising altering the pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

410. The method of claim 380, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

411. The method of claim 380, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

412. The method of claim 380, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

413. The method of claim 380, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

414. The method of claim 380, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

415. The method of claim 380, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

416. The method of claim 380, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

417. The method of claim 380, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

418. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that superimposed heat from the one or more heaters pyrolyzes at least about 20% by weight of hydrocarbons within the selected section of the formation; and

producing a mixture from the formation.

419. The method of claim 418, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

420. The method of claim 418, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

421. The method of claim 418, wherein the one or more heaters comprise electrical heaters.

422. The method of claim 418, wherein the one or more heaters comprise surface burners.

423. The method of claim 418, wherein the one or more heaters comprise flameless distributed combustors.

424. The method of claim 418, wherein the one or more heaters comprise natural distributed combustors.

425. The method of claim 418, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

426. The method of claim 418, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

427. The method of claim 418, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

428. The method of claim 418, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

429. The method of claim 418, wherein providing heat from the one or more heaters comprises heating the selected formation such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

430. The method of claim 418, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 250.

431. The method of claim 418, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

432. The method of claim 418, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

433. The method of claim 418, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

434. The method of claim 418, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

435. The method of claim 418, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

436. The method of claim 418, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

437. The method of claim 418, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

438. The method of claim 418, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

439. The method of claim 418, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

440. The method of claim 418, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

441. The method of claim 418, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

442. The method of claim 418, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

443. The method of claim 418, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

444. The method of claim 418, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

445. The method of claim 418, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

446. The method of claim 418, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

447. The method of claim 418, wherein a partial pressure of H₂ is measured when the mixture is at a production well.

448. The method of claim 418, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

449. The method of claim 418, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

450. The method of claim 418, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

451. The method of claim 418, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

452. The method of claim 418, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

453. The method of claim 418, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

454. The method of claim 418, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

455. The method of claim 418, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

456. The method of claim 455, wherein at least about 20 heaters are disposed in the formation for each production well.

457. The method of claim 418, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

458. The method of claim 418, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

459. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that superimposed heat from the one or more heaters pyrolyzes at least about 20% of hydrocarbons within the selected section of the formation; and

producing a mixture from the formation, wherein the mixture comprises a condensable component having an API gravity of at least about 25°

.

460. The method of claim 459, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

461. The method of claim 459, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

462. The method of claim 459, wherein the one or more heaters comprise electrical heaters.

463. The method of claim 459, wherein the one or more heaters comprise surface burners.

464. The method of claim 459, wherein the one or more heaters comprise flameless distributed combustors.

465. The method of claim 459, wherein the one or more heaters comprise natural distributed combustors.

466. The method of claim 459, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

467. The method of claim 459, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

468. The method of claim 459, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

469. The method of claim 459, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

470. The method of claim 459, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

471. The method of claim 459, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

472. The method of claim 459, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

473. The method of claim 459, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

474. The method of claim 459, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

475. The method of claim 459, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

476. The method of claim 459, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

477. The method of claim 459, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

478. The method of claim 459, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

479. The method of claim 459, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

480. The method of claim 459, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

481. The method of claim 459, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

482. The method of claim 459, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

483. The method of claim 459, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

484. The method of claim 459, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

485. The method of claim 459, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

486. The method of claim 459, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

487. The method of claim 459, wherein a partial pressure of H₂ is measured when the mixture is at a production well.

488. The method of claim 459, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

489. The method of claim 459, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

490. The method of claim 459, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

491. The method of claim 459, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

492. The method of claim 459, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

493. The method of claim 459, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

494. The method of claim 459, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

495. The method of claim 459, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

496. The method of claim 495, wherein at least about 20 heaters are disposed in the formation for each production well.

497. The method of claim 459, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

498. The method of claim 459, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

499. A method of treating a layer of a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the layer, wherein the one or more heaters are positioned proximate an edge of the layer;

allowing the heat to transfer from the one or more heaters to a selected section of the layer such that superimposed heat from the one or more heaters pyrolyzes at least some hydrocarbons within the selected section of the formation; and

producing a mixture from the formation.

500. The method of claim 499, wherein the one or more heaters are laterally spaced from a center of the layer.

501. The method of claim 499, wherein the one or more heaters are positioned in a staggered line.

502. The method of claim 499, wherein the one or more heaters positioned proximate the edge of the layer can increase an amount of hydrocarbons produced per unit of energy input to the one or more heaters.

503. The method of claim 499, wherein the one or more heaters positioned proximate the edge of the layer can increase the volume of formation undergoing pyrolysis per unit of energy input to the one or more heaters.

504. The method of claim 499, wherein the one or more heaters comprise electrical heaters.

505. The method of claim 499, wherein the one or more heaters comprise surface burners.

506. The method of claim 499, wherein the one or more heaters comprise flameless distributed combustors.

507. The method of claim 499, wherein the one or more heaters comprise natural distributed combustors.

508. The method of claim 499, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

509. The method of claim 499, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1.0°

C. per day during pyrolysis.

510. The method of claim 499, wherein providing heat from the one or more heaters to at least the portion of the layer comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

511. The method of claim 499, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

512. The method of claim 499, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

513. The method of claim 499, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

514. The method of claim 499, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

515. The method of claim 499, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

516. The method of claim 499, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

517. The method of claim 499, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

518. The method of claim 499, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

519. The method of claim 499, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

520. The method of claim 499, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

521. The method of claim 499, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

522. The method of claim 499, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

523. The method of claim 499, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

524. The method of claim 499, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

525. The method of claim 499, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

526. The method of claim 499, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

527. The method of claim 499, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

528. The method of claim 527, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

529. The method of claim 499, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

530. The method of claim 499, further comprising controlling formation conditions, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

531. The method of claim 499, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

532. The method of claim 499, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

533. The method of claim 499, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

534. The method of claim 499, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

535. The method of claim 499, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

536. The method of claim 499, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

537. The method of claim 536, wherein at least about 20 heaters are disposed in the formation for each production well.

538. The method of claim 499, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

539. The method of claim 499, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

540. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure; and

producing a mixture from the formation.

541. The method of claim 540, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

542. The method of claim 540, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

543. The method of claim 540, wherein the one or more heaters comprise electrical heaters.

544. The method of claim 540, wherein the one or more heaters comprise surface burners.

545. The method of claim 540, wherein the one or more heaters comprise flameless distributed combustors.

546. The method of claim 540, wherein the one or more heaters comprise natural distributed combustors.

547. The method of claim 540, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

548. The method of claim 540, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (Cv), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

549. The method of claim 540, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

550. The method of claim 540, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

551. The method of claim 540, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

552. The method of claim 540, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

553. The method of claim 540, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

554. The method of claim 540, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

555. The method of claim 540, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

556. The method of claim 540, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

557. The method of claim 540, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

558. The method of claim 540, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

559. The method of claim 540, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

560. The method of claim 540, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

561. The method of claim 540, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

In some embodiments, the recovery unit, as shown in FIG. 377, separates the component from a feedstock stream (e.g., formation fluid, synthetic condensate, a gas stream, a light fraction, a middle fraction, a heavy fraction, bottoms, a naphtha stream, a jet fuel stream, a diesel stream, etc). Recovery units may separate more than one component from the feedstock stream in certain embodiments. For example, a recovery unit may separate a feedstock stream into a naphthalene stream, an anthracene stream, a naphthalene/anthracene stream, and/or a hydrocarbon mixture. Fluids generated during an in situ conversion process (e.g., of a coal formation) may contain naphthalene and/or anthracene.

When nitrogen containing components (e.g., pyridines and pyrroles) are to be separated from a feedstock, the recovery unit may be a nitrogen extraction unit. In some embodiments, a nitrogen extraction unit may separate the nitrogen containing components using a sulfuric acid process or a formic acid process. Nitrogen extraction units may include sulfuric acid extraction units and/or closed cycle formic acid extraction units. A sulfiric acid process may separate a portion of the formation fluid into a raffinate and an extract oil. The

562. The method of claim 540, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

563. The method of claim 540, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

564. The method of claim 540, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

565. The method of claim 540, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

566. The method of claim 540, wherein the controlled pressure is at least about 2.0 bars absolute.

567. The method of claim 540, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

568. The method of claim 540, wherein a partial pressure of H₂ is measured when the mixture is at a production well.

569. The method of claim 540, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

570. The method of claim 540, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

571. The method of claim 540, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

572. The method of claim 540, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

573. The method of claim 540, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

574. The method of claim 540, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

575. The method of claim 540, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

576. The method of claim 540, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

577. The method of claim 576, wherein at least about 20 heaters are disposed in the formation for each production well.

578. The method of claim 540, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

579. The method of claim 540, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

580. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation to raise an average temperature within the selected section to, or above, a temperature that will pyrolyze hydrocarbons within the selected section;

producing a mixture from the formation; and

controlling API gravity of the produced mixture to be greater than about 25 degrees API by controlling average pressure and average temperature in the selected section such that the average pressure in the selected section is greater than the pressure (p) set forth in the following equation for an assessed average temperature (T) in the selected section;

p=e<sup>[−

44000/T+67]</sup>

where p is measured in psia and T is measured in °

Kelvin.

581. The method of claim 580, wherein the API gravity of the produced mixture is controlled to be greater than about 30 degrees API, and wherein the equation is:

p=e<sup>[−

31000/T+51]</sup>.

582. The method of claim 580, wherein the API gravity of the produced mixture is controlled to be greater than about 35 degrees API, and wherein the equation is:

p=e<sup>[−

22000/T+38]</sup>.

583. The method of claim 580, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

584. The method of claim 580, wherein controlling the average temperature comprises maintaining a temperature in the selected section within a pyrolysis temperature range.

585. The method of claim 580, wherein the one or more heaters comprise electrical heaters.

586. The method of claim 580, wherein the one or more heaters comprise surface burners.

587. The method of claim 580, wherein the one or more heaters comprise flameless distributed combustors.

588. The method of claim 580, wherein the one or more heaters comprise natural distributed combustors.

589. The method of claim 580, further comprising controlling a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

590. The method of claim 580, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

591. The method of claim 580, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_V), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_V*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

592. The method of claim 580, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

593. The method of claim 580, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

594. The method of claim 580, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

595. The method of claim 580, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

596. The method of claim 580, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

597. The method of claim 580, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

598. The method of claim 580, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

599. The method of claim 580, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

600. The method of claim 580, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

601. The method of claim 580, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

602. The method of claim 580, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

603. The method of claim 580, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

604. The method of claim 580, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

605. The method of claim 580, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

606. The method of claim 580, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

607. The method of claim 580, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

608. The method of claim 580, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

609. The method of claim 580, wherein a partial pressure of H₂ is measured when the mixture is at a production well.

610. The method of claim 580, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

611. The method of claim 580, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

612. The method of claim 580, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

613. The method of claim 580, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

614. The method of claim 580, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

615. The method of claim 580, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

616. The method of claim 580, wherein the heat is controlled to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

617. The method of claim 580, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

618. The method of claim 617, wherein at least about 20 heaters are disposed in the formation for each production well.

619. The method of claim 580, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

620. The method of claim 580, fturther comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

621. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat to at least a portion of a hydrocarbon containing formation such that a temperature (T) in a substantial part of the heated portion exceeds 270°

C. and hydrocarbons are pyrolyzed within the heated portion of the formation;

controlling a pressure (p) within at least a substantial part of the heated portion of the formation;

p_bar>

e<sup>[(−

A/T)+B−

2.6744]</sup>;

wherein p is the pressure in bars absolute and T is the temperature in degrees K, and A and B are parameters that are larger than 10 and are selected in relation to the characteristics and composition of the hydrocarbon containing formation and on the required olefin content and carbon number of the pyrolyzed hydrocarbon fluids; and

producing pyrolyzed hydrocarbon fluids from the heated portion of the formation.

622. The method of claim 621, wherein A is greater than 14000 and B is greater than about 25 and a majority of the produced pyrolyzed hydrocarbon fluids have an average carbon number lower than 25 and comprise less than about 10% by weight of olefins.

623. The method of claim 621, wherein T is less than about 390°

C., p is greater than about 1.4 bar, A is greater than about 44000, and b is greater than about 67, and a majority of the produced pyrolyzed hydrocarbon fluids have an average carbon number less than 25 and comprise less than 10% by weight of olefins.

624. The method of claim 621, wherein Tis less than about 390°

C., p is greater than about 2 bar, A is less than about 57000, and b is less than about 83, and a majority of the produced pyrolyzed hydrocarbon fluids have an average carbon number lower than about 21.

625. The method of claim 621, further comprising controlling the heat such that an average heating rate of the heated portion is less than about 3°

C. per day during pyrolysis.

626. The method of claim 621, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

627. The method of claim 621, wherein heat is transferred substantially by conduction from one or more heaters located in one or more heaters to the heated portion of the formation.

628. The method of claim 621, further comprising controlling formation conditions to produce a mixture of hydrocarbon fluids and H₂, wherein a partial pressure of H₂ within the mixture flowing through the formation is greater than 0.5 bars.

629. The method of claim 628, further comprising, hydrogenating a portion of the produced pyrolyzed hydrocarbon fluids with at least a portion of the produced hydrogen and heating the fluids with heat from hydrogenation.

630. The method of claim 621, wherein the hydrocarbon containing formation is a coal seam and at least about 70% of the hydrocarbon content of the coal, when such hydrocarbon content is measured by a Fischer assay, is produced from the heated portion of the formation.

631. The method of claim 621, wherein the substantially gaseous pyrolyzed hydrocarbon fluids are produced from a production well, the method further comprising heating a wellbore of the production well to inhibit condensation of the hydrocarbon fluids within the wellbore.

632. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation to raise an average temperature within the selected section to, or above, a temperature that will pyrolyze hydrocarbons within the selected section;

producing a mixture from the formation; and

controlling a weight percentage of olefins of the produced mixture to be less than about 20% by weight by controlling average pressure and average temperature in the selected section such that the average pressure in the selected section is greater than the pressure (p) set forth in the following equation for an assessed average temperature (T) in the selected section;

p=e<sup>[−

57000/T+831]</sup>

where p is measured in psia and T is measured in °

Kelvin.

633. The method of claim 632, wherein the weight percentage of olefins of the produced mixture is controlled to be less than about 10% by weight, and wherein the equation is:

p=e[−

16000/T+281].

634. The method of claim 632, wherein the weight percentage of olefins of the produced mixture is controlled to be less than about 5% by weight, and wherein the equation is:

p=e<sup>[−

12000/T+22]</sup>.

635. The method of claim 632, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

636. The method of claim 632, wherein the one or more heaters comprise electrical heaters.

637. The method of claim 632, wherein the one or more heaters comprise surface burners.

638. The method of claim 632, wherein the one or more heaters comprise flameless distributed combustors.

639. The method of claim 632, wherein the one or more heaters comprise natural distributed combustors.

640. The method of claim 632, further comprising controlling a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

641. The method of claim 640, wherein controlling an average temperature comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

642. The method of claim 632, further comprising controlling the heat such that an average heating rate of the selected section is less than about 3.0°

C. per day during pyrolysis.

643. The method of claim 632, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

644. The method of claim 632, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

645. The method of claim 632, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

646. The method of claim 632, wherein providing heat from the one or more heaters comprises heating the selected formation such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

647. The method of claim 632, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

648. The method of claim 632, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

649. The method of claim 632, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

650. The method of claim 632, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

651. The method of claim 632, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

652. The method of claim 632, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

653. The method of claim 632, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

654. The method of claim 632, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

655. The method of claim 632, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

656. The method of claim 632, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

657. The method of claim 632, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

658. The method of claim 632, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

659. The method of claim 632, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

660. The method of claim 632, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

661. The method of claim 632, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

662. The method of claim 632, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

663. The method of claim 632, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

664. The method of claim 632, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

665. The method of claim 632, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

666. The method of claim 632, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

667. The method of claim 632, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

668. The method of claim 632, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

669. The method of claim 632, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

670. The method of claim 632, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

671. The method of claim 632, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

672. The method of claim 632, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

673. The method of claim 632, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

674. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation to raise an average temperature within the selected section to, or above, a temperature that will pyrolyze hydrocarbons within the selected section;

producing a mixture from the formation; and

controlling hydrocarbons having carbon numbers greater than 25 of the produced mixture to be less than about 25% by weight by controlling average pressure and average temperature in the selected section such that the average pressure in the selected section is greater than the pressure (p) set forth in the following equation for an assessed average temperature (T) in the selected section;

p=e[−

14000/T+25]

where p is measured in psia and T is measured in °

Kelvin.

675. The method of claim 674, wherein the hydrocarbons having carbon numbers greater than 25 of the produced mixture is controlled to be less than about 20% by weight, and wherein the equation is:

p=e<sup>[−

16000/T+28]</sup>.

676. The method of claim 674, wherein the hydrocarbons having carbon numbers greater than 25 of the produced mixture is controlled to be less than about 15% by weight, and wherein the equation is:

p=e<sup>[−

18000/T+32]</sup>.

677. The method of claim 674, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

678. The method of claim 674, wherein the one or more heaters comprise electrical heaters.

679. The method of claim 674, wherein the one or more heaters comprise surface burners.

680. The method of claim 674, wherein the one or more heaters comprise flameless distributed combustors.

681. The method of claim 674, wherein the one or more heaters comprise natural distributed combustors.

682. The method of claim 674, fturther comprising controlling a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

683. The method of claim 682, wherein controlling the temperature comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

684. The method of claim 674, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

685. The method of claim 674, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

686. The method of claim 674, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

687. The method of claim 674, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

688. The method of claim 674, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

689. The method of claim 674, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

690. The method of claim 674, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

691. The method of claim 674, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

692. The method of claim 674, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

693. The method of claim 674, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

694. The method of claim 674, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

695. The method of claim 674, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

696. The method of claim 674, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

697. The method of claim 674, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

698. The method of claim 674, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

699. The method of claim 674, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

700. The method of claim 674, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

701. The method of claim 674, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

702. The method of claim 674, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

703. The method of claim 674, wherein a partial pressure of H₂ is measured when the mixture is at a production well.

704. The method of claim 674, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

705. The method of claim 674, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

706. The method of claim 674, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

707. The method of claim 674, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

708. The method of claim 674, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

709. The method of claim 674, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

710. The method of claim 674, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

711. The method of claim 710, wherein at least about 20 heaters are disposed in the formation for each production well.

712. The method of claim 674, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

713. The method of claim 674, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

714. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation to raise an average temperature within the selected section to, or above, a temperature that will pyrolyze hydrocarbons within the selected section;

producing a mixture from the formation; and

controlling an atomic hydrogen to carbon ratio of the produced mixture to be greater than about 1.7 by controlling average pressure and average temperature in the selected section such that the average pressure in the selected section is greater than the pressure (p) set forth in the following equation for an assessed average temperature (T) in the selected section;

p=e<sup>[−

38000/T+61]</sup>

where p is measured in psia and T is measured in °

Kelvin.

715. The method of claim 714, wherein the atomic hydrogen to carbon ratio of the produced mixture is controlled to be greater than about 1.8, and wherein the equation is:

p=e<sup>[−

13000/T+24]</sup>.

716. The method of claim 714, wherein the atomic hydrogen to carbon ratio of the produced mixture is controlled to be greater than about 1.9, and wherein the equation is:

p=e[−

8000/T+18].

717. The method of claim 714, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

718. The method of claim 714, wherein the one or more heaters comprise electrical heaters.

719. The method of claim 714, wherein the one or more heaters comprise surface burners.

720. The method of claim 714, wherein the one or more heaters comprise flameless distributed combustors.

721. The method of claim 714, wherein the one or more heaters comprise natural distributed combustors.

722. The method of claim 714, further comprising controlling a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

723. The method of claim 722, wherein controlling the temperature comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

724. The method of claim 714, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

725. The method of claim 714, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

726. The method of claim 714, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

727. The method of claim 714, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

728. The method of claim 714, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 250.

729. The method of claim 714, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

730. The method of claim 714, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

731. The method of claim 714, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

732. The method of claim 714, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

733. The method of claim 714, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

734. The method of claim 714, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

735. The method of claim 714, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

736. The method of claim 714, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

737. The method of claim 714, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

738. The method of claim 714, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

739. The method of claim 714, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30%.by weight of the condensable hydrocarbons are cycloalkanes.

740. The method of claim 714, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

741. The method of claim 714, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

742. The method of claim 714, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

743. The method of claim 714, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

744. The method of claim 714, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

745. The method of claim 714, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

746. The method of claim 714, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

747. The method of claim 714, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

748. The method of claim 714, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

749. The method of claim 714, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

750. The method of claim 714, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

751. The method of claim 714, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

752. The method of claim 714, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

753. The method of claim 714, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

754. The method of claim 714, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

755. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

controlling a pressure-temperature relationship within at least the selected section of the formation by selected energy input into the one or more heaters and by pressure release from the selected section through wellbores of the one or more heaters; and

producing a mixture from the formation.

756. The method of claim 755, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

757. The method of claim 755, wherein the one or more heaters comprise at least two heaters.

758. The method of claim 755, wherein the one or more heaters comprise surface burners.

759. The method of claim 755, wherein the one or more heaters comprise flameless distributed combustors.

760. The method of claim 755, wherein the one or more heaters comprise natural distributed combustors.

761. The method of claim 755, further comprising controlling the pressure-temperature relationship by controlling a rate of removal of fluid from the formation.

762. The method of claim 755, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

763. The method of claim 755, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

764. The method of claim 755, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

765. The method of claim 755, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

766. The method of claim 755, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

767. The method of claim 755, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

768. The method of claim 755, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

769. The method of claim 755, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

770. The method of claim 755, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

771. The method of claim 755, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

772. The method of claim 755, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

773. The method of claim 755, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

774. The method of claim 755, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

775. The method of claim 755, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

776. The method of claim 755, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

777. The method of claim 755, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

778. The method of claim 755, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

779. The method of claim 755, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

780. The method of claim 755, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

781. The method of claim 755, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

782. The method of claim 755, further comprising controlling formation conditions to produce a mixture of hydrocarbon fluids and H₂, wherein the partial pressure of H₂ within the mixture is greater than about 0.5 bars.

783. The method of claim 755, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

784. The method of claim 755, wherein a partial pressure of H₂ is measured when the mixture is at a production well.

785. The method of claim 755, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

786. The method of claim 755, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

787. The method of claim 755, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

788. The method of claim 755, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

789. The method of claim 755, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

790. The method of claim 755, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

791. The method of claim 755, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

792. The method of claim 755, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

793. The method of claim 792, wherein at least about 20 heaters are disposed in the formation for each production well.

794. The method of claim 755, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

795. The method of claim 755, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

796. A method of treating a hydrocarbon containing formation in situ, comprising:

heating a selected volume (V) of the hydrocarbon containing formation, wherein formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

797. The method of claim 796, wherein heating a selected volume comprises heating with an electrical heater.

798. The method of claim 796, wherein heating a selected volume comprises heating with a surface burner.

799. The method of claim 796, wherein heating a selected volume comprises heating with a flameless distributed combustor.

800. The method of claim 796, wherein heating a selected volume comprises heating with at least one natural distributed combustor.

801. The method of claim 796, further comprising controlling a pressure and a temperature within at least a majority of the selected volume of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

802. The method of claim 796, further comprising controlling the heating such that an average heating rate of the selected volume is less than about 1°

C. per day during pyrolysis.

803. The method of claim 796, wherein a value for C_vis determined as an average heat capacity of two or more samples taken from the hydrocarbon containing formation.

804. The method of claim 796, wherein heating the selected volume comprises transferring heat substantially by conduction.

805. The method of claim 796, wherein heating the selected volume comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

806. The method of claim 796, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

807. The method of claim 796, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

808. The method of claim 796, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

809. The method of claim 796, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

810. The method of claim 796, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

811. The method of claim 796, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

812. The method of claim 796, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

813. The method of claim 796, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

814. The method of claim 796, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

815. The method of claim 796, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

816. The method of claim 796, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

817. The method of claim 796, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

818. The method of claim 796, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

819. The method of claim 796, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

820. The method of claim 796, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer

821. The method of claim 796, further comprising controlling a pressure within at least a majority of the selected volume of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

822. The method of claim 796, further comprising controlling formation conditions to produce a mixture from the formation comprising condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

823. The method of claim 796, wherein a partial pressure of H₂ is measured when the mixture is at a production well.

824. The method of claim 796, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

825. The method of claim 796, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

826. The method of claim 796, further comprising:

providing hydrogen (H₂) to the heated volume to hydrogenate hydrocarbons within the volume; and

heating a portion of the volume with heat from hydrogenation.

827. The method of claim 796, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

828. The method of claim 796, further comprising increasing a permeability of a majority of the selected volume to greater than about 100 millidarcy.

829. The method of claim 796, further comprising substantially uniformly increasing a permeability of a majority of the selected volume.

830. The method of claim 796, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

831. The method of claim 796, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

832. The method of claim 831, wherein at least about 20 heaters are disposed in the formation for each production well.

833. The method of claim 796, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

834. The method of claim 796, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

835. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation to raise an average temperature within the selected section to, or above, a temperature that will pyrolyze hydrocarbons within the selected section;

controlling heat output from the one or more heaters such that an average heating rate of the selected section rises by less than about 3°

C. per day when the average temperature of the selected section is at, or above, the temperature that will pyrolyze hydrocarbons within the selected section; and

producing a mixture from the formation.

836. The method of claim 835, wherein controlling heat output comprises:

raising the average temperature within the selected section to a first temperature that is at or above a minimum pyrolysis temperature of hydrocarbons within the formation;

limiting energy input into the one or more heaters to inhibit increase in temperature of the selected section; and

increasing energy input into the formation to raise an average temperature of the selected section above the first temperature when production of formation fluid declines below a desired production rate.

837. The method of claim 835, wherein controlling heat output comprises:

raising the average temperature within the selected section to a first temperature that is at or above a minimum pyrolysis temperature of hydrocarbons within the formation;

limiting energy input into the one or more heaters to inhibit increase in temperature of the selected section; and

increasing energy input into the formation to raise an average temperature of the selected section above the first temperature when quality of formation fluid produced from the formation falls below a desired quality.

838. The method of claim 835, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section.

839. The method of claim 835, wherein the one or more heaters comprise electrical heaters.

840. The method of claim 835, wherein the one or more heaters comprise surface burners.

841. The method of claim 835, wherein the one or more heaters comprise flameless distributed combustors.

842. The method of claim 835, wherein the one or more heaters comprise natural distributed combustors.

843. The method of claim 835, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

844. The method of claim 835, wherein the heat is controlled such that an average heating rate of the selected section is less than about 1.5°

C. per day during pyrolysis.

845. The method of claim 835, wherein the heat is controlled such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

846. The method of claim 835, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

847. The method of claim 835, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

848. The method of claim 835, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

849. The method of claim 835, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

850. The method of claim 835, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

851. The method of claim 835, wherein the produced mixture comprises condensable hydrocarbons, wherein the condensable hydrocarbons have an olefin content less than about 2.5% by weight of the condensable hydrocarbons, and wherein the olefin content is greater than about 0.1% by weight of the condensable hydrocarbons.

852. The method of claim 835, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.

853. The method of claim 835, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.10 and wherein the ratio of ethene to ethane is greater than about 0.001.

854. The method of claim 835, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.05 and wherein the ratio of ethene to ethane is greater than about 0.001.

855. The method of claim 835, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

856. The method of claim 835, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

857. The method of claim 835, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

858. The method of claim 835, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

859. The method of claim 835, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

860. The method of claim 835, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

861. The method of claim 835, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

862. The method of claim 835, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

863. The method of claim 835, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

864. The method of claim 835, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

865. The method of claim 835, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

866. The method of claim 835, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

867. The method of claim 835, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

868. The method of claim 835, wherein a partial pressure of H₂ is measured when the mixture is at a production well.

869. The method of claim 835, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

870. The method of claim 835, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

871. The method of claim 835, further comprising:

providing H₂ to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

872. The method of claim 835, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

873. The method of claim 835, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

874. The method of claim 835, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

875. The method of claim 835, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

876. The method of claim 835, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

877. The method of claim 876, wherein at least about 20 heaters are disposed in the formation for each production well.

878. The method of claim 835, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

879. The method of claim 835, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

880. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

to heat a selected section of the formation to an average temperature above about 270°

C.;

allowing the heat to transfer from the one or more heaters to the selected section of the formation;

controlling the heat from the one or more heaters such that an average heating rate of the selected section is less than about 3°

C. per day during pyrolysis; and

producing a mixture from the formation.

881. The method of claim 880, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

882. The method of claim 880, wherein the one or more heaters comprise electrical heaters.

883. The method of claim 880, further comprising supplying electricity to the electrical heaters substantially during non-peak hours.

884. The method of claim 880, wherein the one or more heaters comprise surface burners.

885. The method of claim 880, wherein the one or more heaters comprise flameless distributed combustors.

886. The method of claim 880, wherein the one or more heaters comprise natural distributed combustors.

887. The method of claim 880, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

888. The method of claim 880, wherein the heat is further controlled such that an average heating rate of the selected section is less than about 3°

C./day until production of condensable hydrocarbons substantially ceases.

889. The method of claim 880, wherein the heat is further controlled such that an average heating rate of the selected section is less than about 1.5°

C. per day during pyrolysis.

890. The method of claim 880, wherein the heat is further controlled such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

891. The method of claim 880, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

892. The method of claim 880, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

893. The method of claim 880, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

894. The method of claim 880, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 250.

895. The method of claim 880, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

896. The method of claim 880, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

897. The method of claim 880, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.

898. The method of claim 880, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

899. The method of claim 880, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

900. The method of claim 880, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

901. The method of claim 880, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

902. The method of claim 880, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

903. The method of claim 880, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

904. The method of claim 880, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

905. The method of claim 880, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

906. The method of claim 880, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

907. The method of claim 880, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

908. The method of claim 880, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

909. The method of claim 880, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

910. The method of claim 880, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

911. The method of claim 910, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

912. The method of claim 880, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

913. The method of claim 880, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

914. The method of claim 880, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

915. The method of claim 880, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

916. The method of claim 880, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

917. The method of claim 880, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

918. The method of claim 880, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

919. The method of claim 880, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

920. The method of claim 919, wherein at least about 20 heaters are disposed in the formation for each production well.

921. The method of claim 880, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

922. The method of claim 880, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

923. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

producing a mixture from the formation through at least one production well;

monitoring a temperature at or in the production well; and

controlling heat input to raise the monitored temperature at a rate of less than about 3°

C. per day.

924. The method of claim 923, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

925. The method of claim 923, wherein the one or more heaters comprise electrical heaters.

926. The method of claim 923, wherein the one or more heaters comprise surface burners.

927. The method of claim 923, wherein the one or more heaters comprise flameless distributed combustors.

928. The method of claim 923, wherein the one or more heaters comprise natural distributed combustors.

929. The method of claim 923, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

930. The method of claim 923, wherein the heat is controlled such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

931. The method of claim 923, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

932. The method of claim 923, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

933. The method of claim 923, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

934. The method of claim 923, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

935. The method of claim 923, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins,

936. The method of claim 923, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.

937. The method of claim 923, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

938. The method of claim 923, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen

939. The method of claim 923, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

940. The method of claim 923, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

941. The method of claim 923, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

942. The method of claim 923, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

943. The method of claim 923, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

944. The method of claim 923, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

945. The method of claim 923, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

946. The method of claim 923, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

947. The method of claim 923, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

948. The method of claim 923, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

949. The method of claim 923, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

950. The method of claim 949, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

951. The method of claim 923, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

952. The method of claim 923, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

953. The method of claim 923, further comprising:

providing H₂ to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

954. The method of claim 923, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

955. The method of claim 923, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

956. The method of claim 923, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

957. The method of claim 923, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

958. The method of claim 923, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

959. The method of claim 958, wherein at least about 20 heaters are disposed in the formation for each production well.

960. The method of claim 923, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

961. The method of claim 923, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

962. A method of treating a hydrocarbon containing formation in situ, comprising:

heating a portion of the formation to a temperature sufficient to support oxidation of hydrocarbons within the portion, wherein the portion is located substantially adjacent to a wellbore;

flowing an oxidant through a conduit positioned within the wellbore to a heater zone within the portion, wherein the heater zone supports an oxidation reaction between hydrocarbons and the oxidant;

reacting a portion of the oxidant with hydrocarbons to generate heat; and

transferring generated heat substantially by conduction to a pyrolysis zone of the formation to pyrolyze at least a portion of the hydrocarbons within the pyrolysis zone.

963. The method of claim 962, wherein heating the portion of the formation comprises raising a temperature of the portion above about 400°

C.

964. The method of claim 962, wherein the conduit comprises critical flow orifices, the method further comprising flowing the oxidant through the critical flow orifices to the heater zone.

965. The method of claim 962, further comprising removing reaction products from the heater zone through the wellbore.

966. The method of claim 962, farther comprising removing excess oxidant from the heater zone to inhibit transport of the oxidant to the pyrolysis zone.

967. The method of claim 962, further comprising transporting the oxidant from the conduit to the heater zone substantially by diffusion.

968. The method of claim 962, further comprising heating the conduit with reaction products being removed through the wellbore.

969. The method of claim 962, wherein the oxidant comprises hydrogen peroxide.

970. The method of claim 962, wherein the oxidant comprises air.

971. The method of claim 962, wherein the oxidant comprises a fluid substantially free of nitrogen.

972. The method of claim 962, further comprising limiting an amount of oxidant to maintain a temperature of the heater zone less than about 1200°

C.

973. The method of claim 962, wherein heating the portion of the formation comprises electrically heating the formation.

974. The method of claim 962, wherein heating the portion of the formation comprises heating the portion using exhaust gases from a surface burner.

975. The method of claim 962, wherein heating the portion of the formation comprises heating the portion with a flameless distributed combustor.

976. The method of claim 962, further comprising controlling a pressure and a temperature within at least a majority of the pyrolysis zone, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

977. The method of claim 962, further comprising controlling the heat such that an average heating rate of the pyrolysis zone is less than about 1°

C. per day during pyrolysis.

978. The method of claim 962, wherein heating the portion comprises heating the pyrolysis zone such that a thermal conductivity of at least a portion of the pyrolysis zone is greater than about 0.5 W/(m °

C.).

979. The method of claim 962, further comprising controlling a pressure within at least a majority of the pyrolysis zone of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

980. The method of claim 962, further comprising:

providing hydrogen (H₂) to the pyrolysis zone to hydrogenate hydrocarbons within the pyrolysis zone; and

heating a portion of the pyrolysis zone with heat from hydrogenation.

981. The method of claim 962, wherein transferring generated heat comprises increasing a permeability of a majority of the pyrolysis zone to greater than about 100 millidarcy.

982. The method of claim 962, wherein transferring generated heat comprises substantially uniformly increasing a permeability of a majority of the pyrolysis zone.

983. The method of claim 962, wherein the heating is controlled to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

984. The method of claim 962, wherein the wellbore is located along strike to reduce pressure differentials along a heated length of the wellbore.

985. The method of claim 962, wherein the wellbore is located along strike to increase uniformity of heating along a heated length of the wellbore.

986. The method of claim 962, wherein the wellbore is located along strike to increase control of heating along a heated length of the wellbore.

987. A method of treating a hydrocarbon containing formation in situ, comprising:

heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidant;

flowing the oxidant into a conduit, and wherein the conduit is connected such that the oxidant can flow from the conduit to the hydrocarbons;

allowing the oxidant and the hydrocarbons to react to produce heat in a heater zone;

allowing heat to transfer from the heater zone to a pyrolysis zone in the formation to pyrolyze at least a portion of the hydrocarbons within the pyrolysis zone; and

removing reaction products such that the reaction products are inhibited from flowing from the heater zone to the pyrolysis zone.

988. The method of claim 987, wherein heating the portion of the formation comprises raising the temperature of the portion above about 400°

C.

989. The method of claim 987, wherein heating the portion of the formation comprises electrically heating the formation.

990. The method of claim 987, wherein heating the portion of the formation comprises heating the portion using exhaust gases from a surface burner.

991. The method of claim 987, wherein the conduit comprises critical flow orifices, the method further comprising flowing the oxidant through the critical flow orifices to the heater zone.

992. The method of claim 987, wherein the conduit is located within a wellbore, wherein removing reaction products comprises removing reaction products from the heater zone through the wellbore.

993. The method of claim 987, further comprising removing excess oxidant from the heater zone to inhibit transport of the oxidant to the pyrolysis zone.

994. The method of claim 987, further comprising transporting the oxidant from the conduit to the heater zone substantially by diffusion.

995. The method of claim 987, wherein the conduit is located within a wellbore, the method further comprising heating the conduit with reaction products being removed through the wellbore to raise a temperature of the oxidant passing through the conduit.

996. The method of claim 987, wherein the oxidant comprises hydrogen peroxide.

997. The method of claim 987, wherein the oxidant comprises air.

998. The method of claim 987, wherein the oxidant comprises a fluid substantially free of nitrogen.

999. The method of claim 987, further comprising limiting an amount of oxidant to maintain a temperature of the heater zone less than about 1200°

C.

1000. The method of claim 987, further comprising limiting an amount of oxidant to maintain a temperature of the heater zone at a temperature that inhibits production of oxides of nitrogen.

1001. The method of claim 987, wherein heating a portion of the formation to a temperature sufficient to support oxidation of hydrocarbons within the portion further comprises heating with a flameless distributed combustor.

1002. The method of claim 987, further comprising controlling a pressure and a temperature within at least a majority of the pyrolysis zone of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1003. The method of claim 987, further comprising controlling the heat such that an average heating rate of the pyrolysis zone is less than about 1°

C. per day during pyrolysis.

1004. The method of claim 987, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1005. The method of claim 987, wherein allowing heat to transfer comprises heating the pyrolysis zone such that a thermal conductivity of at least a portion of the pyrolysis zone is greater than about 0.5 W/(m °

C.).

1006. The method of claim 987, further comprising controlling a pressure within at least a majority of the pyrolysis zone, wherein the controlled pressure is at least about 2.0 bars absolute.

1007. The method of claim 987, further comprising:

providing hydrogen (H₂) to the pyrolysis zone to hydrogenate hydrocarbons within the pyrolysis zone; and

heating a portion of the pyrolysis zone with heat from hydrogenation.

1008. The method of claim 987, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the pyrolysis zone to greater than about 100 millidarcy.

1009. The method of claim 987, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the pyrolysis zone.

1010. The method of claim 987, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1011. An in situ method for heating a hydrocarbon containing formation, comprising:

heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidizing fluid, wherein the portion is located substantially adjacent to an opening in the formation;

providing the oxidizing fluid to a heater zone in the formation;

allowing the oxidizing gas to react with at least a portion of the hydrocarbons at the heater zone to generate heat in the heater zone; and

transferring the generated heat substantially by conduction from the heater zone to a pyrolysis zone in the formation.

1012. The method of claim 1011, further comprising transporting the oxidizing fluid through the heater zone by diffusion.

1013. The method of claim 1011, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a conduit disposed in the opening.

1014. The method of claim 1011, further comprising controlling a flow of the oxidizing fluid with critical flow orifices of a conduit disposed in the opening such that a rate of oxidation is controlled.

1015. The method of claim 1011, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit.

1016. The method of claim 1011, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and transferring substantial heat from the oxidation product in the conduit to the oxidizing fluid in the conduit.

1017. The method of claim 1011, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

1018. The method of claim 1011, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and controlling a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.

1019. The method of claim 1011, wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the outer conduit.

1020. The method of claim 1011, wherein the heater zone extends radially from the opening a width of less than approximately 0.15 m.

1021. The method of claim 1011, wherein heating the portion comprises applying electrical current to an electric heater disposed within the opening.

1022. The method of claim 1011, wherein the pyrolysis zone is substantially adjacent to the heater zone.

1023. The method of claim 1011, further comprising controlling a pressure and a temperature within at least a majority of the pyrolysis zone of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1024. The method of claim 1011, further comprising controlling the heat such that an average heating rate of the pyrolysis zone is less than about 1°

C. per day during pyrolysis.

1025. The method of claim 1011, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1026. The method of claim 1011, wherein allowing heat to transfer comprises heating the portion such that a thermal conductivity of at least a portion of the pyrolysis zone is greater than about 0.5 W/(m °

C.).

1027. The method of claim 1011, further comprising controlling a pressure within at least a majority of the pyrolysis zone, wherein the controlled pressure is at least about 2.0 bars absolute.

1028. The method of claim 1011, further comprising:

providing hydrogen (H₂) to the pyrolysis zone to hydrogenate hydrocarbons within the pyrolysis zone; and

heating a portion of the pyrolysis zone with heat from hydrogenation.

1029. The method of claim 1011, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the pyrolysis zone to greater than about 100 millidarcy.

1030. The method of claim 1011, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the pyrolysis zone.

1031. The method of claim 1011, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1032. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

producing a mixture from the formation; and

maintaining an average temperature within the selected section above a minimum pyrolysis temperature and below a vaporization temperature of hydrocarbons having carbon numbers greater than 25 to inhibit production of a substantial amount of hydrocarbons having carbon numbers greater than 25 in the mixture.

1033. The method of claim 1032, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1034. The method of claim 1032, wherein maintaining the average temperature within the selected section comprises maintaining the temperature within a pyrolysis temperature range.

1035. The method of claim 1032, wherein the one or more heaters comprise electrical heaters.

1036. The method of claim 1032, wherein the one or more heaters comprise surface burners.

1037. The method of claim 1032, wherein the one or more heaters comprise flameless distributed combustors.

1038. The method of claim 1032, wherein the one or more heaters comprise natural distributed combustors.

1039. The method of claim 1032, wherein the minimum pyrolysis temperature is greater than about 270°

C.

1040. The method of claim 1032, wherein the vaporization temperature is less than approximately 450°

C. at atmospheric pressure.

1041. The method of claim 1032, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1042. The method of claim 1032, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1043. The method of claim 1032, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1044. The method of claim 1032, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1045. The method of claim 1032, wherein providing heat from the one or more heaters comprises heating the selected formation such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1046. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1047. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1048. The method of claim 1032, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

1049. The method of claim 1032, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.

1050. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1051. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1052. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1053. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1054. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1055. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1056. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1057. The method of claim 1032, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1058. The method of claim 1032, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1059. The method of claim 1032, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1060. The method of claim 1032, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1061. The method of claim 1032, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1062. The method of claim 1032, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1063. The method of claim 1062, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

1064. The method of claim 1032, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

1065. The method of claim 1032, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1066. The method of claim 1032, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1067. The method of claim 1032, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1068. The method of claim 1032, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1069. The method of claim 1032, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1070. The method of claim 1032, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1071. The method of claim 1070, wherein at least about 20 heaters are disposed in the formation for each production well.

1072. The method of claim 1032, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1073. The method of claim 1032, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1074. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

controlling a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than 25; and

producing a mixture from the formation.

1075. The method of claim 1074, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1076. The method of claim 1074, wherein the one or more heaters comprise electrical heaters.

1077. The method of claim 1074, wherein the one or more heaters comprise surface burners.

1078. The method of claim 1074, wherein the one or more heaters comprise flameless distributed combustors.

1079. The method of claim 1074, wherein the one or more heaters comprise natural distributed combustors.

1080. The method of claim 1074, further comprising controlling a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1081. The method of claim 1080, wherein controlling the temperature comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

1082. The method of claim 1074, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1083. The method of claim 1074, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1084. The method of claim 1074, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1085. The method of claim 1074, wherein providing heat from the one or more heaters comprises heating the selected formation such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1086. The method of claim 1074, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1087. The method of claim 1074, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1088. The method of claim 1074, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

1089. The method of claim 1074, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.

1090. The method of claim 1074, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1091. The method of claim 1074, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1092. The method of claim 1074, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1093. The method of claim 1074, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1094. The method of claim 1074, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1095. The method of claim 1074, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1096. The method of claim 1074, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1097. The method of claim 1074, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1098. The method of claim 1074, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1099. The method of claim 1074, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1100. The method of claim 1074, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1101. The method of claim 1074, further comprising controlling the pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1102. The method of claim 1074, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1103. The method of claim 1102, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

1104. The method of claim 1074, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

1105. The method of claim 1074, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1106. The method of claim 1074, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1107. The method of claim 1074, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1108. The method of claim 1074, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1109. The method of claim 1074, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1110. The method of claim 1074, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1111. The method of claim 1110, wherein at least about 20 heaters are disposed in the formation for each production well.

1112. The method of claim 1074, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1113. The method of claim 1074, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1114. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1115. The method of claim 1114, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1116. The method of claim 1114, wherein the one or more heaters comprise electrical heaters.

1117. The method of claim 1114, wherein the one or more heaters comprise surface burners.

1118. The method of claim 1114, wherein the one or more heaters comprise flameless distributed combustors.

1119. The method of claim 1114, wherein the one or more heaters comprise natural distributed combustors.

1120. The method of claim 1114, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1121. The method of claim 1114, wherein controlling the temperature comprises maintaining the temperature within the selected section within a pyrolysis temperature range.

1122. The method of claim 1114, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1123. The method of claim 1114, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

/day.

1124. The method of claim 1114, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1125. The method of claim 1114, wherein providing heat from the one or more heaters comprises heating the selected formation such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1126. The method of claim 1114, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1127. The method of claim 1114, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1128. The method of claim 1114, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

1129. The method of claim 1114, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.

1130. The method of claim 1114, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1131. The method of claim 1114, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1132. The method of claim 1114, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1133. The method of claim 1114, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1134. The method of claim 1114, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1135. The method of claim 1114, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1136. The method of claim 1114, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1137. The method of claim 1114, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1138. The method of claim 1114, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1139. The method of claim 1114, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1140. The method of claim 1114, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1141. The method of claim 1114, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1142. The method of claim 1114, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1143. The method of claim 1142, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

1144. The method of claim 1114, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1145. The method of claim 1114, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

1146. The method of claim 1114, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1147. The method of claim 1114, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1148. The method of claim 1114, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1149. The method of claim 1114, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1150. The method of claim 1114, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1151. The method of claim 1114, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1152. The method of claim 1151, wherein at least about 20 heaters are disposed in the formation for each production well.

1153. The method of claim 1114, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1154. The method of claim 1114, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1155. A method of treating a hydrocarbon containing formation in situ, comprising:

heating a section of the formation to a pyrolysis temperature from at least a first heater, a second heater and a third heater, and wherein the first heater, the second heater and the third heater are located along a perimeter of the section;

controlling heat input to the first heater, the second heater and the third heater to limit a heating rate of the section to a rate configured to produce a mixture from the formation with an olefin content of less than about 15% by weight of condensable fluids (on a dry basis) within the produced mixture; and

producing the mixture from the formation through a production well.

1156. The method of claim 1155, wherein superposition of heat form the first heater, second heater, and third heater pyrolyzes a portion of the hydrocarbons within the formation to fluids.

1157. The method of claim 1155, wherein the pyrolysis temperature is between about 270°

C. and about 400°

C.

1158. The method of claim 1155, wherein the first heater is operated for less than about twenty four hours a day.

1159. The method of claim 1155, wherein the first heater comprises an electrical heater.

1160. The method of claim 1155, wherein the first heater comprises a surface burner.

1161. The method of claim 1155, wherein the first heater comprises a flameless distributed combustor.

1162. The method of claim 1155, wherein the first heater, second heater and third heater are positioned substantially at apexes of an equilateral triangle.

1163. The method of claim 1155, wherein the production well is located substantially at a geometrical center of the first heater, second heater, and third heater.

1164. The method of claim 1155, further comprising a fourth heater, fifth heater, and sixth heater located along the perimeter of the section.

1165. The method of claim 1164, wherein the heaters are located substantially at apexes of a regular hexagon.

1166. The method of claim 1165, wherein the production well is located substantially at a center of the hexagon.

1167. The method of claim 1155, further comprising controlling a pressure and a temperature within at least a majority of the section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1168. The method of claim 1155, wherein controlling the temperature comprises maintaining the temperature within the selected section within a pyrolysis temperature range.

1169. The method of claim 1155, further comprising controlling the heat such that an average heating rate of the section is less than about 3°

C. per day during pyrolysis.

1170. The method of claim 1155, further comprising controlling the heat such that an average heating rate of the section is less than about 1°

C. per day during pyrolysis.

1171. The method of claim 1155, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1172. The method of claim 1155, wherein heating the section of the formation comprises transferring heat substantially by conduction.

1173. The method of claim 1155, wherein providing heat from the one or more heaters comprises heating the section such that a thermal conductivity of at least a portion of the section is greater than about 0.5 W/(m °

C.).

1174. The method of claim 1155, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1175. The method of claim 1155, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1176. The method of claim 1155, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.

1177. The method of claim 1155, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1178. The method of claim 1155, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1179. The method of claim 1155, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1180. The method of claim 1155, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1181. The method of claim 1155, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1182. The method of claim 1155, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1183. The method of claim 1155, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1184. The method of claim 1155, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1185. The method of claim 1155, wherein the produced mixture comprises anon-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1186. The method of claim 1155, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1187. The method of claim 1155, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1188. The method of claim 1155, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1189. The method of claim 1155, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1190. The method of claim 1189, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

1191. The method of claim 1155, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1192. The method of claim 1155, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

1193. The method of claim 1155, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1194. The method of claim 1155, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1195. The method of claim 1155, wherein heating the section comprises increasing a permeability of a majority of the section to greater than about 100 millidarcy.

1196. The method of claim 1155, wherein heating the section comprises substantially uniformly increasing a permeability of a majority of the section.

1197. The method of claim 1155, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1198. The method of claim 1155, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1199. The method of claim 1198, wherein at least about 20 heaters are disposed in the formation for each production well.

1200. The method of claim 1155, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1201. The method of claim 1155, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1202. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1203. The method of claim 1202, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1204. The method of claim 1202, wherein the one or more heaters comprise electrical heaters.

1205. The method of claim 1202, wherein the one or more heaters comprise surface burners.

1206. The method of claim 1202, wherein the one or more heaters comprise flameless distributed combustors.

1207. The method of claim 1202, wherein the one or more heaters comprise natural distributed combustors.

1208. The method of claim 1202, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1209. The method of claim 1208, wherein controlling the temperature comprises maintaining the temperature within the selected section within a pyrolysis temperature range.

1210. The method of claim 1202, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1211. The method of claim 1202, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1212. The method of claim 1202, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1213. The method of claim 1202, wherein providing heat from the one or more heaters comprises heating the selected formation such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1214. The method of claim 1202, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1215. The method of claim 1202, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1216. The method of claim 1202, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0. 1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

1217. The method of claim 1202, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.

1218. The method of claim 1202, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1219. The method of claim 1202, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1220. The method of claim 1202, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1221. The method of claim 1202, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1222. The method of claim 1202, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1223. The method of claim 1202, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1224. The method of claim 1202, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1225. The method of claim 1202, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1226. The method of claim 1202, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1227. The method of claim 1202, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1228. The method of claim 1202, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1229. The method of claim 1202, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1230. The method of claim 1229, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

1231. The method of claim 1202, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1232. The method of claim 1202, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

1233. The method of claim 1202, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1234. The method of claim 1202, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1235. The method of claim 1202, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1236. The method of claim 1202, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1237. The method of claim 1202, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1238. The method of claim 1202, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1239. The method of claim 1238, wherein at least about 20 heaters are disposed in the formation for each production well.

1240. The method of claim 1202, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1241. The method of claim 1202, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1242. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of is the formation; and

producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1243. The method of claim 1242, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1244. The method of claim 1242, wherein the one or more heaters comprise electrical heaters.

1245. The method of claim 1242, wherein the one or more heaters comprise surface burners.

1246. The method of claim 1242, wherein the one or more heaters comprise flameless distributed combustors.

1247. The method of claim 1242, wherein the one or more heaters comprise natural distributed combustors.

1248. The method of claim 1242, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1249. The method of claim 1248, wherein controlling the temperature comprises maintaining the temperature within the selected section within a pyrolysis temperature range.

1250. The method of claim 1242, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1251. The method of claim 1242, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1252. The method of claim 1242, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1253. The method of claim 1242, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1254. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 250.

1255. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1256. The method of claim 1242, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

1257. The method of claim 1242, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.

1258. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1259. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1260. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1261. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1262. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1263. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1264. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1265. The method of claim 1242, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1266. The method of claim 1242, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1267. The method of claim 1242, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1268. The method of claim 1242, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1269. The method of claim 1242, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1270. The method of claim 1242, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1271. The method of claim 1270, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

1272. The method of claim 1242, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1273. The method of claim 1242, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

1274. The method of claim 1242, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1275. The method of claim 1242, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1276. The method of claim 1242, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1277. The method of claim 1242, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1278. The method of claim 1242, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1279. The method of claim 1242, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1280. The method of claim 1279, wherein at least about 20 heaters are disposed in the formation for each production well.

1281. The method of claim 1242, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1282. The method of claim 1242, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1283. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1284. The method of claim 1283, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1285. The method of claim 1283, wherein the one or more heaters comprise electrical heaters.

1286. The method of claim 1283, wherein the one or more heaters comprise surface burners.

1287. The method of claim 1283, wherein the one or more heaters comprise flameless distributed combustors.

1288. The method of claim 1283, wherein the one or more heaters comprise natural distributed combustors.

1289. The method of claim 1283, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1290. The method of claim 1289, wherein controlling the temperature comprises maintaining the temperature within the selected section within a pyrolysis temperature range.

1291. The method of claim 1283, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1292. The method of claim 1283, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1293. The method of claim 1283, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1294. The method of claim 1283, wherein providing heat from the one or more heaters comprises heating the selected formation such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1295. The method of claim 1283, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1296. The method of claim 1283, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1297. The method of claim 1283, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

1298. The method of claim 1283, wherein the produced mixture comprises non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15, and wherein the ratio of ethene to ethane is greater than about 0.001.

1299. The method of claim 1283, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1300. The method of claim 1283, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1301. The method of claim 1283, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1302. The method of claim 1283, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1303. The method of claim 1283, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1304. The method of claim 1283, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1305. The method of claim 1283, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1306. The method of claim 1283, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1307. The method of claim 1283, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1308. The method of claim 1283, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1309. The method of claim 1283, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1310. The method of claim 1283, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1311. The method of claim 1310, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

1312. The method of claim 1283, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1313. The method of claim 1283, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

1314. The method of claim 1283, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1315. The method of claim 1283, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1316. The method of claim 1283, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1317. The method of claim 1283, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1318. The method of claim 1283, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1319. The method of claim 1283, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1320. The method of claim 1319, wherein at least about 20 heaters are disposed in the formation for each production well.

1321. The method of claim 1283, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1322. The method of claim 1283, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1323. A method of treating a hydrocarbon containing formation in situ, comprising:

raising a temperature of a first section of the formation with one or more heaters to a first pyrolysis temperature;

heating the first section to an upper pyrolysis temperature, wherein heat is supplied to the first section at a rate configured to inhibit olefin production;

producing a first mixture from the formation, wherein the first mixture comprises condensable hydrocarbons and H₂;

creating a second mixture from the first mixture, wherein the second mixture comprises a higher concentration of H₂ than the first mixture;

raising a temperature of a second section of the formation with one or more heaters to a second pyrolysis temperature;

providing a portion of the second mixture to the second section;

heating the second section to an upper pyrolysis temperature, wherein heat is supplied to the second section at a rate configured to inhibit olefin production; and

producing a third mixture from the second section.

1324. The method of claim 1323, wherein creating the second mixture comprises removing condensable hydrocarbons from the first mixture.

1325. The method of claim 1323, wherein creating the second mixture comprises removing water from the first mixture.

1326. The method of claim 1323, wherein creating the second mixture comprises removing carbon dioxide from the first mixture.

1327. The method of claim 1323, wherein the first pyrolysis temperature is greater than about 270°

C.

1328. The method of claim 1323, wherein the second pyrolysis temperature is greater than about 270°

.

1329. The method of claim 1323, wherein the upper pyrolysis temperature is about 500°

C.

1330. The method of claim 1323, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the first or second selected section of the formation.

1331. The method of claim 1323, wherein the one or more heaters comprise electrical heaters.

1332. The method of claim 1323, wherein the one or more heaters comprise surface burners.

1333. The method of claim 1323, wherein the one or more heaters comprise flameless distributed combustors.

1334. The method of claim 1323, wherein the one or more heaters comprise natural distributed combustors.

1335. The method of claim 1323, further comprising controlling a pressure and a temperature within at least a majority of the first section and the second section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1336. The method of claim 1323, further comprising controlling the heat to the first and second sections such that an average heating rate of the first and second sections is less than about 1°

C. per day during pyrolysis.

1337. The method of claim 1323, wherein heating the first and the second sections comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1338. The method of claim 1323, wherein heating the first and second sections comprises transferring heat substantially by conduction.

1339. The method of claim 1323, wherein heating the first and second sections comprises heating the first and second sections such that a thermal conductivity of at least a portion of the first and second sections is greater than about 0.5 W/(m °

C.).

1340. The method of claim 1323, wherein the first or third mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1341. The method of claim 1323, wherein the first or third mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1342. The method of claim 1323, wherein the first or third mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1343. The method of claim 1323, wherein the first or third mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1344. The method of claim 1323, wherein the first or third mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1345. The method of claim 1323, wherein the first or third mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1346. The method of claim 1323, wherein the first or third mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1347. The method of claim 1323, wherein the first or third mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1348. The method of claim 1323, wherein the first or third mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1349. The method of claim 1323, wherein the first or third mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1350. The method of claim 1323, wherein the first or third mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1351. The method of claim 1323, wherein the first or third mixture comprises a non-condensable component, and wherein the non-condensable component comprises hydrogen, and wherein the hydrogen is greater than about 10% by volume of the non-condensable component and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1352. The method of claim 1323, wherein the first or third mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1353. The method of claim 1323, wherein the first or third mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1354. The method of claim 1323, further comprising controlling a pressure within at least a majority of the first or second sections of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1355. The method of claim 1323, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1356. The method of claim 1355, wherein the partial pressure of H₂ within a mixture is measured when the mixture is at a production well.

1357. The method of claim 1323, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1358. The method of claim 1323, further comprising:

providing hydrogen (H₂) to the first or second section to hydrogenate hydrocarbons within the first or second section; and

heating a portion of the first or second section with heat from hydrogenation.

1359. The method of claim 1323, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1360. The method of claim 1323, further comprising increasing a permeability of a majority of the first or second section to greater than about 100 millidarcy.

1361. The method of claim 1323, further comprising substantially uniformly increasing a permeability of a majority of the first or second section.

1362. The method of claim 1323, wherein the heating is controlled to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1363. The method of claim 1323, wherein producing the first or third mixture comprises producing the first or third mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1364. The method of claim 1363, wherein at least about 20 heaters are disposed in the formation for each production well.

1365. The method of claim 1323, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1366. The method of claim 1323, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1367. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

producing a mixture from the formation; and

hydrogenating a portion of the produced mixture with H₂ produced from the formation.

1368. The method of claim 1367, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1369. The method of claim 1367, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

1370. The method of claim 1367, wherein the one or more heaters comprise electrical heaters.

1371. The method of claim 1367, wherein the one or more heaters comprise surface burners.

1372. The method of claim 1367, wherein the one or more heaters comprise flameless distributed combustors.

1373. The method of claim 1367, wherein the one or more heaters comprise natural distributed combustors.

1374. The method of claim 1367, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1375. The method of claim 1367, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1376. The method of claim 1367, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1377. The method of claim 1367, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1378. The method of claim 1367, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1379. The method of claim 1367, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1380. The method of claim 1367, wherein the produced mixture comprises condensable no hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1381. The method of claim 1367, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1382. The method of claim 1367, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1383. The method of claim 1367, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1384. The method of claim 1367, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1385. The method of claim 1367, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1386. The method of claim 1367, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1387. The method of claim 1367, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1388. The method of claim 1367, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1389. The method of claim 1367, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1390. The method of claim 1367, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1391. The method of claim 1367, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1392. The method of claim 1367, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1393. The method of claim 1367, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1394. The method of claim 1367, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1395. The method of claim 1367, wherein a partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

1396. The method of claim 1367, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1397. The method of claim 1367, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1398. The method of claim 1367, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1399. The method of claim 1367, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1400. The method of claim 1367, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1401. The method of claim 1367, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1402. The method of claim 1401, wherein at least about 20 heaters are disposed in the formation for each production well.

1403. The method of claim 1367, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1404. The method of claim 1367, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1405. A method of treating a hydrocarbon containing formation in situ, comprising:

heating a first section of the formation;

producing H₂ from the first section of formation;

heating a second section of the formation; and

recirculating a portion of the H₂ from the first section into the second section of the formation to provide a reducing environment within the second section of the formation.

1406. The method of claim 1405, wherein heating the first section or heating the second section comprises heating with an electrical heater.

1407. The method of claim 1405, wherein heating the first section or heating the second section comprises heating with a surface burner.

1408. The method of claim 1405, wherein heating the first section or heating the second section comprises heating with a flameless distributed combustor.

1409. The method of claim 1405, wherein heating the first section or heating the second section comprises heating with a natural distributed combustor.

1410. The method of claim 1405, further comprising controlling a pressure and a temperature within at least a majority of the first or second section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1411. The method of claim 1405, further comprising controlling the heat such that an average heating rate of the first or second section is less than about 1°

C. per day during pyrolysis.

1412. The method of claim 1405, wherein heating the first section or heating the second section further comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1413. The method of claim 1405, wherein heating the first section or heating the second section comprises transferring heat substantially by conduction.

1414. The method of claim 1405, wherein heating the first section or heating the second section comprises heating the formation such that a thermal conductivity of at least a portion of the first or second section is greater than about 0.5 W/(m °

C.).

1415. The method of claim 1405, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 250.

1416. The method of claim 1405, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1417. The method of claim 1405, further comprising producing a mixture from the second section, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1418. The method of claim 1405, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1419. The method of claim 1405, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1420. The method of claim 1405, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1421. The method of claim 1405, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1422. The method of claim 1405, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1423. The method of claim 1405, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1424. The method of claim 1405, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1425. The method of claim 1405, further comprising producing a mixture from the second section, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1426. The method of claim 1405, further comprising producing a mixture from the second section, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1427. The method of claim 1405, further comprising producing a mixture from the second section, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1428. The method of claim 1405, further comprising producing a mixture from the second section, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1429. The method of claim 1405, further comprising controlling a pressure within at least a majority of the first or second section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1430. The method of claim 1405, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1431. The method of claim 1430, wherein the partial pressure of H₂ within a mixture is measured when the mixture is at a production well.

1432. The method of claim 1405, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1433. The method of claim 1405, further comprising:

providing hydrogen (H₂) to the second section to hydrogenate hydrocarbons within the section; and

heating a portion of the second section with heat from hydrogenation.

1434. The method of claim 1405, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1435. The method of claim 1405, wherein heating the first section or heating the second section comprises increasing a permeability of a majority of the first or second section, respectively, to greater than about 100 millidarcy.

1436. The method of claim 1405, wherein heating the first section or heating the second section comprises substantially uniformly increasing a permeability of a majority of the first or second section, respectively.

1437. The method of claim 1405, further comprising controlling the heating of the first section or controlling the heat of the second section to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1438. The method of claim 1405, further comprising producing a mixture from the formation in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1439. The method of claim 1438, wherein at least about 20 heaters are disposed in the formation for each production well.

1440. The method of claim 1405, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1441. The method of claim 1405, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1442. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

producing a mixture from the formation; and

controlling formation conditions such that the mixture produced from the formation comprises condensable hydrocarbons including H₂, wherein the partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1443. The method of claim 1442, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1444. The method of claim 1442, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

1445. The method of claim 1442, wherein the one or more heaters comprise electrical heaters.

1446. The method of claim 1442, wherein the one or more heaters comprise surface burners.

1447. The method of claim 1442, wherein the one or more heaters comprise flameless distributed combustors.

1448. The method of claim 1442, wherein the one or more heaters comprise natural distributed combustors.

1449. The method of claim 1442, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1450. The method of claim 1442, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1451. The method of claim 1442, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1452. The method of claim 1442, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1453. The method of claim 1442, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1454. The method of claim 1442, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1455. The method of claim 1442, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1456. The method of claim 1442, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1457. The method of claim 1442, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1458. The method of claim 1442, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1459. The method of claim 1442, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1460. The method of claim 1442, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1461. The method of claim 1442, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1462. The method of claim 1442, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1463. The method of claim 1442, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1464. The method of claim 1442, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1465. The method of claim 1442, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1466. The method of claim 1442, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1467. The method of claim 1442, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1468. The method of claim 1442, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1469. The method of claim 1442, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1470. The method of claim 1442, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

1471. The method of claim 1442, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1472. The method of claim 1442, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1473. The method of claim 1442, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1474. The method of claim 1442, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1475. The method of claim 1442, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1476. The method of claim 1442, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1477. The method of claim 1442, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1478. The method of claim 1442, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1479. The method of claim 1442, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

1480. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

maintaining a pressure of the selected section above atmospheric pressure to increase a partial pressure of H₂, as compared to the partial pressure of H₂ at atmospheric pressure, in at least a majority of the selected section; and

producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1481. The method of claim 1480, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1482. The method of claim 1480, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

1483. The method of claim 1480, wherein the one or more heaters comprise electrical heaters.

1484. The method of claim 1480, wherein the one or more heaters comprise surface burners.

1485. The method of claim 1480, wherein the one or more heaters comprise flameless distributed combustors.

1486. The method of claim 1480, wherein the one or more heaters comprise natural distributed combustors.

1487. The method of claim 1480, further comprising controlling the pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1488. The method of claim 1480, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1489. The method of claim 1480, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1490. The method of claim 1480, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1491. The method of claim 1480, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1492. The method of claim 1480, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1493. The method of claim 1480, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1494. The method of claim 1480, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1495. The method of claim 1480, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1496. The method of claim 1480, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1497. The method of claim 1480, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1498. The method of claim 1480, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1499. The method of claim 1480, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1500. The method of claim 1480, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1501. The method of claim 1480, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1502. The method of claim 1480, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1503. The method of claim 1480, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1504. The method of claim 1480, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1505. The method of claim 1480, further comprising controlling the pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1506. The method of claim 1480, further comprising increasing the pressure of the selected section, to an upper limit of about 21 bars absolute, to increase an amount of non-condensable hydrocarbons produced from the formation.

1507. The method of claim 1480, farther comprising decreasing pressure of the selected section, to a lower limit of about atmospheric pressure, to increase an amount of condensable hydrocarbons produced from the formation.

1508. The method of claim 1480, wherein the partial pressure comprises a partial pressure based on properties measured at a production well.

1509. The method of claim 1480, further comprising altering the pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1510. The method of claim 1480, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

1511. The method of claim 1480, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1512. The method of claim 1480, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1513. The method of claim 1480, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1514. The method of claim 1480, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1515. The method of claim 1480, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1516. The method of claim 1480, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1517. The method of claim 1516, wherein at least about 20 heaters are disposed in the formation for each production well.

1518. The method of claim 1480, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1519. The method of claim 1480, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1520. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing H₂ to the formation to produce a reducing environment in at least some of the formation;

producing a mixture from the formation.

1521. The method of claim 1520, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1522. The method of claim 1520, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

1523. The method of claim 1520, further comprising separating a portion of hydrogen within the mixture and recirculating the portion into the formation.

1524. The method of claim 1520, wherein the one or more heaters comprise electrical heaters.

1525. The method of claim 1520, wherein the one or more heaters comprise surface burners.

1526. The method of claim 1520, wherein the one or more heaters comprise flameless distributed combustors.

1527. The method of claim 1520, wherein the one or more heaters comprise natural distributed combustors.

1528. The method of claim 1520, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1529. The method of claim 1520, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1530. The method of claim 1520, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1531. The method of claim 1520, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1532. The method of claim 1520, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1533. The method of claim 1520, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1534. The method of claim 1520, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1535. The method of claim 1520, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1536. The method of claim 1520, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1537. The method of claim 1520, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1538. The method of claim 1520, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1539. The method of claim 1520, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1540. The method of claim 1520, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1541. The method of claim 1520, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1542. The method of claim 1520, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1543. The method of claim 1520, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1544. The method of claim 1520, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1545. The method of claim 1520, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1546. The method of claim 1520, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1547. The method of claim 1520, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1548. The method of claim 1520, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1549. The method of claim 1520, wherein a partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

1550. The method of claim 1520, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1551. The method of claim 1520, wherein providing hydrogen (H₂) to the formation further comprises:

hydrogenating hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1552. The method of claim 1520, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1553. The method of claim 1520, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1554. The method of claim 1520, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1555. The method of claim 1520, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1556. The method of claim 1520, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1557. The method of claim 1556, wherein at least about 20 heaters are disposed in the formation for each production well.

1558. The method of claim 1520, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1559. The method of claim 1520, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1560. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing H₂ to the selected section to hydrogenate hydrocarbons within the selected section and to heat a portion of the section with heat from the hydrogenation; and

controlling heating of the selected section by controlling amounts of H₂ provided to the selected section.

1561. The method of claim 1560, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1562. The method of claim 1560, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

1563. The method of claim 1560, wherein the one or more heaters comprise electrical heaters.

1564. The method of claim 1560, wherein the one or more heaters comprise surface burners.

1565. The method of claim 1560, wherein the one or more heaters comprise flameless distributed combustors.

1566. The method of claim 1560, wherein the one or more heaters comprise natural distributed combustors.

1567. The method of claim 1560, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1568. The method of claim 1560, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1569. The method of claim 1560, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1570. The method of claim 1560, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1571. The method of claim 1560, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1572. The method of claim 1560, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1573. The method of claim 1560, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1574. The method of claim 1560, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1575. The method of claim 1560, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1576. The method of claim 1560, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1577. The method of claim 1560, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1578. The method of claim 1560, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1579. The method of claim 1560, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1580. The method of claim 1560, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1581. The method of claim 1560, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1582. The method of claim 1560, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1583. The method of claim 1560, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component

1584. The method of claim 1560, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1585. The method of claim 1560, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1586. The method of claim 1560, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1587. The method of claim 1560, further comprising controlling formation conditions to produce a mixture from the formation, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1588. The method of claim 1587, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

1589. The method of claim 1560, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1590. The method of claim 1560, further comprising controlling formation conditions by recirculating a portion of hydrogen from a produced mixture into the formation.

1591. The method of claim 1560, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1592. The method of claim 1560, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1593. The method of claim 1560, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1594. The method of claim 1560, further comprising producing a mixture in a production well, wherein at least about 7 heaters are disposed in the formation for each production well.

1595. The method of claim 1594, wherein at least about 20 heaters are disposed in the formation for each production well.

1596. The method of claim 1560, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1597. The method of claim 1560, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1598. An in situ method for producing H₂ from a hydrocarbon containing formation, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

producing a mixture from the formation, wherein a H₂ partial pressure within the mixture is greater than about 0.5 bars.

1599. The method of claim 1598, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1600. The method of claim 1598, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

1601. The method of claim 1598, wherein the one or more heaters comprise electrical heaters.

1602. The method of claim 1598, wherein the one or more heaters comprise surface burners.

1603. The method of claim 1598, wherein the one or more heaters comprise flameless distributed combustors.

1604. The method of claim 1598, wherein the one or more heaters comprise natural distributed combustors.

1605. The method of claim 1598, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1606. The method of claim 1598, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1607. The method of claim 1598, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1608. The method of claim 1598, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1609. The method of claim 1598, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1610. The method of claim 1598, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1611. The method of claim 1598, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1612. The method of claim 1598, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1613. The method of claim 1598, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1614. The method of claim 1598, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1615. The method of claim 1598, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur

1616. The method of claim 1598, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1617. The method of claim 1598, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1618. The method of claim 1598, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1619. The method of claim 1598, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1620. The method of claim 1598, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1621. The method of claim 1598, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1622. The method of claim 1598, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1623. The method of claim 1598, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1624. The method of claim 1598, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1625. The method of claim 1598, fturther comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1626. The method of claim 1598, further comprising recirculating a portion of the hydrogen within the mixture into the formation.

1627. The method of claim 1598, further comprising condensing a hydrocarbon component from the produced mixture and hydrogenating the condensed hydrocarbons with a portion of the hydrogen.

1628. The method of claim 1598, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1629. The method of claim 1598, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1630. The method of claim 1598, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1631. The method of claim 1598, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1632. The method of claim 1598, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1633. The method of claim 1632, wherein at least about 20 heaters are disposed in the formation for each production well.

1634. The method of claim 1598, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1635. The method of claim 1598, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1636. The method of claim 1598, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

1637. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

wherein the selected section has been selected for heating using an atomic hydrogen weight percentage of at least a portion of hydrocarbons in the selected section, and wherein at least the portion of the hydrocarbons in the selected section comprises an atomic hydrogen weight percentage, when measured on a dry, ash-free basis, of greater than about 4.0%; and

producing a mixture from the formation.

1638. The method of claim 1637, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1639. The method of claim 1637, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

1640. The method of claim 1637, wherein the one or more heaters comprise electrical heaters.

1641. The method of claim 1637, wherein the one or more heaters comprise surface burners.

1642. The method of claim 1637, wherein the one or more heaters comprise flameless distributed combustors.

1643. The method of claim 1637, wherein the one or more heaters comprise natural distributed combustors.

1644. The method of claim 1637, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1645. The method of claim 1637, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1646. The method of claim 1637, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1647. The method of claim 1637, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1648. The method of claim 1637, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1649. The method of claim 1637, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1650. The method of claim 1637, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1651. The method of claim 1637, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1652. The method of claim 1637, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1653. The method of claim 1637, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1654. The method of claim 1637, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1655. The method of claim 1637, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1656. The method of claim 1637, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1657. The method of claim 1637, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1658. The method of claim 1637, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1659. The method of claim 1637, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1660. The method of claim 1637, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1661. The method of claim 1637, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1662. The method of claim 1637, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1663. The method of claim 1637, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1664. The method of claim 1637, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1665. The method of claim 1664, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

1666. The method of claim 1637, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1667. The method of claim 1637, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

1668. The method of claim 1637, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1669. The method of claim 1637, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1670. The method of claim 1637, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1671. The method of claim 1637, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1672. The method of claim 1637, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1673. The method of claim 1637, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1674. The method of claim 1673, wherein at least about 20 heaters are disposed in the formation for each production well.

1675. The method of claim 1637, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1676. The method of claim 1637, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1677. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

wherein at least some hydrocarbons within the selected section have an initial atomic hydrogen weight percentage of greater than about 4.0%; and

producing a mixture from the formation.

1678. The method of claim 1677, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1679. The method of claim 1677, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

1680. The method of claim 1677, wherein the one or more heaters comprise electrical heaters.

1681. The method of claim 1677, wherein the one or more heaters comprise surface burners.

1682. The method of claim 1677, wherein the one or more heaters comprise flameless distributed combustors.

1683. The method of claim 1677, wherein the one or more heaters comprise natural distributed combustors.

1684. The method of claim 1677, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1685. The method of claim 1677, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1686. The method of claim 1677, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1687. The method of claim 1677, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1688. The method of claim 1677, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1689. The method of claim 1677, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1690. The method of claim 1677, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1691. The method of claim 1677, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1692. The method of claim 1677, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1693. The method of claim 1677, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1694. The method of claim 1677, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1695. The method of claim 1677, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1696. The method of claim 1677, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1697. The method of claim 1677, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1698. The method of claim 1677, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1699. The method of claim 1677, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1700. The method of claim 1677, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1701. The method of claim 1677, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1702. The method of claim 1677, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1703. The method of claim 1677, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1704. The method of claim 1677, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1705. The method of claim 1704, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

1706. The method of claim 1677, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1707. The method of claim 1677, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

1708. The method of claim 1677, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1709. The method of claim 1677, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1710. The method of claim 1677, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1711. The method of claim 1677, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1712. The method of claim 1677, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1713. The method of claim 1677, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1714. The method of claim 1713, wherein at least about 20 heaters are disposed in the formation for each production well.

1715. The method of claim 1677, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1716. The method of claim 1677, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1717. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

wherein the selected section has been selected for heating using vitrinite reflectance of at least some hydrocarbons in the selected section, and wherein at least a portion of the hydrocarbons in the selected section comprises a vitrinite reflectance of greater than about 0.3%;

wherein at least a portion of the hydrocarbons in the selected section comprises a vitrinite reflectance of less than about 4.5%; and

producing a mixture from the formation.

1718. The method of claim 1717, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1719. The method of claim 1717, further comprising maintaining a temperature within the selected section within a pyrolysis temperature.

1720. The method of claim 1717, wherein the vitrinite reflectance of at least the portion of hydrocarbons within the selected section is between about 0.47% and about 1.5% such that a majority of the produced mixture comprises condensable hydrocarbons.

1721. The method of claim 1717, wherein the vitrinite reflectance of at least the portion of hydrocarbons within the selected section is between about 1.4% and about 4.2% such that a majority of the produced mixture comprises non-condensable hydrocarbons.

1722. The method of claim 1717, wherein the one or more heaters comprise electrical heaters.

1723. The method of claim 1717, wherein the one or more heaters comprise surface burners.

1724. The method of claim 1717, wherein the one or more heaters comprise flameless distributed combustors.

1725. The method of claim 1717, wherein the one or more heaters comprise natural distributed combustors.

1726. The method of claim 1717, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1727. The method of claim 1717, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1728. The method of claim 1717, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1729. The method of claim 1717, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1730. The method of claim 1717, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1731. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 250.

1732. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1733. The method of claim 1717, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1734. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1735. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1736. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1737. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1738. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1739. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1740. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1741. The method of claim 1717, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1742. The method of claim 1717, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1743. The method of claim 1717, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1744. The method of claim 1717, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1745. The method of claim 1717, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1746. The method of claim 1717, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1747. The method of claim 1746, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

1748. The method of claim 1717, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1749. The method of claim 1717, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

1750. The method of claim 1717, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1751. The method of claim 1717, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1752. The method of claim 1717, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1753. The method of claim 1717, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1754. The method of claim 1717, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1755. The method of claim 1717, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1756. The method of claim 1755, wherein at least about 20 heaters are disposed in the formation for each production well.

1757. The method of claim 1717, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1758. The method of claim 1717, fturther comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1759. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

wherein the selected section has been selected for heating using a total organic matter weight percentage of at least a portion of the selected section, and wherein at least the portion of the selected section comprises a total organic matter weight percentage, of at least about 5.0%; and

producing a mixture from the formation.

1760. The method of claim 1759, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1761. The method of claim 1759, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

1762. The method of claim 1759, wherein the one or more heaters comprise electrical heaters.

1763. The method of claim 1759, wherein the one or more heaters comprise surface burners.

1764. The method of claim 1759, wherein the one or more heaters comprise flameless distributed combustors.

1765. The method of claim 1759, wherein the one or more heaters comprise natural distributed combustors.

1766. The method of claim 1759, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1767. The method of claim 1759, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1768. The method of claim 1759, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1769. The method of claim 1759, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1770. The method of claim 1759, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1771. The method of claim 1759, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1772. The method of claim 1759, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1773. The method of claim 1759, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1774. The method of claim 1759, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1775. The method of claim 1759, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1776. The method of claim 1759, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1777. The method of claim 1759, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1778. The method of claim 1759, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1779. The method of claim 1759, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1780. The method of claim 1759, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1781. The method of claim 1759, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1782. The method of claim 1759, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1783. The method of claim 1759, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1784. The method of claim 1759, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1785. The method of claim 1759, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1786. The method of claim 1759, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1787. The method of claim 1786, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

1788. The method of claim 1759, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1789. The method of claim 1759, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

1790. The method of claim 1759, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1791. The method of claim 1759, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1792. The method of claim 1759, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1793. The method of claim 1759, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1794. The method of claim 1759, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1795. The method of claim 1759, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1796. The method of claim 1795, wherein at least about 20 heaters are disposed in the formation for each production well.

1797. The method of claim 1759, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1798. The method of claim 1759, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1799. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

wherein at least some hydrocarbons within the selected section have an initial total organic matter weight percentage of at least about 5.0%; and

producing a mixture from the formation.

1800. The method of claim 1799, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1801. The method of claim 1799, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

1802. The method of claim 1799, wherein the one or more heaters comprise electrical heaters.

1803. The method of claim 1799, wherein the one or more heaters comprise surface burners.

1804. The method of claim 1799, wherein the one or more heaters comprise flameless distributed combustors.

1805. The method of claim 1799, wherein the one or more heaters comprise natural distributed combustors.

1806. The method of claim 1799, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1807. The method of claim 1799, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1808. The method of claim 1799, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1809. The method of claim 1799, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1810. The method of claim 1799, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1811. The method of claim 1799, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1812. The method of claim 1799, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1813. The method of claim 1799, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1814. The method of claim 1799, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1815. The method of claim 1799, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1816. The method of claim 1799, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1817. The method of claim 1799, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1818. The method of claim 1799, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1819. The method of claim 1799, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1820. The method of claim 1799, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1821. The method of claim 1799, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1822. The method of claim 1799, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1823. The method of claim 1799, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1824. The method of claim 1799, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1825. The method of claim 1799, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1826. The method of claim 1799, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1827. The method of claim 1826, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

1828. The method of claim 1799, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1829. The method of claim 1799, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

1830. The method of claim 1799, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1831. The method of claim 1799, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1832. The method of claim 1799, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1833. The method of claim 1799, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1834. The method of claim 1799, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1835. The method of claim 1799, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1836. The method of claim 1835, wherein at least about 20 heaters are disposed in the formation for each production well.

1837. The method of claim 1799, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1838. The method of claim 1799, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units

1839. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

wherein the selected section has been selected for heating using an atomic oxygen weight percentage of at least a portion of hydrocarbons in the selected section, and wherein at least a portion of the hydrocarbons in the selected section comprises an atomic oxygen weight percentage of less than about 15% when measured on a dry, ash free basis; and

producing a mixture from the formation.

1840. The method of claim 1839, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1841. The method of claim 1839, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

1842. The method of claim 1839, wherein the one or more heaters comprise electrical heaters.

1843. The method of claim 1839, wherein the one or more heaters comprise surface burners.

1844. The method of claim 1839, wherein the one or more heaters comprise flameless distributed combustors.

1845. The method of claim 1839, wherein the one or more heaters comprise natural distributed combustors.

1846. The method of claim 1839, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1847. The method of claim 1839, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1848. The method of claim 1839, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1849. The method of claim 1839, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1850. The method of claim 1839, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1851. The method of claim 1839, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1852. The method of claim 1839, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1853. The method of claim 1839, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1854. The method of claim 1839, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1855. The method of claim 1839, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1856. The method of claim 1839, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1857. The method of claim 1839, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1858. The method of claim 1839, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1859. The method of claim 1839, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1860. The method of claim 1839, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1861. The method of claim 1839, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1862. The method of claim 1839, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1863. The method of claim 1839, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1864. The method of claim 1839, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1865. The method of claim 1839, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1866. The method of claim 1839, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1867. The method of claim 1866, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

1868. The method of claim 1839, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1869. The method of claim 1839, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

1870. The method of claim 1839, fturther comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1871. The method of claim 1839, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1872. The method of claim 1839, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1873. The method of claim 1839, wherein allowing the heat to transfer further comprises substantially uniformly increasing a permeability of a majority of the selected section.

1874. The method of claim 1839, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1875. The method of claim 1839, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1876. The method of claim 1875, wherein at least about 20 heaters are disposed in the formation for each production well.

1877. The method of claim 1839, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1878. The method of claim 1839, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1879. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to a selected section of the formation;

allowing the heat to transfer from the one or more heaters to the selected section of the formation to pyrolyze hydrocarbon within the selected section;

wherein at least some hydrocarbons within the selected section have an initial atomic oxygen weight percentage of less than about 15%; and

producing a mixture from the formation.

1880. The method of claim 1879, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1881. The method of claim 1879, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

1882. The method of claim 1879, wherein the one or more heaters comprise electrical heaters.

1883. The method of claim 1879, wherein the one or more heaters comprise surface burners.

1884. The method of claim 1879, wherein the one or more heaters comprise flameless distributed combustors.

1885. The method of claim 1879, wherein the one or more heaters comprise natural distributed combustors.

1886. The method of claim 1879, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1887. The method of claim 1879, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

per day during pyrolysis.

1888. The method of claim 1879, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

/day.

1889. The method of claim 1879, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1890. The method of claim 1879, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1891. The method of claim 1879, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1892. The method of claim 1879, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1893. The method of claim 1879, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1894. The method of claim 1879, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1895. The method of claim 1879, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1896. The method of claim 1879, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1897. The method of claim 1879, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1898. The method of claim 1879, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1899. The method of claim 1879, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1900. The method of claim 1879, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1901. The method of claim 1879, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1902. The method of claim 1879, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1903. The method of claim 1879, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1904. The method of claim 1879, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1905. The method of claim 1879, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1906. The method of claim 1879, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1907. The method of claim 1906, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

1908. The method of claim 1879, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1909. The method of claim 1879, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

1910. The method of claim 1879, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1911. The method of claim 1879, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1912. The method of claim 1879, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1913. The method of claim 1879, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1914. The method of claim 1879, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1915. The method of claim 1879, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1916. The method of claim 1915, wherein at least about 20 heaters are disposed in the formation for each production well.

1917. The method of claim 1879, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1918. The method of claim 1879, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1919. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

wherein the selected section has been selected for heating using an atomic hydrogen to carbon ratio of at least a portion of hydrocarbons in the selected section, wherein at least a portion of the hydrocarbons in the selected section comprises an atomic hydrogen to carbon ratio greater than about 0.70, and wherein the atomic hydrogen to carbon ratio is less than about 1.65; and

producing a mixture from the formation.

1920. The method of claim 1919, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1921. The method of claim 1919, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

1922. The method of claim 1919, wherein the one or more heaters comprise electrical heaters.

1923. The method of claim 1919, wherein the one or more heaters comprise surface burners.

1924. The method of claim 1919, wherein the one or more heaters comprise flameless distributed combustors.

1925. The method of claim 1919, wherein the one or more heaters comprise natural distributed combustors.

1926. The method of claim 1919, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1927. The method of claim 1919, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1928. The method of claim 1919, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1929. The method of claim 1919, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1930. The method of claim 1919, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1931. The method of claim 1919, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1932. The method of claim 1919, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1933. The method of claim 1919, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1934. The method of claim 1919, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1935. The method of claim 1919, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1936. The method of claim 1919, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1937. The method of claim 1919, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1938. The method of claim 1919, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1939. The method of claim 1919, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1940. The method of claim 1919, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1941. The method of claim 1919, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1942. The method of claim 1919, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1943. The method of claim 1919, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1944. The method of claim 1919, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1945. The method of claim 1919, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1946. The method of claim 1919, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1947. The method of claim 1946, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

1948. The method of claim 1919, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1949. The method of claim 1919, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

1950. The method of claim 1919, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1951. The method of claim 1919, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1952. The method of claim 1919, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1953. The method of claim 1919, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1954. The method of claim 1919, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1955. The method of claim 1919, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1956. The method of claim 1955, wherein at least about 20 heaters are disposed in the formation for each production well.

1957. The method of claim 1919, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1958. The method of claim 1919, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1959. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to a selected section of the formation;

allowing the heat to transfer from the one or more heaters to the selected section of the formation to pyrolyze hydrocarbons within the selected section;

wherein at least some hydrocarbons within the selected section have an initial atomic hydrogen to carbon ratio greater than about 0.70;

wherein the initial atomic hydrogen to carbon ration is less than about 1.65; and

producing a mixture from the formation.

1960. The method of claim 1959, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

1961. The method of claim 1959, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

1962. The method of claim 1959, wherein the one or more heaters comprise electrical heaters.

1963. The method of claim 1959, wherein the one or more heaters comprise surface burners.

1964. The method of claim 1959, wherein the one or more heaters comprise flameless distributed combustors.

1965. The method of claim 1959, wherein the one or more heaters comprise natural distributed combustors.

1966. The method of claim 1959, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

1967. The method of claim 1959, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

1968. The method of claim 1959, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

1969. The method of claim 1959, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

1970. The method of claim 1959, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

1971. The method of claim 1959, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

1972. The method of claim 1959, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

1973. The method of claim 1959, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

1974. The method of claim 1959, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

1975. The method of claim 1959, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

1976. The method of claim 1959, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

1977. The method of claim 1959, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

1978. The method of claim 1959, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

1979. The method of claim 1959, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

1980. The method of claim 1959, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

1981. The method of claim 1959, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

1982. The method of claim 1959, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

1983. The method of claim 1959, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

1984. The method of claim 1959, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

1985. The method of claim 1959, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

1986. The method of claim 1959, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

1987. The method of claim 1986, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

1988. The method of claim 1959, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

1989. The method of claim 1959, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

1990. The method of claim 1959, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

1991. The method of claim 1959, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

1992. The method of claim 1959, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

1993. The method of claim 1959, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

1994. The method of claim 1959, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

1995. The method of claim 1959, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

1996. The method of claim 1995, wherein at least about 20 heaters are disposed in the formation for each production well.

1997. The method of claim 1959, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

1998. The method of claim 1959, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

1999. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

wherein the selected section has been selected for heating using an atomic oxygen to carbon ratio of at least a portion of hydrocarbons in the selected section, wherein at least a portion of the hydrocarbons in the selected section comprises an atomic oxygen to carbon ratio greater than about 0.025, and wherein the atomic oxygen to carbon ratio of at least a portion of the hydrocarbons in the selected section is less than about 0.15; and

producing a mixture from the formation.

2000. The method of claim 1999, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

2001. The method of claim 1999, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

2002. The method of claim 1999, wherein the one or more heaters comprise electrical heaters.

2003. The method of claim 1999, wherein the one or more heaters comprise surface burners.

2004. The method of claim 1999, wherein the one or more heaters comprise flameless distributed combustors.

2005. The method of claim 1999, wherein the one or more heaters comprise natural distributed combustors.

2006. The method of claim 1999, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2007. The method of claim 1999, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

2008. The method of claim 1999, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2009. The method of claim 1999, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

2010. The method of claim 1999, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

2011. The method of claim 1999, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2012. The method of claim 1999, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2013. The method of claim 1999, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2014. The method of claim 1999, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2015. The method of claim 1999, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2016. The method of claim 1999, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2017. The method of claim 1999, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2018. The method of claim 1999, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2019. The method of claim 1999, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2020. The method of claim 1999, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2021. The method of claim 1999, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2022. The method of claim 1999, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2023. The method of claim 1999, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2024. The method of claim 1999, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2025. The method of claim 1999, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2026. The method of claim 1999, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2027. The method of claim 2026, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2028. The method of claim 1999, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2029. The method of claim 1999, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2030. The method of claim 1999, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

2031. The method of claim 1999, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2032. The method of claim 1999, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

2033. The method of claim 1999, wherein allowing the heat to transfer further comprises substantially uniformly increasing a permeability of a majority of the selected section.

2034. The method of claim 1999, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2035. The method of claim 1999, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2036. The method of claim 2035, wherein at least about 20 heaters are disposed in the formation for each production well.

2037. The method of claim 1999, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2038. The method of claim 1999, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2039. A method of treating a hydrocarbon containing formation in situ, comprising

providing heat from one or more heaters to a selected section of the formation;

allowing the heat to transfer from the one or more heaters to the selected section of the formation to pyrolyze hydrocarbons within the selected section;

wherein at least some hydrocarbons within the selected section have an initial atomic oxygen to carbon ratio greater than about 0.025;

wherein the initial atomic oxygen to carbon ratio is less than about 0.15; and

producing a mixture from the formation.

2040. The method of claim 2039, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

2041. The method of claim 2039, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

2042. The method of claim 2039, wherein the one or more heaters comprise electrical heaters.

2043. The method of claim 2039, wherein the one or more heaters comprise surface burners.

2044. The method of claim 2039, wherein the one or more heaters comprise flameless distributed combustors.

2045. The method of claim 2039, wherein the one or more heaters comprise natural distributed combustors.

2046. The method of claim 2039, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2047. The method of claim 2039, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

2048. The method of claim 2039, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2049. The method of claim 2039, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

2050. The method of claim 2039, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

2051. The method of claim 2039, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2052. The method of claim 2039, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2053. The method of claim 2039, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2054. The method of claim 2039, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2055. The method of claim 2039, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2056. The method of claim 2039, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2057. The method of claim 2039, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2058. The method of claim 2039, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2059. The method of claim 2039, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2060. The method of claim 2039, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2061. The method of claim 2039, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2062. The method of claim 2039, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2063. The method of claim 2039, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2064. The method of claim 2039, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2065. The method of claim 2039, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2066. The method of claim 2039, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2067. The method of claim 2066, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2068. The method of claim 2039, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2069. The method of claim 2039, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2070. The method of claim 2039, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

2071. The method of claim 2039, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2072. The method of claim 2039, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

2073. The method of claim 2039, wherein allowing the heat to transfer further comprises substantially uniformly increasing a permeability of a majority of the selected section.

2074. The method of claim 2039, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2075. The method of claim 2039, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2076. The method of claim 2075, wherein at least about 20 heaters are disposed in the formation for each production well.

2077. The method of claim 2039, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2078. The method of claim 2039, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2079. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

wherein the selected section has been selected for heating using a moisture content in the selected section, and wherein at least a portion of the selected section comprises a moisture content of less than about 15% by weight; and

producing a mixture from the formation.

2080. The method of claim 2079, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

2081. The method of claim 2079, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

2082. The method of claim 2079, wherein the one or more heaters comprise electrical heaters.

2083. The method of claim 2079, wherein the one or more heaters comprise surface burners.

2084. The method of claim 2079, wherein the one or more heaters comprise flameless distributed combustors.

2085. The method of claim 2079, wherein the one or more heaters comprise natural distributed combustors.

2086. The method of claim 2079, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2087. The method of claim 2079, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

2088. The method of claim 2079, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2089. The method of claim 2079, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

2090. The method of claim 2079, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

2091. The method of claim 2079, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2092. The method of claim 2079, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2093. The method of claim 2079, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2094. The method of claim 2079, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2095. The method of claim 2079, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2096. The method of claim 2079, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2097. The method of claim 2079, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2098. The method of claim 2079, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2099. The method of claim 2079, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2100. The method of claim 2079, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2101. The method of claim 2079, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2102. The method of claim 2079, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2103. The method of claim 2079, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2104. The method of claim 2079, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2105. The method of claim 2079, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2106. The method of claim 2079, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2107. The method of claim 2106, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2108. The method of claim 2079, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2109. The method of claim 2079, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2110. The method of claim 2079, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

2111. The method of claim 2079, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2112. The method of claim 2079, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

2113. The method of claim 2079, wherein allowing the heat to transfer further comprises substantially uniformly increasing a permeability of a majority of the selected section.

2114. The method of claim 2079, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2115. The method of claim 2079, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2116. The method of claim 2115, wherein at least about 20 heaters are disposed in the formation for each production well.

2117. The method of claim 2079, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2118. The method of claim 2079, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2119. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to a selected section of the formation;

allowing the heat to transfer from the one or more heaters to the selected section of the formation;

wherein at least a portion of the selected section has an initial moisture content of less than about 15% by weight; and

producing a mixture from the formation.

2120. The method of claim 2119, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

2121. The method of claim 2119, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

2122. The method of claim 2119, wherein the one or more heaters comprise electrical heaters.

2123. The method of claim 2119, wherein the one or more heaters comprise surface burners.

2124. The method of claim 2119, wherein the one or more heaters comprise flameless distributed combustors.

2125. The method of claim 2119, wherein the one or more heaters comprise natural distributed combustors.

2126. The method of claim 2119, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2127. The method of claim 2119, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

2128. The method of claim 2119, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2129. The method of claim 2119, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

2130. The method of claim 2119, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

2131. The method of claim 2119, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2132. The method of claim 2119, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2133. The method of claim 2119, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2134. The method of claim 2119, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2135. The method of claim 2119, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2136. The method of claim 2119, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2137. The method of claim 2119, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2138. The method of claim 2119, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2139. The method of claim 2119, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2140. The method of claim 2119, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2141. The method of claim 2119, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2142. The method of claim 2119, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2143. The method of claim 2119, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2144. The method of claim 2119, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2145. The method of claim 2119, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2146. The method of claim 2119, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2147. The method of claim 2146, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2148. The method of claim 2119, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2149. The method of claim 2119, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2150. The method of claim 2119, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

2151. The method of claim 2119, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2152. The method of claim 2119, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

2153. The method of claim 2119, wherein allowing the heat to transfer further comprises substantially uniformly increasing a permeability of a majority of the selected section.

2154. The method of claim 2119, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2155. The method of claim 2119, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2156. The method of claim 2155, wherein at least about 20 heaters are disposed in the formation for each production well.

2157. The method of claim 2119, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2158. The method of claim 2119, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2159. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

wherein the selected section is heated in a reducing environment during at least a portion of the time that the selected section is being heated; and

producing a mixture from the formation.

2160. The method of claim 2159, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

2161. The method of claim 2159, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

2162. The method of claim 2159, wherein the one or more heaters comprise electrical heaters.

2163. The method of claim 2159, wherein the one or more heaters comprise surface burners.

2164. The method of claim 2159, wherein the one or more heaters comprise flameless distributed combustors.

2165. The method of claim 2159, wherein the one or more heaters comprise natural distributed combustors.

2166. The method of claim 2159, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2167. The method of claim 2159, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

2168. The method of claim 2159, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2169. The method of claim 2159, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

2170. The method of claim 2159, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

2171. The method of claim 2159, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2172. The method of claim 2159, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2173. The method of claim 2159, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2174. The method of claim 2159, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2175. The method of claim 2159, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2176. The method of claim 2159, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2177. The method of claim 2159, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2178. The method of claim 2159, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2179. The method of claim 2159, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2180. The method of claim 2159, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2181. The method of claim 2159, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2182. The method of claim 2159, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2183. The method of claim 2159, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2184. The method of claim 2159, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2185. The method of claim 2159, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2186. The method of claim 2159, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2187. The method of claim 2186, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2188. The method of claim 2159, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2189. The method of claim 2159, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2190. The method of claim 2159, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

2191. The method of claim 2159, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2192. The method of claim 2159, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

2193. The method of claim 2159, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

2194. The method of claim 2159, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2195. The method of claim 2159, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2196. The method of claim 2195, wherein at least about 20 heaters are disposed in the formation for each production well.

2197. The method of claim 2159, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2198. The method of claim 2159, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2199. A method of treating a hydrocarbon containing formation in situ, comprising:

heating a first section of the formation to produce a mixture from the formation;

heating a second section of the formation; and

recirculating a portion of the produced mixture from the first section into the second section of the formation to provide a reducing environment within the second section of the formation.

2200. The method of claim 2199, further comprising maintaining a temperature within the first section or the second section within a pyrolysis temperature range.

2201. The method of claim 2199, wherein heating the first or the second section comprises heating with an electrical heater.

2202. The method of claim 2199, wherein heating the first or the second section comprises heating with a surface burner.

2203. The method of claim 2199, wherein heating the first or the second section comprises heating with a flameless distributed combustor.

2204. The method of claim 2199, wherein heating the first or the second section comprises heating with a natural distributed combustor.

2205. The method of claim 2199, further comprising controlling a pressure and a temperature within at least a majority of the first or second section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2206. The method of claim 2199, further comprising controlling the heat such that an average heating rate of the first or the second section is less than about 1°

per day during pyrolysis.

2207. The method of claim 2199, wherein heating the first or the second section comprises:

heating a selected volume (V) of the hydrocarbon containing formation from one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2208. The method of claim 2199, wherein heating the first or the second section comprises transferring heat substantially by conduction.

2209. The method of claim 2199, wherein heating the first or the second section comprises heating the first or the second section such that a thermal conductivity of at least a portion of the first or the second section is greater than about 0.5 W/(m °

C.).

2210. The method of claim 2199, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2211. The method of claim 2199, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2212. The method of claim 2199, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2213. The method of claim 2199, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2214. The method of claim 2199, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2215. The method of claim 2199, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2216. The method of claim 2199, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2217. The method of claim 2199, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2218. The method of claim 2199, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2219. The method of claim 2199, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2220. The method of claim 2199, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2221. The method of claim 2199, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2222. The method of claim 2199, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2223. The method of claim 2199, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2224. The method of claim 2199, further comprising controlling a pressure within at least a majority of the first or second section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2225. The method of claim 2199, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2226. The method of claim 2225, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2227. The method of claim 2199, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2228. The method of claim 2199, further comprising:

providing hydrogen (H₂) to the first or second section to hydrogenate hydrocarbons within the first or second section; and

heating a portion of the first or second section with heat from hydrogenation.

2229. The method of claim 2199, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2230. The method of claim 2199, wherein heating the first or the second section comprises increasing a permeability of a majority of the first or the second section to greater than about 100 millidarcy.

2231. The method of claim 2199, wherein heating the first or the second section comprises substantially uniformly increasing a permeability of a majority of the first or the second section.

2232. The method of claim 2199, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2233. The method of claim 2199, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2234. The method of claim 2233, wherein at least about 20 heaters are disposed in the formation for each production well.

2235. The method of claim 2199, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2236. The method of claim 2199, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2237. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation; and

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that a permeability of at least a portion of the selected section increases to greater than about 100 millidarcy.

2238. The method of claim 2237, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

2239. The method of claim 2237, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

2240. The method of claim 2237, wherein the one or more heaters comprise electrical heaters.

2241. The method of claim 2237, wherein the one or more heaters comprise surface burners.

2242. The method of claim 2237, wherein the one or more heaters comprise flameless distributed combustors.

2243. The method of claim 2237, wherein the one or more heaters comprise natural distributed combustors.

2244. The method of claim 2237, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2245. The method of claim 2237, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

2246. The method of claim 2237, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2247. The method of claim 2237, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

2248. The method of claim 2237, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

2249. The method of claim 2237, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 250.

2250. The method of claim 2237, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2251. The method of claim 2237, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2252. The method of claim 2237, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2253. The method of claim 2237, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2254. The method of claim 2237, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2255. The method of claim 2237, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2256. The method of claim 2237, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2257. The method of claim 2237, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2258. The method of claim 2237, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2259. The method of claim 2237, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2260. The method of claim 2237, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2261. The method of claim 2237, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2262. The method of claim 2237, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2263. The method of claim 2237, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2264. The method of claim 2237, further comprising controlling formation conditions to produce a mixture from the formation, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2265. The method of claim 2264, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2266. The method of claim 2237, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2267. The method of claim 2237, further comprising producing a mixture from the formation and controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2268. The method of claim 2237, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

2269. The method of claim 2237, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2270. The method of claim 2237, further comprising increasing a permeability of a majority of the selected section to greater than about 5 Darcy.

2271. The method of claim 2237, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

2272. The method of claim 2237, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2273. The method of claim 2237, further comprising producing a mixture in a production well, wherein at least about 7 heaters are disposed in the formation for each production well.

2274. The method of claim 2273, wherein at least about 20 heaters are disposed in the formation for each production well.

2275. The method of claim 2237, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2276. The method of claim 2237, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2277. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation; and

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that a permeability of a majority of at least a portion of the selected section increases substantially uniformly.

2278. The method of claim 2277, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

2279. The method of claim 2277, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

2280. The method of claim 2277, wherein the one or more heaters comprise electrical heaters.

2281. The method of claim 2277, wherein the one or more heaters comprise surface burners.

2282. The method of claim 2277, wherein the one or more heaters comprise flameless distributed combustors.

2283. The method of claim 2277, wherein the one or more heaters comprise natural distributed combustors.

2284. The method of claim 2277, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2285. The method of claim 2277, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

2286. The method of claim 2277, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2287. The method of claim 2277, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

2288. The method of claim 2277, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

2289. The method of claim 2277, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2290. The method of claim 2277, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2291. The method of claim 2277, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2292. The method of claim 2277, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2293. The method of claim 2277, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2294. The method of claim 2277, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2295. The method of claim 2277, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2296. The method of claim 2277, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2297. The method of claim 2277, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2298. The method of claim 2277, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2299. The method of claim 2277, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2300. The method of claim 2277, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2301. The method of claim 2277, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2302. The method of claim 2277, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2303. The method of claim 2277, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2304. The method of claim 2277, further comprising controlling formation conditions to produce a mixture from the formation, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2305. The method of claim 2277, further comprising producing a mixture from the formation, wherein a partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2306. The method of claim 2277, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2307. The method of claim 2277, further comprising producing a mixture from the formation and controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2308. The method of claim 2277, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

2309. The method of claim 2277, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2310. The method of claim 2277, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

2311. The method of claim 2277, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2312. The method of claim 2277, further comprising producing a mixture in a production well, wherein at least about 7 heaters are disposed in the formation for each production well.

2313. The method of claim 2312, wherein at least about 20 heaters are disposed in the formation for each production well.

2314. The method of claim 2277, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2315. The method of claim 2277, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2316. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation; and

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that a porosity of a majority of at least a portion of the selected section increases substantially uniformly.

2317. The method of claim 2316, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

2318. The method of claim 2316, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

2319. The method of claim 2316, wherein the one or more heaters comprise electrical heaters.

2320. The method of claim 2316, wherein the one or more heaters comprise surface burners.

2321. The method of claim 2316, wherein the one or more heaters comprise flameless distributed combustors.

2322. The method of claim 2316, wherein the one or more heaters comprise natural distributed combustors.

2323. The method of claim 2316, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2324. The method of claim 2316, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

2325. The method of claim 2316, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2326. The method of claim 2316, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

2327. The method of claim 2316, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

2328. The method of claim 2316, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2329. The method of claim 2316, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2330. The method of claim 2316, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2331. The method of claim 2316, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2332. The method of claim 2316, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2333. The method of claim 2316, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2334. The method of claim 2316, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2335. The method of claim 2316, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2336. The method of claim 2316, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2337. The method of claim 2316, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2338. The method of claim 2316, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2339. The method of claim 2316, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2340. The method of claim 2316, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2341. The method of claim 2316, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2342. The method of claim 2316, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2343. The method of claim 2316, further comprising controlling formation conditions to roduce a mixture from the formation, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2344. The method of claim 2316, further comprising producing a mixture from the formation, wherein a partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2345. The method of claim 2316, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2346. The method of claim 2316, further comprising producing a mixture from the formation and controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2347. The method of claim 2316, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

2348. The method of claim 2316, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2349. The method of claim 2316, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

2350. The method of claim 2316, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

2351. The method of claim 2316, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2352. The method of claim 2316, further comprising producing a mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2353. The method of claim 2352, wherein at least about 20 heaters are disposed in the formation for each production well.

2354. The method of claim 2316, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2355. The method of claim 2316, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2356. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

controlling the heat to yield at least about 15% by weight of a total organic carbon content of at least some of the hydrocarbon containing formation into condensable hydrocarbons.

2357. The method of claim 2356, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

2358. The method of claim 2356, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

2359. The method of claim 2356, wherein the one or more heaters comprise electrical heaters.

2360. The method of claim 2356, wherein the one or more heaters comprise surface burners.

2361. The method of claim 2356, wherein the one or more heaters comprise flameless distributed combustors.

2362. The method of claim 2356, wherein the one or more heaters comprise natural distributed combustors.

2363. The method of claim 2356, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2364. The method of claim 2356, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

2365. The method of claim 2356, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2366. The method of claim 2356, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

2367. The method of claim 2356, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

2368. The method of claim 2356, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2369. The method of claim 2356, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2370. The method of claim 2356, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2371. The method of claim 2356, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2372. The method of claim 2356, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2373. The method of claim 2356, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2374. The method of claim 2356, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2375. The method of claim 2356, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2376. The method of claim 2356, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2377. The method of claim 2356, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2378. The method of claim 2356, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2379. The method of claim 2356, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2380. The method of claim 2356, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2381. The method of claim 2356, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2382. The method of claim 2356, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2383. The method of claim 2356, further comprising controlling formation conditions to produce a mixture from the formation, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2384. The method of claim 2356, further comprising producing a mixture from the formation, wherein a partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2385. The method of claim 2356, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2386. The method of claim 2356, further comprising producing a mixture from the formation and controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2387. The method of claim 2356, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

2388. The method of claim 2356, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2389. The method of claim 2356, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

2390. The method of claim 2356, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

2391. The method of claim 2356, wherein the heating is controlled to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2392. The method of claim 2356, further comprising producing a mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2393. The method of claim 2392, wherein at least about 20 heaters are disposed in the formation for each production well.

2394. The method of claim 2356, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2395. The method of claim 2356, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2396. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2397. The method of claim 2396, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

2398. The method of claim 2396, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

2399. The method of claim 2396, wherein the one or more heaters comprise electrical heaters.

2400. The method of claim 2396, wherein the one or more heaters comprise surface burners.

2401. The method of claim 2396, wherein the one or more heaters comprise flameless distributed combustors.

2402. The method of claim 2396, wherein the one or more heaters comprise natural distributed combustors.

2403. The method of claim 2396, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2404. The method of claim 2396, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

2405. The method of claim 2396, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2406. The method of claim 2396, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

2407. The method of claim 2396, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

2408. The method of claim 2396, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2409. The method of claim 2396, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2410. The method of claim 2396, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2411. The method of claim 2396, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2412. The method of claim 2396, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2413. The method of claim 2396, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2414. The method of claim 2396, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2415. The method of claim 2396, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2416. The method of claim 2396, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2417. The method of claim 2396, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2418. The method of claim 2396, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2419. The method of claim 2396, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2420. The method of claim 2396, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2421. The method of claim 2396, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2422. The method of claim 2396, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2423. The method of claim 2396, further comprising controlling formation conditions to produce a mixture from the formation, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2424. The method of claim 2396, further comprising producing a mixture from the formation, wherein a partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2425. The method of claim 2396, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2426. The method of claim 2396, further comprising producing a mixture from the formation and controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2427. The method of claim 2396, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

2428. The method of claim 2396, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2429. The method of claim 2396, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

2430. The method of claim 2396, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

2431. The method of claim 2396, further comprising producing a mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2432. The method of claim 2431, wherein at least about 20 heaters are disposed in the formation for each production well.

2433. The method of claim 2396, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2434. The method of claim 2396, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2435. A method of treating a hydrocarbon containing formation in situ, comprising:

heating a first section of the formation to pyrolyze at least some hydrocarbons in the first section and produce a first mixture from the formation;

heating a second section of the formation to pyrolyze at least some hydrocarbons in the second section and produce a second mixture from the formation; and

leaving an unpyrolyzed section between the first section and the second section to inhibit subsidence of the formation.

2436. The method of claim 2435, further comprising maintaining a temperature within the first section or the second section within a pyrolysis temperature range.

2437. The method of claim 2435, wherein heating the first section or heating the second section comprises heating with an electrical heater.

2438. The method of claim 2435, wherein heating the first section or heating the second section comprises heating with a surface burner.

2439. The method of claim 2435, wherein heating the first section or heating the second section comprises heating with a flameless distributed combustor.

2440. The method of claim 2435, wherein heating the first section or heating the second section comprises heating with a natural distributed combustor.

2441. The method of claim 2435, further comprising controlling a pressure and a temperature within at least a majority of the first or second section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2442. The method of claim 2435, further comprising controlling the heat such that an average heating rate of the first or second section is less than about 1°

per day during pyrolysis.

2443. The method of claim 2435, wherein heating the first section or heating the second section comprises:

heating a selected volume (V) of the hydrocarbon containing formation from one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2444. The method of claim 2435, wherein heating the first section or heating the second section comprises transferring heat substantially by conduction.

2445. The method of claim 2435, wherein heating the first section or heating the second section comprises heating the formation such that a thermal conductivity of at least a portion of the first or second section, respectively, is greater than about 0.5 W/(m °

C.).

2446. The method of claim 2435, wherein the first or second mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2447. The method of claim 2435, wherein the first or second mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2448. The method of claim 2435, wherein the first or second mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2449. The method of claim 2435, wherein the first or second mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2450. The method of claim 2435, wherein the first or second mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2451. The method of claim 2435, wherein the first or second mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2452. The method of claim 2435, wherein the first or second mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2453. The method of claim 2435, wherein the first or second mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2454. The method of claim 2435, wherein the first or second mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2455. The method of claim 2435, wherein the first or second mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2456. The method of claim 2435, wherein the first or second mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2457. The method of claim 2435, wherein the first or second mixture comprises anon-condensable component, and wherein the non-condensable component comprises hydrogen, and wherein the hydrogen is greater than about 10% by volume of the non-condensable component and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2458. The method of claim 2435, wherein the first or second mixture comprises ammonia, and wherein greater than about 0.05% by weight of the first or second mixture is ammonia.

2459. The method of claim 2435, wherein the first or second mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2460. The method of claim 2435, fturther comprising controlling a pressure within at least a majority of the first or second section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2461. The method of claim 2435, further comprising controlling formation conditions to produce the first or second mixture, wherein a partial pressure of H₂ within the first or second mixture is greater than about 0.5 bars.

2462. The method of claim 2435, wherein a partial pressure of H₂ within the first or second mixture is measured when the first or second mixture is at a production well.

2463. The method of claim 2435, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2464. The method of claim 2435, further comprising controlling formation conditions by recirculating a portion of hydrogen from the first or second mixture into the formation.

2465. The method of claim 2435, further comprising:

providing hydrogen (H₂) to the first or second section to hydrogenate hydrocarbons within the first or second section, respectively; and

heating a portion of the first or second section, respectively, with heat from hydrogenation.

2466. The method of claim 2435, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2467. The method of claim 2435, wherein heating the first section or heating the second section comprises increasing a permeability of a majority of the first or second section, respectively, to greater than about 100 millidarcy.

2468. The method of claim 2435, wherein heating the first section or heating the second section comprises substantially uniformly increasing a permeability of a majority of the first or second section, respectively.

2469. The method of claim 2435, further comprising controlling heating of the first or second section to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay, from the first or second section, respectively.

2470. The method of claim 2435, wherein producing the first or second mixture comprises producing the first or second mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2471. The method of claim 2470, wherein at least about 20 heaters are disposed in the formation for each production well.

2472. The method of claim 2435, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2473. The method of claim 2435, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2474. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

producing a mixture from the formation through one or more production wells, wherein the heating is controlled such that the mixture can be produced from the formation as a vapor, and wherein at least about 7 heaters are disposed in the formation for each production well.

2475. The method of claim 2474, wherein at least about 20 heaters are disposed in the formation for each production well.

2476. The method of claim 2474, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

2477. The method of claim 2474, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

2478. The method of claim 2474, wherein the one or more heaters comprise electrical heaters.

2479. The method of claim 2474, wherein the one or more heaters comprise surface burners.

2480. The method of claim 2474, wherein the one or more heaters comprise flameless distributed combustors.

2481. The method of claim 2474, wherein the one or more heaters comprise natural distributed combustors.

2482. The method of claim 2474, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2483. The method of claim 2474, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

per day during pyrolysis.

2484. The method of claim 2474, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2485. The method of claim 2474, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

2486. The method of claim 2474, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

2487. The method of claim 2474, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2488. The method of claim 2474, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2489. The method of claim 2474, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2490. The method of claim 2474, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2491. The method of claim 2474, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2492. The method of claim 2474, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2493. The method of claim 2474, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2494. The method of claim 2474, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2495. The method of claim 2474, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2496. The method of claim 2474, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2497. The method of claim 2474, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2498. The method of claim 2474, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2499. The method of claim 2474, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2500. The method of claim 2474, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2501. The method of claim 2474, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2502. The method of claim 2474, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2503. The method of claim 2502, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2504. The method of claim 2474, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2505. The method of claim 2474, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2506. The method of claim 2474, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

2507. The method of claim 2474, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2508. The method of claim 2474, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

2509. The method of claim 2474, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

2510. The method of claim 2474, wherein the heating is controlled to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2511. The method of claim 2474, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2512. The method of claim 2474, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2513. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation, wherein the one or more heaters are disposed within one or more first wells;

allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

producing a mixture from the formation through one or more second wells, wherein one or more of the first or second wells are initially used for a first purpose and are then used for one or more other purposes.

2514. The method of claim 2513, wherein the first purpose comprises removing water from the formation, and wherein the second purpose comprises providing heat to the formation.

2515. The method of claim 2513, wherein the first purpose comprises removing water from the formation, and wherein the second purpose comprises producing the mixture.

2516. The method of claim 2513, wherein the first purpose comprises heating, and wherein the second purpose comprises removing water from the formation.

2517. The method of claim 2513, wherein the first purpose comprises producing the mixture, and wherein the second purpose comprises removing water from the formation.

2518. The method of claim 2513, wherein the one or more heaters comprise electrical heaters.

2519. The method of claim 2513, wherein the one or more heaters comprise surface burners.

2520. The method of claim 2513, wherein the one or more heaters comprise flameless distributed combustors.

2521. The method of claim 2513, wherein the one or more heaters comprise natural distributed combustors.

2522. The method of claim 2513, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2523. The method of claim 2513, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1.0°

C. per day during pyrolysis.

2524. The method of claim 2513, wherein providing heat from the one or more heaters to at least the portion of the formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2525. The method of claim 2513, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

2526. The method of claim 2513, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2527. The method of claim 2513, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2528. The method of claim 2513, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.1 5.

2529. The method of claim 2513, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2530. The method of claim 2513, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2531. The method of claim 2513, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2532. The method of claim 2513, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2533. The method of claim 2513, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2534. The method of claim 2513, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2535. The method of claim 2513, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2536. The method of claim 2513, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2537. The method of claim 2513, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2538. The method of claim 2513, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2539. The method of claim 2513, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2540. The method of claim 2513, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2541. The method of claim 2513, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2542. The method of claim 2541, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

2543. The method of claim 2513, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2544. The method of claim 2513, further comprising controlling formation conditions, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

2545. The method of claim 2513, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

2546. The method of claim 2513, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2547. The method of claim 2513, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

2548. The method of claim 2513, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

2549. The method of claim 2513, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2550. The method of claim 2513, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2551. The method of claim 2550, wherein at least about 20 heaters are disposed in the formation for each production well.

2552. The method of claim 2513, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2553. The method of claim 2513, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2554. A method for forming heater wells in a hydrocarbon containing formation, comprising:

forming a first wellbore in the formation;

forming a second wellbore in the formation using magnetic tracking such that the second wellbore is arranged substantially parallel to the first wellbore; and

providing at least one heater within the first wellbore and at least one heater within the second wellbore such that the heaters can provide heat to at least a portion of the formation.

2555. The method of claim 2554, wherein superposition of heat from the at least one heater within the first wellbore and the at least one heater within the second wellbore pyrolyzes at least some hydrocarbons within a selected section of the formation.

2556. The method of claim 2554, further comprising maintaining a temperature within a selected section within a pyrolysis temperature range.

2557. The method of claim 2554, wherein the heaters comprise electrical heaters.

2558. The method of claim 2554, wherein the heaters comprise surface burners.

2559. The method of claim 2554, wherein the heaters comprise flameless distributed combustors.

2560. The method of claim 2554, wherein the heaters comprise natural distributed combustors.

2561. The method of claim 2554, further comprising controlling a pressure and a temperature within at least a majority of a selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2562. The method of claim 2554, further comprising controlling the heat from the heaters such that heat transferred from the heaters to at least the portion of the hydrocarbons is less than about 1°

C. per day during pyrolysis.

2563. The method of claim 2554, further comprising:

heating a selected volume (V) of the hydrocarbon containing formation from the heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2564. The method of claim 2554, further comprising allowing the heat to transfer from the heaters to at least the portion of the formation substantially by conduction.

2565. The method of claim 2554, further comprising providing heat from the heaters to at least the portion of the formation such that a thermal conductivity of at least the portion of the formation is greater than about 0.5 W/(m °

C.).

2566. The method of claim 2554, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2567. The method of claim 2554, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2568. The method of claim 2554, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2569. The method of claim 2554, fturther comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2570. The method of claim 2554, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2571. The method of claim 2554, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2572. The method of claim 2554, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2573. The method of claim 2554, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2574. The method of claim 2554, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2575. The method of claim 2554, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2576. The method of claim 2554, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2577. The method of claim 2554, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2578. The method of claim 2554, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2579. The method of claim 2554, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2580. The method of claim 2554, further comprising controlling a pressure within at least a majority of a selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2581. The method of claim 2554, further comprising producing a mixture from the formation, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2582. The method of claim 2554, further comprising producing a mixture from the formation, wherein a partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2583. The method of claim 2554, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2584. The method of claim 2554, further comprising producing a mixture from the formation and controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2585. The method of claim 2554, further comprising:

providing hydrogen (H₂) to the portion to hydrogenate hydrocarbons within the formation; and

heating a portion of the formation with heat from hydrogenation.

2586. The method of claim 2554, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2587. The method of claim 2554, further comprising allowing heat to transfer from the heaters to a selected section of the formation to pyrolyze at least some hydrocarbons within the selected section such that a permeability of a majority of a selected section of the formation increases to greater than about 100 millidarcy.

2588. The method of claim 2554, further comprising allowing heat to transfer from the heaters to a selected section of the formation to pyrolyze at least some hydrocarbons within the selected section such that a permeability of a majority of the selected section increases substantially uniformly.

2589. The method of claim 2554, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2590. The method of claim 2554, further comprising producing a mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2591. The method of claim 2590, wherein at least about 20 heaters are disposed in the formation for each production well.

2592. The method of claim 2554, further comprising forming a production well in the formation using magnetic tracking such that the production well is substantially parallel to the first wellbore and coupling a wellhead to the third wellbore.

2593. The method of claim 2554, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2594. The method of claim 2554, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2595. A method for installing a heater well into a hydrocarbon containing formation, comprising:

forming a bore in the ground using a steerable motor and an accelerometer; and

providing a heater within the bore such that the heater can transfer heat to at least a portion of the formation.

2596. The method of claim 2595, further comprising installing at least two heater wells, and wherein superposition of heat from at least the two heater wells pyrolyzes at least some hydrocarbons within a selected section of the formation.

2597. The method of claim 2595, further comprising maintaining a temperature within a selected section within a pyrolysis temperature range.

2598. The method of claim 2595, wherein the heater comprises an electrical heater.

2599. The method of claim 2595, wherein the heater comprises a surface burner.

2600. The method of claim 2595, wherein the heater comprises a flameless distributed combustor.

2601. The method of claim 2595, wherein the heater comprises a natural distributed combustor.

2602. The method of claim 2595, further comprising controlling a pressure and a temperature within at least a majority of a selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2603. The method of claim 2595, further comprising controlling the heat from the heater such that heat transferred from the heater to at least the portion of the formation is less than about 1°

C. per day during pyrolysis.

2604. The method of claim 2595, further comprising:

heating a selected volume (V) of the hydrocarbon containing formation from the heater, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2605. The method of claim 2595, further comprising allowing the heat to transfer from the heater to at least the portion of the formation substantially by conduction.

2606. The method of claim 2595, further comprising providing heat from the heater to at least the portion of the formation such that a thermal conductivity of at least the portion of the formation is greater than about 0.5 W/(m °

C.).

2607. The method of claim 2595, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2608. The method of claim 2595, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2609. The method of claim 2595, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2610. The method of claim 2595, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2611. The method of claim 2595, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2612. The method of claim 2595, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2613. The method of claim 2595, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2614. The method of claim 2595, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2615. The method of claim 2595, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2616. The method of claim 2595, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2617. The method of claim 2595, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2618. The method of claim 2595, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2619. The method of claim 2595, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2620. The method of claim 2595, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2621. The method of claim 2595, further comprising controlling a pressure within at least a majority of a selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2622. The method of claim 2595, further comprising controlling formation conditions to produce a mixture from the formation, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2623. The method of claim 2622, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2624. The method of claim 2595, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2625. The method of claim 2595, further comprising producing a mixture from the formation and controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2626. The method of claim 2595, further comprising:

providing hydrogen (H₂) to the at least the heated portion to hydrogenate hydrocarbons within the formation; and

heating a portion of the formation with heat from hydrogenation.

2627. The method of claim 2595, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2628. The method of claim 2595, further comprising allowing heat to transfer from the heater to a selected section of the formation to pyrolyze at least some hydrocarbons within the selected section such that a permeability of a majority of a selected section of the formation increases to greater than about 100 millidarcy.

2629. The method of claim 2595, further comprising allowing heat to transfer from the heater to a selected section of the formation to pyrolyze at least some hydrocarbons within the selected section such that a permeability of a majority of the selected section increases substantially uniformly.

2630. The method of claim 2595, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2631. The method of claim 2595, further comprising producing a mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2632. The method of claim 2631, wherein at least about 20 heaters are disposed in the formation for each production well.

2633. The method of claim 2595, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2634. The method of claim 2595, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2635. A method for installing of wells in a hydrocarbon containing formation, comprising:

forming a wellbore in the formation by geosteered drilling; and

providing a heater within the wellbore such that the heater can transfer heat to at least a portion of the formation.

2636. The method of claim 2635, further comprising maintaining a temperature within a selected section within a pyrolysis temperature range.

2637. The method of claim 2635, wherein the heater comprises an electrical heater.

2638. The method of claim 2635, wherein the heater comprises a surface burner.

2639. The method of claim 2635, wherein the heater comprises a flameless distributed combustor.

2640. The method of claim 2635, wherein the heater comprises a natural distributed combustor.

2641. The method of claim 2635, further comprising controlling a pressure and a temperature within at least a majority of a selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2642. The method of claim 2635, further comprising controlling the heat from the heater such that heat transferred from the heater to at least the portion of the formation is less than about 1°

C. per day during pyrolysis.

2643. The method of claim 2635, further comprising:

heating a selected volume (V) of the hydrocarbon containing formation from the heater, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2644. The method of claim 2635, further comprising allowing the heat to transfer from the heater to at least the portion of the formation substantially by conduction.

2645. The method of claim 2635, further comprising providing heat from the heater to at least the portion of the formation such that a thermal conductivity of at least the portion of the formation is greater than about 0.5 W/(m °

C.).

2646. The method of claim 2635, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2647. The method of claim 2635, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2648. The method of claim 2635, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2649. The method of claim 2635, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2650. The method of claim 2635, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2651. The method of claim 2635, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2652. The method of claim 2635, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2653. The method of claim 2635, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2654. The method of claim 2635, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2655. The method of claim 2635, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2656. The method of claim 2635, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2657. The method of claim 2635, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2658. The method of claim 2635, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2659. The method of claim 2635, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2660. The method of claim 2635, further comprising controlling a pressure within at least a majority of a selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2661. The method of claim 2635, further comprising controlling formation conditions to produce a mixture from the formation, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2662. The method of claim 2661, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2663. The method of claim 2635, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2664. The method of claim 2635, further comprising producing a mixture from the formation and controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2665. The method of claim 2635, further comprising:

providing hydrogen (H₂) to at least the heated portion to hydrogenate hydrocarbons within the formation; and

heating a portion of the formation with heat from hydrogenation.

2666. The method of claim 2635, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2667. The method of claim 2635, further comprising allowing heat to transfer from the heater to a selected section of the formation to pyrolyze at least some hydrocarbons within the selected section such that a permeability of a majority of a selected section of the formation increases to greater than about 100 millidarcy.

2668. The method of claim 2635, further comprising allowing heat to transfer from the heater to a selected section of the formation to pyrolyze at least some hydrocarbons within the selected section such that a permeability of a majority of the selected section increases substantially uniformly.

2669. The method of claim 2635, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2670. The method of claim 2635, further comprising producing a mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2671. The method of claim 2670, wherein at least about 20 heaters are disposed in the formation for each production well.

2672. The method of claim 2635, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2673. The method of claim 2635, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2674. A method of treating a hydrocarbon containing formation in situ, comprising:

heating a selected section of the formation with a heating element placed within a wellbore, wherein at least one end of the heating element is free to move axially within the wellbore to allow for thermal expansion of the heating element.

2675. The method of claim 2674, further comprising at least two heating elements within at least two wellbores, and wherein superposition of heat from at least the two heating elements pyrolyzes at least some hydrocarbons within a selected section of the formation.

2676. The method of claim 2674, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

2677. The method of claim 2674, wherein the heating element comprises a pipe-in-pipe heater.

2678. The method of claim 2674, wherein the heating element comprises a flameless distributed combustor.

2679. The method of claim 2674, wherein the heating element comprises a mineral insulated cable coupled to a support, and wherein the support is free to move within the wellbore.

2680. The method of claim 2674, wherein the heating element comprises a mineral insulated cable suspended from a wellhead.

2681. The method of claim 2674, further comprising controlling a pressure and a temperature within at least a majority of a heated section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2682. The method of claim 2674, further comprising controlling the heat such that an average heating rate of the heated section is less than about 1°

C. per day during pyrolysis.

2683. The method of claim 2674, wherein heating the section of the formation further comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the heating element, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2684. The method of claim 2674, wherein heating the section of the formation comprises transferring heat substantially by conduction.

2685. The method of claim 2674, further comprising heating the selected section of the formation such that a thermal conductivity of the selected section is greater than about 0.5 W/(m °

C.).

2686. The method of claim 2674, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2687. The method of claim 2674, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2688. The method of claim 2674, further comprising producing a mixture from the formation, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2689. The method of claim 2674, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2690. The method of claim 2674, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2691. The method of claim 2674, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2692. The method of claim 2674, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2693. The method of claim 2674, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2694. The method of claim 2674, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2695. The method of claim 2674, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2696. The method of claim 2674, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2697. The method of claim 2674, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2698. The method of claim 2674, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2699. The method of claim 2674, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2700. The method of claim 2674, further comprising controlling a pressure within the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2701. The method of claim 2674, further comprising controlling formation conditions to produce a mixture from the formation, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2702. The method of claim 2701, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2703. The method of claim 2674, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2704. The method of claim 2674, further comprising producing a mixture from the formation and controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2705. The method of claim 2674, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the heated section; and

heating a portion of the section with heat from hydrogenation.

2706. The method of claim 2674, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2707. The method of claim 2674, wherein heating comprises increasing a permeability of a majority of the heated section to greater than about 100 millidarcy.

2708. The method of claim 2674, wherein heating comprises substantially uniformly increasing a permeability of a majority of the heated section.

2709. The method of claim 2674, wherein the heating is controlled to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2710. The method of claim 2674, further comprising producing a mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2711. The method of claim 2710, wherein at least about 20 heaters are disposed in the formation for each production well.

2712. The method of claim 2674, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2713. The method of claim 2674, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2714. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

producing a mixture from the formation through a production well, wherein the production well is located such that a majority of the mixture produced from the formation comprises non-condensable hydrocarbons and a non-condensable component comprising hydrogen.

2715. The method of claim 2714, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

2716. The method of claim 2714, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

2717. The method of claim 2714, wherein the production well is less than approximately 6 m from a heater of the one or more heaters.

2718. The method of claim 2714, wherein the production well is less than approximately 3 m from a heater of the one or more heaters.

2719. The method of claim 2714, wherein the production well is less than approximately 1.5 m from a heater of the one or more heaters.

2720. The method of claim 2714, wherein an additional heater is positioned within a wellbore of the production well.

2721. The method of claim 2714, wherein the one or more heaters comprise electrical heaters.

2722. The method of claim 2714, wherein the one or more heaters comprise surface burners.

2723. The method of claim 2714, wherein the one or more heaters comprise flameless distributed combustors.

2724. The method of claim 2714, wherein the one or more heaters comprise natural distributed combustors.

2725. The method of claim 2714, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2726. The method of claim 2714, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

2727. The method of claim 2714, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2728. The method of claim 2714, wherein allowing the heat to transfer from the one or more heaters to the selected section comprises transferring heat substantially by conduction.

2729. The method of claim 2714, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

2730. The method of claim 2714, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2731. The method of claim 2714, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2732. The method of claim 2714, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2733. The method of claim 2714, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2734. The method of claim 2714, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2735. The method of claim 2714, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2736. The method of claim 2714, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2737. The method of claim 2714, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2738. The method of claim 2714, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2739. The method of claim 2714, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2740. The method of claim 2714, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2741. The method of claim 2714, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2742. The method of claim 2714, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2743. The method of claim 2714, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2744. The method of claim 2714, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2745. The method of claim 2714, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2746. The method of claim 2745, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2747. The method of claim 2714, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2748. The method of claim 2714, further comprising controlling formation conditions by recirculating a portion of the hydrogen from the mixture into the formation.

2749. The method of claim 2714, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

2750. The method of claim 2714, further comprising:

producing condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2751. The method of claim 2714, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

2752. The method of claim 2714, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

2753. The method of claim 2714, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2754. The method of claim 2714, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

2755. The method of claim 2754, wherein at least about 20 heaters are disposed in the formation for each production well.

2756. The method of claim 2714, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2757. The method of claim 2714, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2758. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat to at least a portion of the formation from one or more first heaters placed within a pattern in the formation;

allowing the heat to transfer from the one or more first heaters to a first section of the formation;

heating a second section of the formation with at least one second heater, wherein the second section is located within the first section, and wherein at least the one second heater is configured to raise an average temperature of a portion of the second section to a higher temperature than an average temperature of the first section; and

producing a mixture from the formation through a production well positioned within the second section, wherein a majority of the produced mixture comprises non-condensable hydrocarbons and a non-condensable component comprising H₂ components.

2759. The method of claim 2758, wherein the one or more first heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the first section of the formation.

2760. The method of claim 2758, further comprising maintaining a temperature within the first section within a pyrolysis temperature range.

2761. The method of claim 2758, wherein at least the one heater comprises a heater element positioned within the production well.

2762. The method of claim 2758, wherein at least the one second heater comprises an electrical heater.

2763. The method of claim 2758, wherein at least the one second heater comprises a surface burner.

2764. The method of claim 2758, wherein at least the one second heater comprises a flameless distributed combustor.

2765. The method of claim 2758, wherein at least the one second heater comprises a natural distributed combustor.

2766. The method of claim 2758, further comprising controlling a pressure and a temperature within at least a majority of the first or the second section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2767. The method of claim 2758, further comprising controlling the heat such that an average heating rate of the first section is less than about 1°

C. per day during pyrolysis.

2768. The method of claim 2758, wherein providing heat to the formation further comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more first heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2769. The method of claim 2758, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

2770. The method of claim 2758, wherein providing heat from the one or more first heaters comprises heating the first section such that a thermal conductivity of at least a portion of the first section is greater than about 0.5 W/(m °

C.).

2771. The method of claim 2758, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2772. The method of claim 2758, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2773. The method of claim 2758, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2774. The method of claim 2758, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2775. The method of claim 2758, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2776. The method of claim 2758, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2777. The method of claim 2758, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2778. The method of claim 2758, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2779. The method of claim 2758, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2780. The method of claim 2758, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2781. The method of claim 2758, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2782. The method of claim 2758, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2783. The method of claim 2758, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2784. The method of claim 2758, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2785. The method of claim 2758, further comprising controlling a pressure within at least a majority of the first or the second section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2786. The method of claim 2758, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2787. The method of claim 2786, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2788. The method of claim 2758, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2789. The method of claim 2758, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2790. The method of claim 2758, further comprising:

providing hydrogen (H₂) to the first or second section to hydrogenate hydrocarbons within the first or second section, respectively; and

heating a portion of the first or second section, respectively, with heat from hydrogenation.

2791. The method of claim 2758, further comprising:

producing condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2792. The method of claim 2758, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the first or second section to greater than about 100 millidarcy.

2793. The method of claim 2758, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the first or second section.

2794. The method of claim 2758, wherein heating the first or the second section is controlled to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2795. The method of claim 2758, wherein at least about 7 heaters are disposed in the formation for each production well.

2796. The method of claim 2795, wherein at least about 20 heaters are disposed in the formation for each production well.

2797. The method of claim 2758, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2798. The method of claim 2758, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2799. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat into the formation from a plurality of heaters placed in a pattern within the formation, wherein a spacing between heaters is greater than about 6 m;

allowing the heat to transfer from the plurality of heaters to a selected section of the formation;

producing a mixture from the formation from a plurality of production wells, wherein the plurality of production wells are positioned within the pattern, and wherein a spacing between production wells is greater than about 12 m.

2800. The method of claim 2799, wherein superposition of heat from the plurality of heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

2801. The method of claim 2799, further comprising maintaining a temperature within the selected section within a pyrolysis temperature range.

2802. The method of claim 2799, wherein the plurality of heaters comprises electrical heaters.

2803. The method of claim 2799, wherein the plurality of heaters comprises surface burners.

2804. The method of claim 2799, wherein the plurality of heaters comprises flameless distributed combustors.

2805. The method of claim 2799, wherein the plurality of heaters comprises natural distributed combustors.

2806. The method of claim 2799, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

2807. The method of claim 2799, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

2808. The method of claim 2799, wherein providing heat from the plurality of heaters comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the plurality of heaters, wherein the formation has an average heat capacity (C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

2809. The method of claim 2799, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

2810. The method of claim 2799, wherein providing heat comprises heating the selected formation such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

2811. The method of claim 2799, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

2812. The method of claim 2799, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

2813. The method of claim 2799, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

2814. The method of claim 2799, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

2815. The method of claim 2799, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

2816. The method of claim 2799, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

2817. The method of claim 2799, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

2818. The method of claim 2799, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

2819. The method of claim 2799, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

2820. The method of claim 2799, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

2821. The method of claim 2799, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

2822. The method of claim 2799, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

2823. The method of claim 2799, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

2824. The method of claim 2799, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

2825. The method of claim 2799, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

2826. The method of claim 2799, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H₂ within the mixture is greater than about 0.5 bars.

2827. The method of claim 2826, wherein the partial pressure of H₂ within the mixture is measured when the mixture is at a production well.

2828. The method of claim 2799, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

2829. The method of claim 2799, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

2830. The method of claim 2799, further comprising:

providing hydrogen (H₂) to the selected section to hydrogenate hydrocarbons within the selected section; and

heating a portion of the selected section with heat from hydrogenation.

2831. The method of claim 2799, further comprising:

producing hydrogen and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

2832. The method of claim 2799, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

2833. The method of claim 2799, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

2834. The method of claim 2799, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

2835. The method of claim 2799, wherein at least about 7 heaters are disposed in the formation for each production well.

2836. The method of claim 2835, wherein at least about 20 heaters are disposed in the formation for each production well.

2837. The method of claim 2799, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

2838. The method of claim 2799, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

2839. A system configured to heat a hydrocarbon containing formation, comprising:

a heater disposed in an opening in the formation, wherein the heater is configured to provide heat to at least a portion of the formation during use;

an oxidizing fluid source;

a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and

wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

2840. The system of claim 2839, wherein the oxidizing fluid is configured to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.

2841. The system of claim 2839, wherein the conduit comprises orifices, and wherein the orifices are configured to provide the oxidizing fluid into the opening.

2842. The system of claim 2839, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configured to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.

2843. The system of claim 2839, wherein the conduit is further configured to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.

2844. The system of claim 2839, wherein the conduit is further configured to remove an oxidation product.

2845. The system of claim 2839, wherein the conduit is further configured to remove an oxidation product such that the oxidation product transfers substantial heat to the oxidizing fluid.

2846. The system of claim 2839, wherein the conduit is further configured to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

2847. The system of claim 2839, wherein the conduit is further configured to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.

2848. The system of claim 2839, wherein the conduit is further configured to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

2849. The system of claim 2839, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

2850. The system of claim 2839, further comprising a center conduit disposed within the conduit, wherein the center conduit is configured to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configured to remove an oxidation product during use.

2851. The system of claim 2839, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

2852. The system of claim 2839, further comprising a conductor disposed in a second conduit, wherein the second conduit is disposed within the opening, and wherein the conductor is configured to heat at least a portion of the formation during application of an electrical current to the conductor.

2853. The system of claim 2839, further comprising an insulated conductor disposed within the opening, wherein the insulated conductor is configured to heat at least a portion of the formation during application of an electrical current to the insulated conductor.

2854. The system of claim 2839, further comprising at least one elongated member disposed within the opening, wherein the at least the one elongated member is configured to heat at least a portion of the formation during application of an electrical current to the at least the one elongated member.

2855. The system of claim 2839, further comprising a heat exchanger disposed external to the formation, wherein the heat exchanger is configured to heat the oxidizing fluid, wherein the conduit is further configured to provide the heated oxidizing fluid into the opening during use, and wherein the heated oxidizing fluid is configured to heat at least a portion of the formation during use.

2856. The system of claim 2839, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

2857. The system of claim 2839, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

2858. The system of claim 2839, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

2859. The system of claim 2839, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

2860. The system of claim 2839, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

2861. The system of claim 2839, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

2862. The system of claim 2839, wherein the system is further configured such that transferred heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.

2863. A system configurable to heat a hydrocarbon containing formation, comprising:

a heater configurable to be disposed in an opening in the formation, wherein the heater is further configurable to provide heat to at least a portion of the formation during use;

a conduit configurable to be disposed in the opening, wherein the conduit is configurable to provide an oxidizing fluid from an oxidizing fluid source to a reaction zone in the formation during use, and wherein the system is configurable to allow the oxidizing fluid to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and

wherein the system is further configurable to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

2864. The system of claim 2863, wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.

2865. The system of claim 2863, wherein the conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening.

2866. The system of claim 2863, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.

2867. The system of claim 2863, wherein the conduit is further configurable to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.

2868. The system of claim 2863, wherein the conduit is further configurable to remove an oxidation product.

2869. The system of claim 2863, wherein the conduit is further configurable to remove an oxidation product, such that the oxidation product transfers heat to the oxidizing fluid.

2870. The system of claim 2863, wherein the conduit is further configurable to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

2871. The system of claim 2863, wherein the conduit is further configurable to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.

2872. The system of claim 2863, wherein the conduit is further configurable to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

2873. The system of claim 2863, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

2874. The system of claim 2863, further comprising a center conduit disposed within the conduit, wherein the center conduit is configurable to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configurable to remove an oxidation product during use.

2875. The system of claim 2863, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

2876. The system of claim 2863, further comprising a conductor disposed in a second conduit, wherein the second conduit is disposed within the opening, and wherein the conductor is configurable to heat at least a portion of the formation during application of an electrical current to the conductor.

2877. The system of claim 2863, further comprising an insulated conductor disposed within the opening, wherein the insulated conductor is configurable to heat at least a portion of the formation during application of an electrical current to the insulated conductor.

2878. The system of claim 2863, further comprising at least one elongated member disposed within the opening, wherein the at least the one elongated member is configurable to heat at least a portion of the formation during application of an electrical current to the at least the one elongated member.

2879. The system of claim 2863, further comprising a heat exchanger disposed external to the formation, wherein the heat exchanger is configurable to heat the oxidizing fluid, wherein the conduit is further configurable to provide the heated oxidizing fluid into the opening during use, and wherein the heated oxidizing fluid is configurable to heat at least a portion of the formation during use.

2880. The system of claim 2863, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

2881. The system of claim 2863, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

2882. The system of claim 2863, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

2883. The system of claim 2863, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

2884. The system of claim 2863, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

2885. The system of claim 2863, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

2886. The system of claim 2863, wherein the system is further configurable such that transferred heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.

2887. The system of claim 2863, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

a heater disposed in an opening in the formation, wherein the heater is configured to provide heat to at least a portion of the formation during use;

an oxidizing fluid source;

a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and

wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

2888. An in situ method for heating a hydrocarbon containing formation, comprising:

heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidizing fluid;

providing the oxidizing fluid to a reaction zone in the formation;

allowing the oxidizing fluid to react with at least a portion of the hydrocarbons at the reaction zone to generate heat at the reaction zone; and

transferring the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the formation.

2889. The method of claim 2888, further comprising transporting the oxidizing fluid through the reaction zone by diffusion.

2890. The method of claim 2888, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a conduit disposed in the opening.

2891. The method of claim 2888, further comprising controlling a flow of the oxidizing fluid with critical flow orifices of a conduit disposed in the opening such that a rate of oxidation is controlled.

2892. The method of claim 2888, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over time within the reaction zone.

2893. The method of claim 2888, wherein a conduit is disposed in the opening, the method further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.

2894. The method of claim 2888, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit.

2895. The method of claim 2888, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and transferring heat from the oxidation product in the conduit to oxidizing fluid in the conduit.

2896. The method of claim 2888, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

2897. The method of claim 2888, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and controlling a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.

2898. The method of claim 2888, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.

2899. The method of claim 2888, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.

2900. The method of claim 2888, wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the outer conduit.

2901. The method of claim 2888, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

2902. The method of claim 2888, wherein heating the portion comprises applying electrical current to a conductor disposed in a conduit, wherein the conduit is disposed within the opening.

2903. The method of claim 2888, wherein heating the portion comprises applying electrical current to an insulated conductor disposed within the opening.

2904. The method of claim 2888, wherein heating the portion comprises applying electrical current to at least one elongated member disposed within the opening.

2905. The method of claim 2888, wherein heating the portion comprises heating the oxidizing fluid in a heat exchanger disposed external to the formation such that providing the oxidizing fluid into the opening comprises transferring heat from the heated oxidizing fluid to the portion.

2906. The method of claim 2888, further comprising removing water from the formation prior to heating the portion.

2907. The method of claim 2888, further comprising controlling the temperature of the formation to substantially inhibit production of oxides of nitrogen during oxidation.

2908. The method of claim 2888, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

2909. The method of claim 2888, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

2910. The method of claim 2888, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

2911. The method of claim 2888, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

2912. The method of claim 2888, wherein the pyrolysis zone is substantially adjacent to the reaction zone.

2913. A system configured to heat a hydrocarbon containing formation, comprising:

a heater disposed in an opening in the formation, wherein the heater is configured to provide heat to at least a portion of the formation during use;

an oxidizing fluid source;

a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone, and wherein the conduit is further configured to remove an oxidation product from the formation during use; and

wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

2914. The system of claim 2913, wherein the oxidizing fluid is configured to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.

2915. The system of claim 2913, wherein the conduit comprises orifices, and wherein the orifices are configured to provide the oxidizing fluid into the opening.

2916. The system of claim 2913, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configured to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.

2917. The system of claim 2913, wherein the conduit is further configured to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.

2918. The system of claim 2913, wherein the conduit is further configured such that the oxidation product transfers heat to the oxidizing fluid.

2919. The system of claim 2913, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

2920. The system of claim 2913, wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.

2921. The system of claim 2913, wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

2922. The system of claim 2913, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

2923. The system of claim 2913, further comprising a center conduit disposed within the conduit, wherein the center conduit is configured to provide the oxidizing fluid into the opening during use.

2924. The system of claim 2913, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

2925. The system of claim 2913, further comprising a conductor disposed in a second conduit, wherein the second conduit is disposed within the opening, and wherein the conductor is configured to heat at least a portion of the formation during application of an electrical current to the conductor.

2926. The system of claim 2913, further comprising an insulated conductor disposed within the opening, wherein the insulated conductor is configured to heat at least a portion of the formation during application of an electrical current to the insulated conductor.

2927. The system of claim 2913, further comprising at least one elongated member disposed within the opening, wherein the at least the one elongated member is configured to heat at least a portion of the formation during application of an electrical current to the at least the one elongated member.

2928. The system of claim 2913, further comprising a heat exchanger disposed external to the formation, wherein the heat exchanger is configured to heat the oxidizing fluid, wherein the conduit is further configured to provide the heated oxidizing fluid into the opening during use, and wherein the heated oxidizing fluid is configured to heat at least a portion of the formation during use.

2929. The system of claim 2913, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

2930. The system of claim 2913, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

2931. The system of claim 2913, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

2932. The system of claim 2913, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

2933. The system of claim 2913, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

2934. The system of claim 2913, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

2935. The system of claim 2913, wherein the system is further configured such that transferred heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.

2936. A system configurable to heat a hydrocarbon containing formation, comprising:

a heater configurable to be disposed in an opening in the formation, wherein the heater is further configurable to provide heat to at least a portion of the formation during use;

a conduit configurable to be disposed in the opening, wherein the conduit is further configurable to provide an oxidizing fluid from an oxidizing fluid source to a reaction zone in the formation during use, wherein the system is configurable to allow the oxidizing fluid to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone, and wherein the conduit is further configurable to remove an oxidation product from the formation during use; and

wherein the system is further configurable to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone during use.

2937. The system of claim 2936, wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by difflusion.

2938. The system of claim 2936, wherein the conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening.

2939. The system of claim 2936, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.

2940. The system of claim 2936, wherein the conduit is further configurable to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.

2941. The system of claim 2936, wherein the conduit is further configurable such that the oxidation product transfers heat to the oxidizing fluid.

2942. The system of claim 2936, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

2943. The system of claim 2936, wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.

2944. The system of claim 2936, wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

2945. The system of claim 2936, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

2946. The system of claim 2936, further comprising a center conduit disposed within the conduit, wherein the center conduit is configurable to provide the oxidizing fluid into the opening during use.

2947. The system of claim 2936, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

2948. The system of claim 2936, further comprising a conductor disposed in a second conduit, wherein the second conduit is disposed within the opening, and wherein the conductor is configurable to heat at least a portion of the formation during application of an electrical current to the conductor.

2949. The system of claim 2936, further comprising an insulated conductor disposed within the opening, wherein the insulated conductor is configurable to heat at least a portion of the formation during application of an electrical current to the insulated conductor.

2950. The system of claim 2936, further comprising at least one elongated member disposed within the opening, wherein the at least the one elongated member is configurable to heat at least a portion of the formation during application of an electrical current to the at least the one elongated member.

2951. The system of claim 2936, further comprising a heat exchanger disposed external to the formation, wherein the heat exchanger is configurable to heat the oxidizing fluid, wherein the conduit is further configurable to provide the heated oxidizing fluid into the opening during use, and wherein the heated oxidizing fluid is configurable to heat at least a portion of the formation during use.

2952. The system of claim 2936, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

2953. The system of claim 2936, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

2954. The system of claim 2936, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

2955. The system of claim 2936, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

2956. The system of claim 2936, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

2957. The system of claim 2936, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

2958. The system of claim 2936, wherein the system is further configurable such that transferred heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.

2959. The system of claim 2936, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

a heater disposed in an opening in the formation, wherein the heater is configured to provide heat to at least a portion of the formation during use;

an oxidizing fluid source;

a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone, and wherein the conduit is further configured to remove an oxidation product from the formation during use; and

wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

2960. An in situ method for heating a hydrocarbon containing formation, comprising:

heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidizing fluid, wherein the portion is located substantially adjacent to an opening in the formation;

providing the oxidizing fluid to a reaction zone in the formation;

allowing the oxidizing gas to react with at least a portion of the hydrocarbons at the reaction zone to generate heat in the reaction zone;

removing at least a portion of an oxidation product through the opening; and

transferring the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the formation.

2961. The method of claim 2960, further comprising transporting the oxidizing fluid through the reaction zone by diffusion.

2962. The method of claim 2960, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a conduit disposed in the opening.

2963. The method of claim 2960, further comprising controlling a flow of the oxidizing fluid with critical flow orifices of a conduit disposed in the opening such that a rate of oxidation is controlled.

2964. The method of claim 2960, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially maintained within the reaction zone.

2965. The method of claim 2960, wherein a conduit is disposed in the opening, the method further comprising cooling the conduit with the oxidizing fluid such that the conduit is not substantially heated by oxidation.

2966. The method of claim 2960, wherein a conduit is disposed within the opening, and wherein removing at least the portion of the oxidation product through the opening comprises removing at least the portion of the oxidation product through the conduit.

2967. The method of claim 2960, wherein a conduit is disposed within the opening, and wherein removing at least the portion of the oxidation product through the opening comprises removing at least the portion of the oxidation product through the conduit, the method further comprising transferring substantial heat from the oxidation product in the conduit to the oxidizing fluid in the conduit.

2968. The method of claim 2960, wherein a conduit is disposed within the opening, wherein removing at least the portion of the oxidation product through the opening comprises removing at least the portion of the oxidation product through the conduit, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

2969. The method of claim 2960, wherein a conduit is disposed within the opening, and wherein removing at least the portion of the oxidation product through the opening comprises removing at least the portion of the oxidation product through the conduit, the method further comprising controlling a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.

2970. The method of claim 2960, wherein a conduit is disposed within the opening, and wherein removing at least the portion of the oxidation product through the opening comprises removing at least the portion of the oxidation product through the conduit, the method further comprising substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.

2971. The method of claim 2960, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.

2972. The method of claim 2960, wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing at least a portion of the oxidation product through the outer conduit.

2973. The method of claim 2960, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

2974. The method of claim 2960, wherein heating the portion comprises applying electrical current to a conductor disposed in a conduit, wherein the conduit is disposed within the opening.

2975. The method of claim 2960, wherein heating the portion comprises applying electrical current to an insulated conductor disposed within the opening.

2976. The method of claim 2960, wherein heating the portion comprises applying electrical current to at least one elongated member disposed within the opening.

2977. The method of claim 2960, wherein heating the portion comprises heating the oxidizing fluid in a heat exchanger disposed external to the formation such that providing the oxidizing fluid into the opening comprises transferring heat from the heated oxidizing fluid to the portion.

2978. The method of claim 2960, further comprising removing water from the formation prior to heating the portion.

2979. The method of claim 2960, further comprising controlling the temperature of the formation to substantially inhibit production of oxides of nitrogen during oxidation.

2980. The method of claim 2960, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

2981. The method of claim 2960, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

2982. The method of claim 2960, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

2983. The method of claim 2960, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

2984. The method of claim 2960, wherein the pyrolysis zone is substantially adjacent to the reaction.

2985. A system configured to heat a hydrocarbon containing formation, comprising:

an electric heater disposed in an opening in the formation, wherein the electric heater is configured to provide heat to at least a portion of the formation during use;

an oxidizing fluid source;

a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and

wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

2986. The system of claim 2985, wherein the oxidizing fluid is configured to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.

2987. The system of claim 2985, wherein the conduit comprises orifices, and wherein the orifices are configured to provide the oxidizing fluid into the opening.

2988. The system of claim 2985, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configured to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.

2989. The system of claim 2985, wherein the conduit is further configured to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.

2990. The system of claim 2985, wherein the conduit is further configured to remove an oxidation product.

2991. The system of claim 2985, wherein the conduit is further configured to remove an oxidation product, such that the oxidation product transfers heat to the oxidizing fluid.

2992. The system of claim 2985, wherein the conduit is further configured to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

2993. The system of claim 2985, wherein the conduit is further configured to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.

2994. The system of claim 2985, wherein the conduit is further configured to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

2995. The system of claim 2985, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

2996. The system of claim 2985, further comprising a center conduit disposed within the conduit, wherein the center conduit is configured to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configured to remove an oxidation product during use.

2997. The system of claim 2985, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

2998. The system of claim 2985, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

2999. The system of claim 2985, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3000. The system of claim 2985, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3001. The system of claim 2985, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3002. The system of claim 2985, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3003. The system of claim 2985, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

3004. The system of claim 2985, wherein the system is further configured such that transferred heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.

3005. A system configurable to heat a hydrocarbon containing formation, comprising:

an electric heater configurable to be disposed in an opening in the formation, wherein the electric heater is further configurable to provide heat to at least a portion of the formation during use, and wherein at least the portion is located substantially adjacent to the opening;

a conduit configurable to be disposed in the opening, wherein the conduit is further configurable to provide an oxidizing fluid from an oxidizing fluid source to a reaction zone in the formation during use, and wherein the system is configurable to allow the oxidizing fluid to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and

wherein the system is further configurable to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

3006. The system of claim 3005, wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.

3007. The system of claim 3005, wherein the conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening.

3008. The system of claim 3005, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.

3009. The system of claim 3005, wherein the conduit is further configurable to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.

3010. The system of claim 3005, wherein the conduit is further configurable to remove an oxidation product.

3011. The system of claim 3005, wherein the conduit is further configurable to remove an oxidation product such that the oxidation product transfers heat to the oxidizing fluid.

3012. The system of claim 3005, wherein the conduit is further configurable to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

3013. The system of claim 3005, wherein the conduit is further configurable to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.

3014. The system of claim 3005, wherein the conduit is further configurable to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3015. The system of claim 3005, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3016. The system of claim 3005, further comprising a center conduit disposed within the conduit, wherein the center conduit is configurable to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configurable to remove an oxidation product during use.

3017. The system of claim 3005, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

3018. The system of claim 3005, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3019. The system of claim 3005, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3020. The system of claim 3005, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3021. The system of claim 3005, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3022. The system of claim 3005, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3023. The system of claim 3005, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

3024. The system of claim 3005, wherein the system is further configurable such that transferred heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.

3025. The system of claim 3005, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

an electric heater disposed in an opening in the formation, wherein the electric heater is configured to provide heat to at least a portion of the formation during use;

an oxidizing fluid source;

a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and

wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

3026. A system configured to heat a hydrocarbon containing formation, comprising:

a conductor disposed in a first conduit, wherein the first conduit is disposed in an opening in the formation, and wherein the conductor is configured to provide heat to at least a portion of the formation during use;

an oxidizing fluid source;

a second conduit disposed in the opening, wherein the second conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and

wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

3027. The system of claim 3026, wherein the oxidizing fluid is configured to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.

3028. The system of claim 3026, wherein the second conduit comprises orifices, and wherein the orifices are configured to provide the oxidizing fluid into the opening.

3029. The system of claim 3026, wherein the second conduit comprises critical flow orifices, and wherein the critical flow orifices are configured to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.

3030. The system of claim 3026, wherein the second conduit is further configured to be cooled with the oxidizing fluid to reduce heating of the second conduit by oxidation.

3031. The system of claim 3026, wherein the second conduit is further configured to remove an oxidation product.

3032. The system of claim 3026, wherein the second conduit is further configured to remove an oxidation product such that the oxidation product transfers heat to the oxidizing fluid.

3033. The system of claim 3026, wherein the second conduit is further configured to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the second conduit.

3034. The system of claim 3026, wherein the second conduit is further configured to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the second conduit and a pressure of the oxidation product in the second conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.

3035. The system of claim 3026, wherein the second conduit is further configured to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3036. The system of claim 3026, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3037. The system of claim 3026, further comprising a center conduit disposed within the second conduit, wherein the center conduit is configured to provide the oxidizing fluid into the opening during use, and wherein the second conduit is further configured to remove an oxidation product during use.

3038. The system of claim 3026, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

3039. The system of claim 3026, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3040. The system of claim 3026, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3041. The system of claim 3026, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3042. The system of claim 3026, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3043. The system of claim 3026, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3044. The system of claim 3026, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

3045. The system of claim 3026, wherein the system is further configured such that transferred heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.

3046. A system configurable to heat a hydrocarbon containing formation, comprising:

a conductor configurable to be disposed in a first conduit, wherein the first conduit is configurable to be disposed in an opening in the formation, and wherein the conductor is further configurable to provide heat to at least a portion of the formation during use;

a second conduit configurable to be disposed in the opening, wherein the second conduit is further configurable to provide an oxidizing fluid from an oxidizing fluid source to a reaction zone in the formation during use, and wherein the system is configurable to allow the oxidizing fluid to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and

wherein the system is further configurable to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

3047. The system of claim 3046, wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.

3048. The system of claim 3046, wherein the second conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening.

3049. The system of claim 3046, wherein the second conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.

3050. The system of claim 3046, wherein the second conduit is further configurable to be cooled with the oxidizing fluid to reduce heating of the second conduit by oxidation.

3051. The system of claim 3046, wherein the second conduit is further configurable to remove an oxidation product.

3052. The system of claim 3046, wherein the second conduit is further configurable to remove an oxidation product such that the oxidation product transfers heat to the oxidizing fluid.

3053. The system of claim 3046, wherein the second conduit is further configurable to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the second conduit.

3054. The system of claim 3046, wherein the second conduit is further configurable to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the second conduit and a pressure of the oxidation product in the second conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.

3055. The system of claim 3046, wherein the second conduit is further configurable to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3056. The system of claim 3046, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3057. The system of claim 3046, further comprising a center conduit disposed within the second conduit, wherein the center conduit is configurable to provide the oxidizing fluid into the opening during use, and wherein the second conduit is further configurable to remove an oxidation product during use.

3058. The system of claim 3046, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

3059. The system of claim 3046, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3060. The system of claim 3046, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3061. The system of claim 3046, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3062. The system of claim 3046, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3063. The system of claim 3046, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3064. The system of claim 3046, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

3065. The system of claim 3046, wherein the system is further configurable such that transferred heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.

3066. The system of claim 3046, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

a conductor disposed in a first conduit, wherein the first conduit is disposed in an opening in the formation, and wherein the conductor is configured to provide heat to at least a portion of the formation during use;

an oxidizing fluid source;

a second conduit disposed in the opening, wherein the second conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and

wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

3067. An in situ method for heating a hydrocarbon containing formation, comprising:

heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidizing fluid, wherein heating comprises applying an electrical current to a conductor disposed in a first conduit to provide heat to the portion, and wherein the first conduit is disposed within the opening;

providing the oxidizing fluid to a reaction zone in the formation;

allowing the oxidizing fluid to react with at least a portion of the hydrocarbons at the reaction zone to generate heat at the reaction zone; and

transferring the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the formation.

3068. The method of claim 3067, further comprising transporting the oxidizing fluid through the reaction zone by diffusion.

3069. The method of claim 3067, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a second conduit disposed in the opening.

3070. The method of claim 3067, further comprising controlling a flow of the oxidizing fluid with critical flow orifices of a second conduit disposed in the opening such that a rate of oxidation is controlled.

3071. The method of claim 3067, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over time within the reaction zone.

3072. The method of claim 3067, wherein a second conduit is disposed in the opening, the method further comprising cooling the second conduit with the oxidizing fluid to reduce heating of the second conduit by oxidation.

3073. The method of claim 3067, wherein a second conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the second conduit.

3074. The method of claim 3067, wherein a second conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the second conduit and transferring heat from the oxidation product in the conduit to the oxidizing fluid in the second conduit.

3075. The method of claim 3067, wherein a second conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the second conduit, wherein a flow rate of the oxidizing fluid in the second conduit is approximately equal to a flow rate of the oxidation product in the second conduit.

3076. The method of claim 3067, wherein a second conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the second conduit and controlling a pressure between the oxidizing fluid and the oxidation product in the second conduit to reduce contamination of the oxidation product by the oxidizing fluid.

3077. The method of claim 3067, wherein a second conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.

3078. The method of claim 3067, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.

3079. The method of claim 3067, wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the outer conduit.

3080. The method of claim 3067, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

3081. The method of claim 3067, further comprising removing water from the formation prior to heating the portion.

3082. The method of claim 3067, further comprising controlling the temperature of the formation to substantially inhibit production of oxides of nitrogen during oxidation.

3083. The method of claim 3067, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3084. The method of claim 3067, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3085. The method of claim 3067, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3086. The method of claim 3067, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3087. A system configured to heat a hydrocarbon containing formation, comprising:

an insulated conductor disposed in an opening in the formation, wherein the insulated conductor is configured to provide heat to at least a portion of the formation during use;

an oxidizing fluid source;

a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and

wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

3088. The system of claim 3087, wherein the oxidizing fluid is configured to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.

3089. The system of claim 3087, wherein the conduit comprises orifices, and wherein the orifices are configured to provide the oxidizing fluid into the opening.

3090. The system of claim 3087, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configured to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.

3091. The system of claim 3087, wherein the conduit is configured to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.

3092. The system of claim 3087, wherein the conduit is further configured to remove an oxidation product.

3093. The system of claim 3087, wherein the conduit is further configured to remove an oxidation product, and wherein the conduit is further configured such that the oxidation product transfers substantial heat to the oxidizing fluid.

3094. The system of claim 3087, wherein the conduit is further configured to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

3095. The system of claim 3087, wherein the conduit is further configured to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the second conduit and a pressure of the oxidation product in the conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.

3096. The system of claim 3087, wherein the conduit is further configured to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3097. The system of claim 3087, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3098. The system of claim 3087, further comprising a center conduit disposed within the conduit, wherein the center conduit is configured to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configured to remove an oxidation product during use.

3099. The system of claim 3087, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

3100. The system of claim 3087, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3101. The system of claim 3087, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3102. The system of claim 3087, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3103. The system of claim 3087, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3104. The system of claim 3087, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3105. The system of claim 3087, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

3106. The system of claim 3087, wherein the system is further configured such that transferred heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.

3107. A system configurable to heat a hydrocarbon containing formation, comprising:

an insulated conductor configurable to be disposed in an opening in the formation, wherein the insulated conductor is further configurable to provide heat to at least a portion of the formation during use;

a conduit configurable to be disposed in the opening, wherein the conduit is further configurable to provide an oxidizing fluid from an oxidizing fluid source to a reaction zone in the formation during use, and wherein the system is configurable to allow the oxidizing fluid to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and

wherein the system is further configurable to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

3108. The system of claim 3107, wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.

3109. The system of claim 3107, wherein the conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening.

3110. The system of claim 3107, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.

3111. The system of claim 3107, wherein the conduit is further configurable to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.

3112. The system of claim 3107, wherein the conduit is further configurable to remove an oxidation product.

3113. The system of claim 3107, wherein the conduit is further configurable to remove an oxidation product, such that the oxidation product transfers heat to the oxidizing fluid.

3114. The system of claim 3107, wherein the conduit is further configurable to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

3115. The system of claim 3107, wherein the conduit is further configurable to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.

3116. The system of claim 3107, wherein the conduit is further configurable to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3117. The system of claim 3107, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3118. The system of claim 3107, further comprising a center conduit disposed within the conduit, wherein the center conduit is configurable to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configurable to remove an oxidation product during use.

3119. The system of claim 3107, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

3120. The system of claim 3107, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3121. The system of claim 3107, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3122. The system of claim 3107, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3123. The system of claim 3107, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3124. The system of claim 3107, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3125. The system of claim 3107, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

3126. The system of claim 3107, wherein the system is further configurable such that transferred heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.

3127. The system of claim 3107, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

an insulated conductor disposed in an opening in the formation, wherein the insulated conductor is configured to provide heat to at least a portion of the formation during use;

an oxidizing fluid source;

a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and

wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

3128. An in situ method for heating a hydrocarbon containing formation, comprising:

heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidizing fluid, wherein heating comprises applying an electrical current to an insulated conductor to provide heat to the portion, and wherein the insulated conductor is disposed within the opening;

providing the oxidizing fluid to a reaction zone in the formation;

allowing the oxidizing fluid to react with at least a portion of the hydrocarbons at the reaction zone to generate heat at the reaction zone; and

transferring the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the formation.

3129. The method of claim 3128, further comprising transporting the oxidizing fluid through the reaction zone by diffusion.

3130. The method of claim 3128, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a conduit disposed in the opening.

3131. The method of claim 3128, further comprising controlling a flow of the oxidizing fluid with critical flow orifices of a conduit disposed in the opening such that a rate of oxidation is controlled.

3132. The method of claim 3128, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over time within the reaction zone.

3133. The method of claim 3128, wherein a conduit is disposed in the opening, the method further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.

3134. The method of claim 3128, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit.

3135. The method of claim 3128, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and transferring heat from the oxidation product in the conduit to the oxidizing fluid in the conduit.

3136. The method of claim 3128, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

3137. The method of claim 3128, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and controlling a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.

3138. The method of claim 3128, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.

3139. The method of claim 3128, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.

3140. The method of claim 3128, wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the outer conduit.

3141. The method of claim 3128, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

3142. The method of claim 3128, further comprising removing water from the formation prior to heating the portion.

3143. The method of claim 3128, further comprising controlling the temperature of the formation to substantially inhibit production of oxides of nitrogen during oxidation.

3144. The method of claim 3128, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3145. The method of claim 3128, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3146. The method of claim 3128, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3147. The method of claim 3128, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3148. The method of claim 3128, wherein the pyrolysis zone is substantially adjacent to the reaction zone.

3149. An in situ method for heating a hydrocarbon containing formation, comprising:

heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidizing fluid, wherein the portion is located substantially adjacent to an opening in the formation, wherein heating comprises applying an electrical current to an insulated conductor to provide heat to the portion, wherein the insulated conductor is coupled to a conduit, wherein the conduit comprises critical flow orifices, and wherein the conduit is disposed within the opening;

providing the oxidizing fluid to a reaction zone in the formation;

allowing the oxidizing fluid to react with at least a portion of the hydrocarbons at the reaction zone to generate heat at the reaction zone; and

transferring the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the formation.

3150. The method of claim 3149, further comprising transporting the oxidizing fluid through the reaction zone by difflusion.

3151. The method of claim 3149, further comprising controlling a flow of the oxidizing fluid with the critical flow orifices such that a rate of oxidation is controlled.

3152. The method of claim 3149, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over time within the reaction zone.

3153. The method of claim 3149, further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.

3154. The method of claim 3149, further comprising removing an oxidation product from the formation through the conduit.

3155. The method of claim 3149, further comprising removing an oxidation product from the formation through the conduit and transferring heat from the oxidation product in the conduit to the oxidizing fluid in the conduit.

3156. The method of claim 3149, further comprising removing an oxidation product from the formation through the conduit, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

3157. The method of claim 3149, further comprising removing an oxidation product from the formation through the conduit and controlling a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.

3158. The method of claim 3149, further comprising removing an oxidation product from the formation through the conduit and substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.

3159. The method of claim 3149, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.

3160. The method of claim 3149, wherein a center conduit is disposed within the conduit, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the conduit.

3161. The method of claim 3149, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

3162. The method of claim 3149, further comprising removing water from the formation prior to heating the portion.

3163. The method of claim 3149, further comprising controlling the temperature of the formation to substantially inhibit production of oxides of nitrogen during oxidation.

3164. The method of claim 3149, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3165. The method of claim 3149, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3166. The method of claim 3149, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3167. The method of claim 3149, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3168. The method of claim 3149, wherein the pyrolysis zone is substantially adjacent to the reaction zone.

3169. A system configured to heat a hydrocarbon containing formation, comprising:

at least one elongated member disposed in an opening in the formation, wherein at least the one elongated member is configured to provide heat to at least a portion of the formation during use;

an oxidizing fluid source;

a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and

wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

3170. The system of claim 3169, wherein the oxidizing fluid is configured to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.

3171. The system of claim 3169, wherein the conduit comprises orifices, and wherein the orifices are configured to provide the oxidizing fluid into the opening.

3172. The system of claim 3169, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configured to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.

3173. The system of claim 3169, wherein the conduit is further configured to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.

3174. The system of claim 3169, wherein the conduit is further configured to remove an oxidation product.

3175. The system of claim 3169, wherein the conduit is further configured to remove an oxidation product such that the oxidation product transfers heat to the oxidizing fluid.

3176. The system of claim 3169, wherein the conduit is further configured to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

3177. The system of claim 3169, wherein the conduit is further configured to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.

3178. The system of claim 3169, wherein the conduit is further configured to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3179. The system of claim 3169, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3180. The system of claim 3169, further comprising a center conduit disposed within the conduit, wherein the center conduit is configured to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configured to remove an oxidation product during use.

3181. The system of claim 3169, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

3182. The system of claim 3169, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3183. The system of claim 3169, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3184. The system of claim 3169, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3185. The system of claim 3169, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3186. The system of claim 3169, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3187. The system of claim 3169, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

3188. The system of claim 3169, wherein the system is further configured such that transferred heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.

3189. A system configurable to heat a hydrocarbon containing formation, comprising:

at least one elongated member configurable to be disposed in an opening in the formation, wherein at least the one elongated member is further configurable to provide heat to at least a portion of the formation during use;

a conduit configurable to be disposed in the opening, wherein the conduit is further configurable to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the system is configurable to allow the oxidizing fluid to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and

wherein the system is further configurable to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

3190. The system of claim 3189, wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.

3191. The system of claim 3189, wherein the conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening.

3192. The system of claim 3189, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.

3193. The system of claim 3189, wherein the conduit is further configurable to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.

3194. The system of claim 3189, wherein the conduit is further configurable to remove an oxidation product.

3195. The system of claim 3189, wherein the conduit is further configurable to remove an oxidation product such that the oxidation product transfers heat to the oxidizing fluid.

3196. The system of claim 3189, wherein the conduit is further configurable to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

3197. The system of claim 3189, wherein the conduit is further configurable to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.

3198. The system of claim 3189, wherein the conduit is further configurable to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3199. The system of claim 3189, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3200. The system of claim 3189, further comprising a center conduit disposed within the conduit, wherein the center conduit is configurable to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configurable to remove an oxidation product during use.

3201. The system of claim 3189, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

3202. The system of claim 3189, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3203. The system of claim 3189, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3204. The system of claim 3189, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3205. The system of claim 3189, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3206. The system of claim 3189, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3207. The system of claim 3189, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

3208. The system of claim 3189, wherein the system is further configurable such that transferred heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.

3209. The system of claim 3189, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

at least one elongated member disposed in an opening in the formation, wherein at least the one elongated member is configured to provide heat to at least a portion of the formation during use;

an oxidizing fluid source;

a conduit disposed in the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to a reaction zone in the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at the reaction zone during use such that heat is generated at the reaction zone; and

wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

3210. An in situ method for heating a hydrocarbon containing formation, comprising:

heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidizing fluid;

wherein heating comprises applying an electrical current to at least one elongated member to provide heat to the portion, and wherein at least the one elongated member is disposed within the opening;

providing the oxidizing fluid to a reaction zone in the formation;

allowing the oxidizing fluid to react with at least a portion of the hydrocarbons at the reaction zone to generate heat at the reaction zone; and

transferring the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the formation.

3211. The method of claim 3210, further comprising transporting the oxidizing fluid through the reaction zone by diffusion.

3212. The method of claim 3210, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a conduit disposed in the opening.

3213. The method of claim 3210, further comprising controlling a flow of the oxidizing fluid with critical flow orifices of a conduit disposed in the opening such that a rate of oxidation is controlled.

3214. The method of claim 3210, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over time within the reaction zone.

3215. The method of claim 3210, wherein a conduit is disposed in the opening, the method further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.

3216. The method of claim 3210, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit.

3217. The method of claim 3210, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and transferring heat from the oxidation product in the conduit to the oxidizing fluid in the conduit.

3218. The method of claim 3210, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

3219. The method of claim 3210, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and controlling a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.

3220. The method of claim 3210, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.

3221. The method of claim 3210, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.

3222. The method of claim 3210, wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the outer conduit.

3223. The method of claim 3210, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

3224. The method of claim 3210, further comprising removing water from the formation prior to heating the portion.

3225. The method of claim 3210, further comprising controlling the temperature of the formation to substantially inhibit production of oxides of nitrogen during oxidation.

3226. The method of claim 3210, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3227. The method of claim 3210, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3228. The method of claim 3210, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3229. The method of claim 3210, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3230. The method of claim 3210, wherein the pyrolysis zone is substantially adjacent to the reaction zone.

3231. A system configured to heat a hydrocarbon containing formation, comprising:

a heat exchanger disposed external to the formation, wherein the heat exchanger is configured to heat an oxidizing fluid during use;

a conduit disposed in the opening, wherein the conduit is configured to provide the heated oxidizing fluid from the heat exchanger to at least a portion of the formation during use, wherein the system is configured to allow heat to transfer from the heated oxidizing fluid to at least the portion of the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at a reaction zone in the formation during use such that heat is generated at the reaction zone; and

wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

3232. The system of claim 3231, wherein the oxidizing fluid is configured to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.

3233. The system of claim 3231, wherein the conduit comprises orifices, and wherein the orifices are configured to provide the oxidizing fluid into the opening.

3234. The system of claim 3231, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configured to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.

3235. The system of claim 3231, wherein the conduit is further configured to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.

3236. The system of claim 3231, wherein the conduit is further configured to remove an oxidation product.

3237. The system of claim 3231, wherein the conduit is further configured to remove an oxidation product, such that the oxidation product transfers heat to the oxidizing fluid.

3238. The system of claim 3231, wherein the conduit is further configured to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

3239. The system of claim 3231, wherein the conduit is further configured to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.

3240. The system of claim 3231, wherein the conduit is further configured to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3241. The system of claim 3231, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3242. The system of claim 3231, further comprising a center conduit disposed within the conduit, wherein the center conduit is configured to provide the oxidizing fluid into the opening during use, and wherein the conduit is further configured to remove an oxidation product during use.

3243. The system of claim 3231, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

3244. The system of claim 3231, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3245. The system of claim 3231, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3246. The system of claim 3231, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3247. The system of claim 3231, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3248. The system of claim 3231, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3249. The system of claim 3231, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

3250. A system configurable to heat a hydrocarbon containing formation, comprising:

a heat exchanger configurable to be disposed external to the formation, wherein the heat exchanger is further configurable to heat an oxidizing fluid during use;

a conduit configurable to be disposed in the opening, wherein the conduit is further configurable to provide the heated oxidizing fluid from the heat exchanger to at least a portion of the formation during use, wherein the system is configurable to allow heat to transfer from the heated oxidizing fluid to at least the portion of the formation during use, and wherein the system is further configurable to allow the oxidizing fluid to oxidize at least some hydrocarbons at a reaction zone in the formation during use such that heat is generated at the reaction zone; and

wherein the system is further configurable to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

3251. The system of claim 3250, wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.

3252. The system of claim 3250, wherein the conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening.

3253. The system of claim 3250, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled.

3254. The system of claim 3250, wherein the conduit is further configurable to be cooled with the oxidizing fluid such that the conduit is not substantially heated by oxidation.

3255. The system of claim 3250, wherein the conduit is further configurable to remove an oxidation product.

3256. The system of claim 3250, wherein the conduit is further configurable to remove an oxidation product such that the oxidation product transfers heat to the oxidizing fluid.

3257. The system of claim 3250, wherein the conduit is further configurable to remove an oxidation product, and wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

3258. The system of claim 3250, wherein the conduit is further configurable to remove an oxidation product, and wherein a pressure of the oxidizing fluid in the conduit and a pressure of the oxidation product in the conduit are controlled to reduce contamination of the oxidation product by the oxidizing fluid.

3259. The system of claim 3250, wherein the conduit is further configurable to remove an oxidation product, and wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3260. The system of claim 3250, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone.

3261. The system of claim 3250, further comprising a center conduit disposed within the conduit, wherein the center conduit is configurable to provide the oxidizing fluid into the opening during use, and wherein the second conduit is further configurable to remove an oxidation product during use.

3262. The system of claim 3250, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

3263. The system of claim 3250, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3264. The system of claim 3250, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3265. The system of claim 3250, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3266. The system of claim 3250, further comprising an overburden casing coupled to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3267. The system of claim 3250, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3268. The system of claim 3250, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

3269. The system of claim 3250, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

a heat exchanger disposed external to the formation, wherein the heat exchanger is configured to heat an oxidizing fluid during use;

a conduit disposed in the opening, wherein the conduit is configured to provide the heated oxidizing fluid from the heat exchanger to at least a portion of the formation during use, wherein the system is configured to allow heat to transfer from the heated oxidizing fluid to at least the portion of the formation during use, and wherein the oxidizing fluid is selected to oxidize at least some hydrocarbons at a reaction zone in the formation during use such that heat is generated at the reaction zone; and

wherein the system is configured to allow heat to transfer substantially by conduction from the reaction zone to a pyrolysis zone of the formation during use.

3270. An in situ method for heating a hydrocarbon containing formation, comprising:

heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidizing fluid, wherein heating comprises;

heating the oxidizing fluid with a heat exchanger, wherein the heat exchanger is disposed external to the formation;

providing the heated oxidizing fluid from the heat exchanger to the portion of the formation; and

allowing heat to transfer from the heated oxidizing fluid to the portion of the formation;

providing the oxidizing fluid to a reaction zone in the formation;

allowing the oxidizing fluid to react with at least a portion of the hydrocarbons at the reaction zone to generate heat at the reaction zone; and

transferring the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the formation.

3271. The method of claim 3270, further comprising transporting the oxidizing fluid through the reaction zone by diffusion.

3272. The method of claim 3270, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a conduit disposed in the opening.

3273. The method of claim 3270, further comprising controlling a flow of the oxidizing fluid with critical flow orifices of a conduit disposed in the opening such that a rate of oxidation is controlled.

3274. The method of claim 3270, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over time within the reaction zone.

3275. The method of claim 3270, wherein a conduit is disposed in the opening, the method further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.

3276. The method of claim 3270, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit.

3277. The method of claim 3270, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and transferring heat from the oxidation product in the conduit to the oxidizing fluid in the conduit.

3278. The method of claim 3270, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

3279. The method of claim 3270, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and controlling a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.

3280. The method of claim 3270, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.

3281. The method of claim 3270, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.

3282. The method of claim 3270, wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the outer conduit.

3283. The method of claim 3270, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

3284. The method of claim 3270, further comprising removing water from the formation prior to heating the portion.

3285. The method of claim 3270, further comprising controlling the temperature of the formation to substantially inhibit production of oxides of nitrogen during oxidation.

3286. The method of claim 3270, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3287. The method of claim 3270, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3288. The method of claim 3270, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3289. The method of claim 3270, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3290. The method of claim 3270, wherein the pyrolysis zone is substantially adjacent to the reaction zone.

3291. An in situ method for heating a hydrocarbon containing formation, comprising:

heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidizing fluid, wherein heating comprises;

oxidizing a fuel gas in a heater, wherein the heater is disposed external to the formation;

providing the oxidized fuel gas from the heater to the portion of the formation; and

allowing heat to transfer from the oxidized fuel gas to the portion of the formation;

providing the oxidizing fluid to a reaction zone in the formation;

allowing the oxidizing fluid to react with at least a portion of the hydrocarbons at the reaction zone to generate heat at the reaction zone; and

transferring the generated heat substantially by conduction from the reaction zone to a pyrolysis zone in the formation.

3292. The method of claim 3291, further comprising transporting the oxidizing fluid through the reaction zone by difflusion.

3293. The method of claim 3291, further comprising directing at least a portion of the oxidizing fluid into the opening through orifices of a conduit disposed in the opening.

3294. The method of claim 3291, further comprising controlling a flow of the oxidizing fluid with critical flow orifices of a conduit disposed in the opening such that a rate of oxidation is controlled.

3295. The method of claim 3291, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over time within the reaction zone.

3296. The method of claim 3291, wherein a conduit is disposed in the opening, the method further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.

3297. The method of claim 3291, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit.

3298. The method of claim 3291, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and transferring heat from the oxidation product in the conduit to the oxidizing fluid in the conduit.

3299. The method of claim 3291, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit, wherein a flow rate of the oxidizing fluid in the conduit is approximately equal to a flow rate of the oxidation product in the conduit.

3300. The method of claim 3291, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and controlling a pressure between the oxidizing fluid and the oxidation product in the conduit to reduce contamination of the oxidation product by the oxidizing fluid.

3301. The method of claim 3291, wherein a conduit is disposed within the opening, the method further comprising removing an oxidation product from the formation through the conduit and substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.

3302. The method of claim 3291, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.

3303. The method of claim 3291, wherein a center conduit is disposed within an outer conduit, and wherein the outer conduit is disposed within the opening, the method further comprising providing the oxidizing fluid into the opening through the center conduit and removing an oxidation product through the outer conduit.

3304. The method of claim 3291, wherein the portion of the formation extends radially from the opening a width of less than approximately 0.2 m.

3305. The method of claim 3291, further comprising removing water from the formation prior to heating the portion.

3306. The method of claim 3291, further comprising controlling the temperature of the formation to substantially inhibit production of oxides of nitrogen during oxidation.

3307. The method of claim 3291, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3308. The method of claim 3291, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3309. The method of claim 3291, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3310. The method of claim 3291, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

3311. The method of claim 3291, wherein the pyrolysis zone is substantially adjacent to the reaction zone.

3312. A system configured to heat a hydrocarbon containing formation, comprising:

an insulated conductor disposed within an open wellbore in the formation, wherein the insulated conductor is configured to provide radiant heat to at least a portion of the formation during use; and

wherein the system is configured to allow heat to transfer from the insulated conductor to a selected section of the formation during use.

3313. The system of claim 3312, wherein the insulated conductor is further configured to generate heat during application of an electrical current to the insulated conductor during use.

3314. The system of claim 3312, further comprising a support member, wherein the support member is configured to support the insulated conductor.

3315. The system of claim 3312, further comprising a support member and a centralizer, wherein the support member is configured to support the insulated conductor, and wherein the centralizer is configured to maintain a location of the insulated conductor on the support member.

3316. The system of claim 3312, wherein the open wellbore comprises a diameter of at least approximately 5 cm.

3317. The system of claim 3312, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

3318. The system of claim 3312, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a rubber insulated conductor.

3319. The system of claim 3312, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a copper wire.

3320. The system of claim 3312, further comprising a lead-in conductor coupled to the insulated conductor with a cold pin transition conductor.

3321. The system of claim 3312, further comprising a lead-in conductor coupled to the insulated conductor with a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

3322. The system of claim 3312, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material is disposed in a sheath.

3323. The system of claim 3312, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the conductor comprises a copper-nickel alloy.

3324. The system of claim 3312, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7% nickel by weight to approximately 12% nickel by weight.

3325. The system of claim 3312, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 2% nickel by weight to approximately 6% nickel by weight.

3326. The system of claim 3312, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises a thermally conductive material.

3327. The system of claim 3312, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises magnesium oxide.

3328. The system of claim 3312, wherein the insulated conductor comprises a conductor is disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.

3329. The system of claim 3312, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises aluminum oxide and magnesium oxide.

3330. The system of claim 3312, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configured to occupy porous spaces within the magnesium oxide.

3331. The system of claim 3312, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material is disposed in a sheath, and wherein the sheath comprises a corrosion-resistant material.

3332. The system of claim 3312, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.

3333. The system of claim 3312, further comprising two additional insulated conductors, wherein the insulated conductor and the two additional insulated conductors are configured in a 3-phase Y configuration.

3334. The system of claim 3312, further comprising an additional insulated conductor, wherein the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configured in a series electrical configuration.

3335. The system of claim 3312, further comprising an additional insulated conductor, wherein the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configured in a parallel electrical configuration.

3336. The system of claim 3312, wherein the insulated conductor is configured to generate radiant heat of approximately 500 W/m to approximately 1150 W/m during use.

3337. The system of claim 3312, further comprising a support member configured to support the insulated conductor, wherein the support member comprises orifices configured to provide fluid flow through the support member into the open wellbore during use.

3338. The system of claim 3312, further comprising a support member configured to support the insulated conductor, wherein the support member comprises critical flow orifices configured to provide a substantially constant amount of fluid flow through the support member into the open wellbore during use.

3339. The system of claim 3312, further comprising a tube coupled to the insulated conductor, wherein the tube is configured to provide a flow of fluid into the open wellbore during use.

3340. The system of claim 3312, further comprising a tube coupled to the insulated conductor, wherein the tube comprises critical flow orifices configured to provide a substantially constant amount of fluid flow through the support member into the open wellbore during use.

3341. The system of claim 3312, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation.

3342. The system of claim 3312, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3343. The system of claim 3312, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3344. The system of claim 3312, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the open wellbore.

3345. The system of claim 3312, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the open wellbore, and wherein the packing material is configured to substantially inhibit a flow of fluid between the open wellbore and the overburden casing during use.

3346. The system of claim 3312, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the open wellbore, and wherein the packing material comprises cement.

3347. The system of claim 3312, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, the system further comprising a wellhead coupled to the overburden casing and a lead-in conductor coupled to the insulated conductor, wherein the wellhead is disposed external to the overburden, wherein the wellhead comprises at least one sealing flange, and wherein at least the one sealing flange is configured to couple to the lead-in conductor.

3348. The system of claim 3312, wherein the system is further configured to transfer heat such that the transferred heat can pyrolyze at least some of the hydrocarbons in the selected section.

3349. A system configurable to heat a hydrocarbon containing formation, comprising:

an insulated conductor configurable to be disposed within an open wellbore in the formation, wherein the insulated conductor is further configurable to provide radiant heat to at least a portion of the formation during use; and

wherein the system is configurable to allow heat to transfer from the insulated conductor to a selected section of the formation during use.

3350. The system of claim 3349, wherein the insulated conductor is further configurable to generate heat during application of an electrical current to the insulated conductor during use.

3351. The system of claim 3349, further comprising a support member, wherein the support member is configurable to support the insulated conductor.

3352. The system of claim 3349, further comprising a support member and a centralizer, wherein the support member is configurable to support the insulated conductor, and wherein the centralizer is configurable to maintain a location of the insulated conductor on the support member.

3353. The system of claim 3349, wherein the open wellbore comprises a diameter of at least approximately 5 cm.

3354. The system of claim 3349, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.

3355. The system of claim 3349, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a rubber insulated conductor.

3356. The system of claim 3349, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a copper wire.

3357. The system of claim 3349, further comprising a lead-in conductor coupled to the insulated conductor with a cold pin transition conductor.

3358. The system of claim 3349, further comprising a lead-in conductor coupled to the insulated conductor with a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

3359. The system of claim 3349, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material is disposed in a sheath.

3360. The system of claim 3349, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the conductor comprises a copper-nickel alloy.

3361. The system of claim 3349, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7% nickel by weight to approximately 12% nickel by weight.

3362. The system of claim 3349, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 2% nickel by weight to approximately 6% nickel by weight.

3363. The system of claim 3349, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises a thermally conductive material.

3364. The system of claim 3349, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises magnesium oxide.

3365. The system of claim 3349, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.

3366. The system of claim 3349, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises aluminum oxide and magnesium oxide.

3367. The system of claim 3349, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configurable to occupy porous spaces within the magnesium oxide.

3368. The system of claim 3349, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material is disposed in a sheath, and wherein the sheath comprises a corrosion-resistant material.

3369. The system of claim 3349, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.

3370. The system of claim 3349, further comprising two additional insulated conductors, wherein the insulated conductor and the two additional insulated conductors are configurable in a 3-phase Y configuration.

3371. The system of claim 3349, further comprising an additional insulated conductor, wherein the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configurable in a series electrical configuration.

3372. The system of claim 3349, further comprising an additional insulated conductor, wherein the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configurable in a parallel electrical configuration.

3373. The system of claim 3349, wherein the insulated conductor is configurable to generate radiant heat of approximately 500 W/m to approximately 1150 W/m during use.

3374. The system of claim 3349, further comprising a support member configurable to support the insulated conductor, wherein the support member comprises orifices configurable to provide fluid flow through the support member into the open wellbore during use.

3375. The system of claim 3349, further comprising a support member configurable to support the insulated conductor, wherein the support member comprises critical flow orifices configurable to provide a substantially constant amount of fluid flow through the support member into the open wellbore during use.

3376. The system of claim 3349, further comprising a tube coupled to the insulated conductor, wherein the tube is configurable to provide a flow of fluid into the open wellbore during use.

3377. The system of claim 3349, further comprising a tube coupled to the first insulated conductor, wherein the tube comprises critical flow orifices configurable to provide a substantially constant amount of fluid flow through the support member into the open wellbore during use.

3378. The system of claim 3349, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation.

3379. The system of claim 3349, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3380. The system of claim 3349, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3381. The system of claim 3349, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the open wellbore.

3382. The system of claim 3349, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the open wellbore, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the open wellbore and the overburden casing during use.

3383. The system of claim 3349, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the open wellbore, and wherein the packing material comprises cement.

3384. The system of claim 3349, further comprising an overburden casing coupled to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, the system further comprising a wellhead coupled to the overburden casing and a lead-in conductor coupled to the insulated conductor, wherein the wellhead is disposed external to the overburden, wherein the wellhead comprises at least one sealing flange, and wherein at least the one sealing flange is configurable to couple to the lead-in conductor.

3385. The system of claim 3349, wherein the system is further configured to transfer heat such that the transferred heat can pyrolyze at least some hydrocarbons in the selected section.

3386. The system of claim 3349, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

an insulated conductor disposed within an open wellbore in the formation, wherein the insulated conductor is configured to provide radiant heat to at least a portion of the formation during use; and

wherein the system is configured to allow heat to transfer from the insulated conductor to a selected section of the formation during use.

3387. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to an insulated conductor to provide radiant heat to at least a portion of the formation, wherein the insulated conductor is disposed within an open wellbore in the formation; and

allowing the radiant heat to transfer from the insulated conductor to a selected section of the formation.

3388. The method of claim 3387, further comprising supporting the insulated conductor on a support member.

3389. The method of claim 3387, further comprising supporting the insulated conductor on a support member and maintaining a location of the insulated conductor on the support member with a centralizer.

3390. The method of claim 3387, wherein the insulated conductor is coupled to two additional insulated conductors, wherein the insulated conductor and the two insulated conductors are disposed within the open wellbore, and wherein the three insulated conductors are electrically coupled in a 3-phase Y configuration.

3391. The method of claim 3387, wherein an additional insulated conductor is disposed within the open wellbore.

3392. The method of claim 3387, wherein an additional insulated conductor is disposed within the open wellbore, and wherein the insulated conductor and the additional insulated conductor are electrically coupled in a series configuration.

3393. The method of claim 3387, wherein an additional insulated conductor is disposed within the open wellbore, and wherein the insulated conductor and the additional insulated conductor are electrically coupled in a parallel configuration.

3394. The method of claim 3387, wherein the provided heat comprises approximately 500 W/m to approximately 1150 W/m.

3395. The method of claim 3387, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the conductor comprises a copper-nickel alloy.

3396. The method of claim 3387, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7% nickel by weight to approximately 12% nickel by weight.

3397. The method of claim 3387, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 2% nickel by weight to approximately 6% nickel by weight.

3398. The method of claim 3387, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises magnesium oxide.

3399. The method of claim 3387, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.

3400. The method of claim 3387, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises aluminum oxide and magnesium oxide.

3401. The method of claim 3387, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configured to occupy porous spaces within the magnesium oxide.

3402. The method of claim 3387, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises a corrosion-resistant material.

3403. The method of claim 3387, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.

3404. The method of claim 3387, further comprising supporting the insulated conductor on a support member and flowing a fluid into the open wellbore through an orifice in the support member.

3405. The method of claim 3387, further comprising supporting the insulated conductor on a support member and flowing a substantially constant amount of fluid into the open wellbore through critical flow orifices in the support member.

3406. The method of claim 3387, wherein a perforated tube is disposed in the open wellbore proximate to the insulated conductor, the method further comprising flowing a fluid into the open wellbore through the perforated tube.

3407. The method of claim 3387, wherein a tube is disposed in the open wellbore proximate to the insulated conductor, the method further comprising flowing a substantially constant amount of fluid into the open wellbore through critical flow orifices in the tube.

3408. The method of claim 3387, further comprising supporting the insulated conductor on a support member and flowing a corrosion inhibiting fluid into the open wellbore through an orifice in the support member.

3409. The method of claim 3387, wherein a perforated tube is disposed in the open wellbore proximate to the insulated conductor, the method further comprising flowing a corrosion inhibiting fluid into the open wellbore through the perforated tube.

3410. The method of claim 3387, further comprising determining a temperature distribution in the insulated conductor using an electromagnetic signal provided to the insulated conductor.

3411. The method of claim 3387, further comprising monitoring a leakage current of the insulated conductor.

3412. The method of claim 3387, further comprising monitoring the applied electrical current.

3413. The method of claim 3387, further comprising monitoring a voltage applied to the insulated conductor.

3414. The method of claim 3387, further comprising monitoring a temperature in the insulated conductor with at least one thermocouple.

3415. The method of claim 3387, further comprising electrically coupling a lead-in conductor to the insulated conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

3416. The method of claim 3387, further comprising electrically coupling a lead-in conductor to the insulated conductor using a cold pin transition conductor.

3417. The method of claim 3387, further comprising electrically coupling a lead-in conductor to the insulated conductor using a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

3418. The method of claim 3387, further comprising coupling an overburden casing to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation.

3419. The method of claim 3387, further comprising coupling an overburden casing to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3420. The method of claim 3387, further comprising coupling an overburden casing to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3421. The method of claim 3387, further comprising coupling an overburden casing to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the open wellbore.

3422. The method of claim 3387, further comprising coupling an overburden casing to the open wellbore, wherein the overburden casing is disposed in an overburden of the formation, and wherein the method further comprises inhibiting a flow of fluid between the open wellbore and the overburden casing with a packing material.

3423. The method of claim 3387, further comprising heating at least the portion of the formation to pyrolyze at least some hydrocarbons within the formation.

3424. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to an insulated conductor to provide heat to at least a portion of the formation, wherein the insulated conductor is disposed within an opening in the formation; and

allowing the heat to transfer from the insulated conductor to a section of the formation.

3425. The method of claim 3424, further comprising supporting the insulated conductor on a support member.

3426. The method of claim 3424, further comprising supporting the insulated conductor on a support member and maintaining a location of the first insulated conductor on the support member with a centralizer.

3427. The method of claim 3424, wherein the insulated conductor is coupled to two additional insulated conductors, wherein the insulated conductor and the two insulated conductors are disposed within the opening, and wherein the three insulated conductors are electrically coupled in a 3-phase Y configuration.

3428. The method of claim 3424, wherein an additional insulated conductor is disposed within the opening.

3429. The method of claim 3424, wherein an additional insulated conductor is disposed within the opening, and wherein the insulated conductor and the additional insulated conductor are electrically coupled in a series configuration.

3430. The method of claim 3424, wherein an additional insulated conductor is disposed within the opening, and wherein the insulated conductor and the additional insulated conductor are electrically coupled in a parallel configuration.

3431. The method of claim 3424, wherein the provided heat comprises approximately 500 W/m to approximately 1150 W/m.

3432. The method of claim 3424, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the conductor comprises a copper-nickel alloy.

3433. The method of claim 3424, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7% nickel by weight to approximately 12% nickel by weight.

3434. The method of claim 3424, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 2% nickel by weight to approximately 6% nickel by weight.

3435. The method of claim 3424, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises magnesium oxide.

3436. The method of claim 3424, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.

3437. The method of claim 3424, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises aluminum oxide and magnesium oxide.

3438. The method of claim 3424, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configured to occupy porous spaces within the magnesium oxide.

3439. The method of claim 3424, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises a corrosion-resistant material.

3440. The method of claim 3424, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.

3441. The method of claim 3424, further comprising supporting the insulated conductor on a support member and flowing a fluid into the opening through an orifice in the support member.

3442. The method of claim 3424, further comprising supporting the insulated conductor on a support member and flowing a substantially constant amount of fluid into the opening through critical flow orifices in the support member.

3443. The method of claim 3424, wherein a perforated tube is disposed in the opening proximate to the insulated conductor, the method further comprising flowing a fluid into the opening through the perforated tube.

3444. The method of claim 3424, wherein a tube is disposed in the opening proximate to the insulated conductor, the method further comprising flowing a substantially constant amount of fluid into the opening through critical flow orifices in the tube.

3445. The method of claim 3424, further comprising supporting the insulated conductor on a support member and flowing a corrosion inhibiting fluid into the opening through an orifice in the support member.

3446. The method of claim 3424, wherein a perforated tube is disposed in the opening proximate to the insulated conductor, the method further comprising flowing a corrosion inhibiting fluid into the opening through the perforated tube.

3447. The method of claim 3424, further comprising determining a temperature distribution in the insulated conductor using an electromagnetic signal provided to the insulated conductor.

3448. The method of claim 3424, further comprising monitoring a leakage current of the insulated conductor.

3449. The method of claim 3424, further comprising monitoring the applied electrical current.

3450. The method of claim 3424, further comprising monitoring a voltage applied to the insulated conductor.

3451. The method of claim 3424, further comprising monitoring a temperature in the insulated conductor with at least one thermocouple.

3452. The method of claim 3424, further comprising electrically coupling a lead-in conductor to the insulated conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

3453. The method of claim 3424, further comprising electrically coupling a lead-in conductor to the insulated conductor using a cold pin transition conductor.

3454. The method of claim 3424, further comprising electrically coupling a lead-in conductor to the insulated conductor using a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

3455. The method of claim 3424, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3456. The method of claim 3424, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3457. The method of claim 3424, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3458. The method of claim 3424, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3459. The method of claim 3424, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with a packing material.

3460. The method of claim 3424, further comprising heating at least the portion of the formation to substantially pyrolyze at least some hydrocarbons within the formation.

3461. A system configured to heat a hydrocarbon containing formation, comprising:

an insulated conductor disposed within an opening in the formation, wherein the insulated conductor is configured to provide heat to at least a portion of the formation during use, wherein the insulated conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7% nickel by weight to approximately 12% nickel by weight; and

wherein the system is configured to allow heat to transfer from the insulated conductor to a selected section of the formation during use.

3462. The system of claim 3461, wherein the insulated conductor is further configured to generate heat during application of an electrical current to the insulated conductor during use.

3463. The system of claim 3461, further comprising a support member, wherein the support member is configured to support the insulated conductor.

3464. The system of claim 3461, further comprising a support member and a centralizer, wherein the support member is configured to support the insulated conductor, and wherein the centralizer is configured to maintain a location of the insulated conductor on the support member.

3465. The system of claim 3461, wherein the opening comprises a diameter of at least approximately 5 cm.

3466. The system of claim 3461, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

3467. The system of claim 3461, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a rubber insulated conductor.

3468. The system of claim 3461, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a copper wire.

3469. The system of claim 3461, further comprising a lead-in conductor coupled to the insulated conductor with a cold pin transition conductor.

3470. The system of claim 3461, further comprising a lead-in conductor coupled to the insulated conductor with a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

3471. The system of claim 3461, wherein the copper-nickel alloy is disposed in an electrically insulating material, and wherein the electrically insulating material comprises a thermally conductive material.

3472. The system of claim 3461, wherein the copper-nickel alloy is disposed in an electrically insulating material, and wherein the electrically insulating material comprises magnesium oxide.

3473. The system of claim 3461, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.

3474. The system of claim 3461, wherein the copper-nickel alloy is disposed in an electrically insulating material, and wherein the electrically insulating material comprises aluminum oxide and magnesium oxide.

3475. The system of claim 3461, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configured to occupy porous spaces within the magnesium oxide.

3476. The system of claim 3461, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the electrically insulating material is disposed in a sheath, and wherein the sheath comprises a corrosion-resistant material.

3477. The system of claim 3461, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the electrically insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.

3478. The system of claim 3461, further comprising two additional insulated conductors, wherein the insulated conductor and the two additional insulated conductors are configured in a 3-phase Y configuration.

3479. The system of claim 3461, further comprising an additional insulated conductor, wherein the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configured in a series electrical configuration.

3480. The system of claim 3461, further comprising an additional insulated conductor, wherein the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configured in a parallel electrical configuration.

3481. The system of claim 3461, wherein the insulated conductor is configured to generate radiant heat of approximately 500 W/m to approximately 1150 W/m during use.

3482. The system of claim 3461, further comprising a support member configured to support the insulated conductor, wherein the support member comprises orifices configured to provide fluid flow through the support member into the opening during use.

3483. The system of claim 3461, further comprising a support member configured to support the insulated conductor, wherein the support member comprises critical flow orifices configured to provide a substantially constant amount of fluid flow through the support member into the opening during use.

3484. The system of claim 3461, further comprising a tube coupled to the insulated conductor, wherein the tube is configured to provide a flow of fluid into the opening during use.

3485. The system of claim 3461, further comprising a tube coupled to the insulated conductor, wherein the tube comprises critical flow orifices configured to provide a substantially constant amount of fluid flow through the support member into the opening during use.

3486. The system of claim 3461, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3487. The system of claim 3461, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3488. The system of claim 3461, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3489. The system of claim 3461, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3490. The system of claim 3461, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3491. The system of claim 3461, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

3492. The system of claim 3461, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, the system further comprising a wellhead coupled to the overburden casing and a lead-in conductor coupled to the insulated conductor, wherein the wellhead is disposed external to the overburden, wherein the wellhead comprises at least one sealing flange, and wherein at least the one sealing flange is configured to couple to the lead-in conductor.

3493. The system of claim 3461, wherein the system is further configured to transfer heat such that the transferred heat can pyrolyze at least some hydrocarbons in the selected section.

3494. A system configurable to heat a hydrocarbon containing formation, comprising:

an insulated conductor configurable to be disposed within an opening in the formation, wherein the insulated conductor is further configurable to provide heat to at least a portion of the formation during use, wherein the insulated conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7% nickel by weight to approximately 12% nickel by weight; and

wherein the system is configurable to allow heat to transfer from the insulated conductor to a selected section of the formation during use.

3495. The system of claim 3494, wherein the insulated conductor is further configurable to generate heat during application of an electrical current to the insulated conductor during use.

3496. The system of claim 3494, further comprising a support member, wherein the support member is configurable to support the insulated conductor.

3497. The system of claim 3494, further comprising a support member and a centralizer, wherein the support member is configurable to support the insulated conductor, and wherein the centralizer is configurable to maintain a location of the insulated conductor on the support member.

3498. The system of claim 3494, wherein the opening comprises a diameter of at least approximately 5 cm.

3499. The system of claim 3494, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.

3500. The system of claim 3494, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a rubber insulated conductor.

3501. The system of claim 3494, further comprising a lead-in conductor coupled to the insulated conductor, wherein the lead-in conductor comprises a copper wire.

3502. The system of claim 3494, further comprising a lead-in conductor coupled to the insulated conductor with a cold pin transition conductor.

3503. The system of claim 3494, further comprising a lead-in conductor coupled to the insulated conductor with a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

3504. The system of claim 3494, wherein the copper-nickel alloy is disposed in an electrically insulating material, and wherein the electrically insulating material comprises a thermally conductive material.

3505. The system of claim 3494, wherein the copper-nickel alloy is disposed in an electrically insulating material, and wherein the electrically insulating material comprises magnesium oxide.

3506. The system of claim 3494, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.

3507. The system of claim 3494, wherein the copper-nickel alloy is disposed in an electrically insulating material, and wherein the electrically insulating material comprises aluminum oxide and magnesium oxide.

3508. The system of claim 3494, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configurable to occupy porous spaces within the magnesium oxide.

3509. The system of claim 3494, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the electrically insulating material is disposed in a sheath, and wherein the sheath comprises a corrosion-resistant material.

3510. The system of claim 3494, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the electrically insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.

3511. The system of claim 3494, further comprising two additional insulated conductors, wherein the insulated conductor and the two additional insulated conductors are configurable in a 3-phase Y configuration.

3512. The system of claim 3494, further comprising an additional insulated conductor, wherein the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configurable in a series electrical configuration.

3513. The system of claim 3494, further comprising an additional insulated conductor, wherein the insulated conductor and the additional insulated conductor are coupled to a support member, and wherein the insulated conductor and the additional insulated conductor are configurable in a parallel electrical configuration.

3514. The system of claim 3494, wherein the insulated conductor is configurable to generate radiant heat of approximately 500 W/m to approximately 1150 W/m during use.

3515. The system of claim 3494, further comprising a support member configurable to support the insulated conductor, wherein the support member comprises orifices configurable to provide fluid flow through the support member into the open wellbore during use.

3516. The system of claim 3494, further comprising a support member configurable to support the insulated conductor, wherein the support member comprises critical flow orifices configurable to provide a substantially constant amount of fluid flow through the support member into the opening during use.

3517. The system of claim 3494, further comprising a tube coupled to the insulated conductor, wherein the tube is configurable to provide a flow of fluid into the opening during use.

3518. The system of claim 3494, further comprising a tube coupled to the insulated conductor, wherein the tube comprises critical flow orifices configurable to provide a substantially constant amount of fluid flow through the support member into the opening during use.

3519. The system of claim 3494, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3520. The system of claim 3494, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3521. The system of claim 3494, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3522. The system of claim 3494, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3523. The system of claim 3494, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3524. The system of claim 3494, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

3525. The system of claim 3494, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, the system further comprising a wellhead coupled to the overburden casing and a lead-in conductor coupled to the insulated conductor, wherein the wellhead is disposed external to the overburden, wherein the wellhead comprises at least one sealing flange, and wherein at least the one sealing flange is configurable to couple to the lead-in conductor.

3526. The system of claim 3494, wherein the system is further configured to transfer heat such that the transferred heat can pyrolyze at least some hydrocarbons in the selected section.

3527. The system of claim 3494, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

an insulated conductor disposed within an opening in the formation, wherein the insulated conductor is configured to provide heat to at least a portion of the formation during use, wherein the insulated conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7% nickel by weight to approximately 12% nickel by weight; and

wherein the system is configured to allow heat to transfer from the insulated conductor to a selected section of the formation during use.

3528. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to an insulated conductor to provide heat to at least a portion of the formation, wherein the insulated conductor is disposed within an opening in the formation, and wherein the insulated conductor comprises a copper-nickel alloy of approximately 7% nickel by weight to approximately 12% nickel by weight; and

allowing the heat to transfer from the insulated conductor to a selected section of the formation.

3529. The method of claim 3528, further comprising supporting the insulated conductor on a support member.

3530. The method of claim 3528, further comprising supporting the insulated conductor on a support member and maintaining a location of the first insulated conductor on the support member with a centralizer.

3531. The method of claim 3528, wherein the insulated conductor is coupled to two additional insulated conductors, wherein the insulated conductor and the two insulated conductors are disposed within the opening, and wherein the three insulated conductors are electrically coupled in a 3-phase Y configuration.

3532. The method of claim 3528, wherein an additional insulated conductor is disposed within the opening.

3533. The method of claim 3528, wherein an additional insulated conductor is disposed within the opening, and wherein the insulated conductor and the additional insulated conductor are electrically coupled in a series configuration.

3534. The method of claim 3528, wherein an additional insulated conductor is disposed within the opening, and wherein the insulated conductor and the additional insulated conductor are electrically coupled in a parallel configuration.

3535. The method of claim 3528, wherein the provided heat comprises approximately 500 W/m to approximately 1150 W/m.

3536. The method of claim 3528, wherein the copper-nickel alloy is disposed in an electrically insulating material.

3537. The method of claim 3528, wherein the copper-nickel alloy is disposed in an electrically insulating material, and wherein the electrically insulating material comprises magnesium oxide.

3538. The method of claim 3528, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.

3539. The method of claim 3528, wherein the copper-nickel alloy is disposed in an electrically insulating material, and wherein the electrically insulating material comprises aluminum oxide and magnesium oxide.

3540. The method of claim 3528, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configured to occupy porous spaces within the magnesium oxide.

3541. The method of claim 3528, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises a corrosion-resistant material.

3542. The method of claim 3528, wherein the copper-nickel alloy is disposed in an electrically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.

3543. The method of claim 3528, further comprising supporting the insulated conductor on a support member and flowing a fluid into the opening through an orifice in the support member.

3544. The method of claim 3528, further comprising supporting the insulated conductor on a support member and flowing a substantially constant amount of fluid into the opening through critical flow orifices in the support member.

3545. The method of claim 3528, wherein a perforated tube is disposed in the opening proximate to the insulated conductor, the method further comprising flowing a fluid into the opening through the perforated tube.

3546. The method of claim 3528, wherein a tube is disposed in the opening proximate to the insulated conductor, the method further comprising flowing a substantially constant amount of fluid into the opening through critical flow orifices in the tube.

3547. The method of claim 3528, further comprising supporting the insulated conductor on a support member and flowing a corrosion inhibiting fluid into the opening through an orifice in the support member.

3548. The method of claim 3528, wherein a perforated tube is disposed in the opening proximate to the insulated conductor, the method further comprising flowing a corrosion inhibiting fluid into the opening through the perforated tube.

3549. The method of claim 3528, further comprising determining a temperature distribution in the insulated conductor using an electromagnetic signal provided to the insulated conductor.

3550. The method of claim 3528, further comprising monitoring a leakage current of the insulated conductor.

3551. The method of claim 3528, further comprising monitoring the applied electrical current.

3552. The method of claim 3528, further comprising monitoring a voltage applied to the insulated conductor.

3553. The method of claim 3528, further comprising monitoring a temperature in the insulated conductor with at least one thermocouple.

3554. The method of claim 3528, further comprising electrically coupling a lead-in conductor to the insulated conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

3555. The method of claim 3528, further comprising electrically coupling a lead-in conductor to the insulated conductor using a cold pin transition conductor.

3556. The method of claim 3528, further comprising electrically coupling a lead-in conductor to the insulated conductor using a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

3557. The method of claim 3528, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3558. The method of claim 3528, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3559. The method of claim 3528, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3560. The method of claim 3528, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3561. The method of claim 3528, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with a packing material.

3562. The method of claim 3528, further comprising heating at least the portion of the formation to substantially pyrolyze at least some hydrocarbons within the formation.

3563. A system configured to heat a hydrocarbon containing formation, comprising:

at least three insulated conductors disposed within an opening in the formation, wherein at least the three insulated conductors are electrically coupled in a 3-phase Y configuration, and wherein at least the three insulated conductors are configured to provide heat to at least a portion of the formation during use; and

wherein the system is configured to allow heat to transfer from at least the three insulated conductors to a selected section of the formation during use.

3564. The system of claim 3563, wherein at least the three insulated conductors are further configured to generate heat during application of an electrical current to at least the three insulated conductors during use.

3565. The system of claim 3563, further comprising a support member, wherein the support member is configured to support at least the three insulated conductors.

3566. The system of claim 3563, further comprising a support member and a centralizer, wherein the support member is configured to support at least the three insulated conductors, and wherein the centralizer is configured to maintain a location of at least the three insulated conductors on the support member.

3567. The system of claim 3563, wherein the opening comprises a diameter of at least approximately 5 cm.

3568. The system of claim 3563, further comprising at least one lead-in conductor coupled to at least the three insulated conductors, wherein at least the one lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

3569. The system of claim 3563, further comprising at least one lead-in conductor coupled to at least the three insulated conductors, wherein at least the one lead-in conductor comprises a rubber insulated conductor.

3570. The system of claim 3563, further comprising at least one lead-in conductor coupled to at least the three insulated conductors, wherein at least the one lead-in conductor comprises a copper wire.

3571. The system of claim 3563, further comprising at least one lead-in conductor coupled to at least the three insulated conductors with a cold pin transition conductor.

3572. The system of claim 3563, further comprising at least one lead-in conductor coupled to at least the three insulated conductors with a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

3573. The system of claim 3563, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the electrically insulating material is disposed in a sheath.

3574. The system of claim 3563, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the conductor comprises a copper-nickel alloy.

3575. The system of claim 3563, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7% nickel by weight to approximately 12% nickel by weight.

3576. The system of claim 3563, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 2% nickel by weight to approximately 6% nickel by weight.

3577. The system of claim 3563, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises a thermally conductive material.

3578. The system of claim 3563, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises magnesium oxide.

3579. The system of claim 3563, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.

3580. The system of claim 3563, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises aluminum oxide and magnesium oxide.

3581. The system of claim 3563, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configured to occupy porous spaces within the magnesium oxide.

3582. The system of claim 3563, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the electrically insulating material is disposed in a sheath, and wherein the sheath comprises a corrosion-resistant material.

3583. The system of claim 3563, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the electrically insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.

3584. The system of claim 3563, wherein at least the three insulated conductors are configured to generate radiant heat of approximately 500 W/m to approximately 1150 W/m of at least the three insulated conductors during use.

3585. The system of claim 3563, further comprising a support member configured to support at least the three insulated conductors, wherein the support member comprises orifices configured to provide fluid flow through the support member into the opening during use.

3586. The system of claim 3563, further comprising a support member configured to support at least the three insulated conductors, wherein the support member comprises critical flow orifices configured to provide a substantially constant amount of fluid flow through the support member into the opening during use.

3587. The system of claim 3563, further comprising a tube coupled to at least the three insulated conductors, wherein the tube is configured to provide a flow of fluid into the opening during use.

3588. The system of claim 3563, further comprising a tube coupled to at least the three insulated conductors, wherein the tube comprises critical flow orifices configured to provide a substantially constant amount of fluid flow through the support member into the opening during use.

3589. The system of claim 3563, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3590. The system of claim 3563, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3591. The system of claim 3563, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3592. The system of claim 3563, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3593. The system of claim 3563, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3594. The system of claim 3563, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

3595. The system of claim 3563, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, the system further comprising a wellhead coupled to the overburden casing and a lead-in conductor coupled to the insulated conductor, wherein the wellhead is disposed external to the overburden, wherein the wellhead comprises at least one sealing flange, and wherein at least the one sealing flange is configured to couple to the lead-in conductor.

3596. The system of claim 3563, wherein the system is further configured to transfer heat such that the transferred heat can pyrolyze at least some hydrocarbons in the selected section.

3597. A system configurable to heat a hydrocarbon containing formation, comprising:

at least three insulated conductors configurable to be disposed within an opening in the formation, wherein at least the three insulated conductors are electrically coupled in a 3-phase Y configuration, and wherein at least the three insulated conductors are further configurable to provide heat to at least a portion of the formation during use; and

wherein the system is configurable to allow heat to transfer from at least the three insulated conductors to a selected section of the formation during use.

3598. The system of claim 3597, wherein at least the three insulated conductors are further configurable to generate heat during application of an electrical current to at least the three insulated conductors during use.

3599. The system of claim 3597, further comprising a support member, wherein the support member is configurable to support at least the three insulated conductors.

3600. The system of claim 3597, further comprising a support member and a centralizer, wherein the support member is configurable to support at least the three insulated conductors, and wherein the centralizer is configurable to maintain a location of at least the three insulated conductors on the support member.

3601. The system of claim 3597, wherein the opening comprises a diameter of at least approximately 5 cm.

3602. The system of claim 3597, further comprising at least one lead-in conductor coupled to at least the three insulated conductors, wherein at least the one lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.

3603. The system of claim 3597, further comprising at least one lead-in conductor coupled to at least the three insulated conductors, wherein at least the one lead-in conductor comprises a rubber insulated conductor.

3604. The system of claim 3597, further comprising at least one lead-in conductor coupled to at least the three insulated conductors, wherein at least the one lead-in conductor comprises a copper wire.

3605. The system of claim 3597, further comprising at least one lead-in conductor coupled to at least the three insulated conductors with a cold pin transition conductor.

3606. The system of claim 3597, further comprising at least one lead-in conductor coupled to at least the three insulated conductors with a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

3607. The system of claim 3597, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the electrically insulating material is disposed in a sheath.

3608. The system of claim 3597, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the conductor comprises a copper-nickel alloy.

3609. The system of claim 3597, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7% nickel by weight to approximately 12% nickel by weight.

3610. The system of claim 3597, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 2% nickel by weight to approximately 6% nickel by weight.

3611. The system of claim 3597, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises a thermally conductive material.

3612. The system of claim 3597, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises magnesium oxide.

3613. The system of claim 3597, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.

3614. The system of claim 3597, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises aluminum oxide and magnesium oxide.

3615. The system of claim 3597, wherein the insulated conductor comprises a conductor disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configurable to occupy porous spaces within the magnesium oxide.

3616. The system of claim 3597, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the electrically insulating material is disposed in a sheath, and wherein the sheath comprises a corrosion-resistant material.

3617. The system of claim 3597, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the electrically insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.

3618. The system of claim 3597, wherein at least the three insulated conductors are configurable to generate radiant heat of approximately 500 W/m to approximately 1150 W/m during use.

3619. The system of claim 3597, further comprising a support member configurable to support at least the three insulated conductors, wherein the support member comprises orifices configurable to provide fluid flow through the support member into the opening during use.

3620. The system of claim 3597, further comprising a support member configurable to support at least the three insulated conductors, wherein the support member comprises critical flow orifices configurable to provide a substantially constant amount of fluid flow through the support member into the opening during use.

3621. The system of claim 3597, further comprising a tube coupled to at least the three insulated conductors, wherein the tube is configurable to provide a flow of fluid into the opening during use.

3622. The system of claim 3597, further comprising a tube coupled to at least the three insulated conductors, wherein the tube comprises critical flow orifices configurable to provide a substantially constant amount of fluid flow through the support member into the opening during use.

3623. The system of claim 3597, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3624. The system of claim 3597, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3625. The system of claim 3597, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3626. The system of claim 3597, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3627. The system of claim 3597, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3628. The system of claim 3597, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

3629. The system of claim 3597, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, the system further comprising a wellhead coupled to the overburden casing and a lead-in conductor coupled to the insulated conductor, wherein the wellhead is disposed external to the overburden, wherein the wellhead comprises at least one sealing flange, and wherein at least the one sealing flange is configurable to couple to the lead-in conductor.

3630. The system of claim 3597, wherein the system is further configured to transfer heat such that the transferred heat can pyrolyze at least some hydrocarbons in the selected section.

3631. The system of claim 3597, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

at least three insulated conductors disposed within an opening in the formation, wherein at least the three insulated conductors are electrically coupled in a 3-phase Y configuration, and wherein at least the three insulated conductors are configured to provide heat to at least a portion of the formation during use; and

wherein the system is configured to allow heat to transfer from at least the three insulated conductors to a selected section of the formation during use.

3632. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to at least three insulated conductors to provide heat to at least a portion of the formation, wherein at least the three insulated conductors are disposed within an opening in the formation; and

allowing the heat to transfer from at least the three insulated conductors to a selected section of the formation.

3633. The method of claim 3632, further comprising supporting at least the three insulated conductors on a support member.

3634. The method of claim 3632, further comprising supporting at least the three insulated conductors on a support member and maintaining a location of at least the three insulated conductors on the support member with a centralizer.

3635. The method of claim 3632, wherein the provided heat comprises approximately 500 W/m to approximately 1150 W/m.

3636. The method of claim 3632, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the conductor comprises a copper-nickel alloy.

3637. The method of claim 3632, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 7% nickel by weight to approximately 12% nickel by weight.

3638. The method of claim 3632, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the conductor comprises a copper-nickel alloy, and wherein the copper-nickel alloy comprises approximately 2% nickel by weight to approximately 6% nickel by weight.

3639. The method of claim 3632, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises magnesium oxide.

3640. The method of claim 3632, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, and wherein the magnesium oxide comprises a thickness of at least approximately 1 mm.

3641. The method of claim 3632, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, and wherein the electrically insulating material comprises aluminum oxide and magnesium oxide.

3642. The method of claim 3632, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the electrically insulating material comprises magnesium oxide, wherein the magnesium oxide comprises grain particles, and wherein the grain particles are configured to occupy porous spaces within the magnesium oxide.

3643. The method of claim 3632, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises a corrosion-resistant material.

3644. The method of claim 3632, wherein at least the three insulated conductors comprise a conductor disposed in an electrically insulating material, wherein the insulating material is disposed in a sheath, and wherein the sheath comprises stainless steel.

3645. The method of claim 3632, further comprising supporting at least the three insulated conductors on a support member and flowing a fluid into the opening through an orifice in the support member.

3646. The method of claim 3632, further comprising supporting at least the three insulated conductors on a support member and flowing a substantially constant amount of fluid into the opening through critical flow orifices in the support member.

3647. The method of claim 3632, wherein a perforated tube is disposed in the opening proximate to at least the three insulated conductors, the method further comprising flowing a fluid into the opening through the perforated tube.

3648. The method of claim 3632, wherein a tube is disposed in the opening proximate to at least the three insulated conductors, the method further comprising flowing a substantially constant amount of fluid into the opening through critical flow orifices in the tube.

3649. The method of claim 3632, further comprising supporting at least the three insulated conductors on a support member and flowing a corrosion inhibiting fluid into the opening through an orifice in the support member.

3650. The method of claim 3632, wherein a perforated tube is disposed in the opening proximate to at least the three insulated conductors, the method further comprising flowing a corrosion inhibiting fluid into the opening through the perforated tube.

3651. The method of claim 3632, further comprising determining a temperature distribution in at least the three insulated conductors using an electromagnetic signal provided to the insulated conductor.

3652. The method of claim 3632, further comprising monitoring a leakage current of at least the three insulated conductors.

3653. The method of claim 3632, further comprising monitoring the applied electrical current.

3654. The method of claim 3632, further comprising monitoring a voltage applied to at least the three insulated conductors.

3655. The method of claim 3632, further comprising monitoring a temperature in at least the three insulated conductors with at least one thermocouple.

3656. The method of claim 3632, further comprising electrically coupling a lead-in conductor to at least the three insulated conductors, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

3657. The method of claim 3632, further comprising electrically coupling a lead-in conductor to at least the three insulated conductors using a cold pin transition conductor.

3658. The method of claim 3632, further comprising electrically coupling a lead-in conductor to at least the three insulated conductors using a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

3659. The method of claim 3632, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3660. The method of claim 3632, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3661. The method of claim 3632, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3662. The method of claim 3632, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3663. The method of claim 3632, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with a packing material.

3664. The method of claim 3632, further comprising heating at least the portion of the formation to substantially pyrolyze at least some of the hydrocarbons within the formation.

3665. A system configured to heat a hydrocarbon containing formation, comprising:

a first conductor disposed in a first conduit, wherein the first conduit is disposed within an opening in the formation, and wherein the first conductor is configured to provide heat to at least a portion of the formation during use; and

wherein the system is configured to allow heat to transfer from the first conductor to a section of the formation during use.

3666. The system of claim 3665, wherein the first conductor is further configured to generate heat during application of an electrical current to the first conductor.

3667. The system of claim 3665, wherein the first conductor comprises a pipe.

3668. The system of claim 3665, wherein the first conductor comprises stainless steel.

3669. The system of claim 3665, wherein the first conduit comprises stainless steel.

3670. The system of claim 3665, further comprising a centralizer configured to maintain a location of the first conductor within the first conduit.

3671. The system of claim 3665, further comprising a centralizer configured to maintain a location of the first conductor within the first conduit, wherein the centralizer comprises ceramic material.

3672. The system of claim 3665, further comprising a centralizer configured to maintain a location of the first conductor within the first conduit, wherein the centralizer comprises ceramic material and stainless steel.

3673. The system of claim 3665, wherein the opening comprises a diameter of at least approximately 5 cm.

3674. The system of claim 3665, further comprising a lead-in conductor coupled to the first conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

3675. The system of claim 3665, further comprising a lead-in conductor coupled to the first conductor, wherein the lead-in conductor comprises copper.

3676. The system of claim 3665, further comprising a sliding electrical connector coupled to the first conductor.

3677. The system of claim 3665, further comprising a sliding electrical connector coupled to the first conductor, wherein the sliding electrical connector is further coupled to the first conduit.

3678. The system of claim 3665, further comprising a sliding electrical connector coupled to the first conductor, wherein the sliding electrical connector is further coupled to the first conduit, and wherein the sliding electrical connector is configured to complete an electrical circuit with the first conductor and the first conduit.

3679. The system of claim 3665, further comprising a second conductor disposed within the first conduit and at least one sliding electrical connector coupled to the first conductor and the second conductor, wherein at least the one sliding electrical connector is configured to generate less heat than the first conductor or the second conductor during use.

3680. The system of claim 3665, wherein the first conduit comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the first conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.

3681. The system of claim 3665, further comprising a fluid disposed within the first conduit, wherein the fluid is configured to maintain a pressure within the first conduit to substantially inhibit deformation of the first conduit during use.

3682. The system of claim 3665, further comprising a thermally conductive fluid disposed within the first conduit.

3683. The system of claim 3665, further comprising a thermally conductive fluid disposed within the first conduit, wherein the thermally conductive fluid comprises helium.

3684. The system of claim 3665, further comprising a fluid disposed within the first conduit, wherein the fluid is configured to substantially inhibit arcing between the first conductor and the first conduit during use.

3685. The system of claim 3665, further comprising a tube disposed within the opening external to the first conduit, wherein the tube is configured to remove vapor produced from at least the heated portion of the formation such that a pressure balance is maintained between the first conduit and the opening to substantially inhibit deformation of the first conduit during use.

3686. The system of claim 3665, wherein the first conductor is further configured to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.

3687. The system of claim 3665, further comprising a second conductor disposed within a second conduit and a third conductor disposed within a third conduit, wherein the first conduit, the second conduit and the third conduit are disposed in different openings of the formation, wherein the first conductor is electrically coupled to the second conductor and the third conductor, and wherein the first, second, and third conductors are configured to operate in a 3-phase Y configuration during use.

3688. The system of claim 3665, further comprising a second conductor disposed within the first conduit, wherein the second conductor is electrically coupled to the first conductor to form an electrical circuit.

3689. The system of claim 3665, further comprising a second conductor disposed within the first conduit, wherein the second conductor is electrically coupled to the first conductor to form an electrical circuit with a connector.

3690. The system of claim 3665, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3691. The system of claim 3665, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3692. The system of claim 3665, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3693. The system of claim 3665, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3694. The system of claim 3665, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3695. The system of claim 3665, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to the first conductor.

3696. The system of claim 3665, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to the first conductor, and wherein the substantially low resistance conductor comprises carbon steel.

3697. The system of claim 3665, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing and a centralizer configured to support the substantially low resistance conductor within the overburden casing.

3698. The system of claim 3665, wherein the heated section of the formation is substantially pyrolyzed.

3699. A system configurable to heat a hydrocarbon containing formation, comprising:

a first conductor configurable to be disposed in a first conduit, wherein the first conduit is configurable to be disposed within an opening in the formation, and wherein the first conductor is further configurable to provide heat to at least a portion of the formation during use; and

wherein the system is configurable to allow heat to transfer from the first conductor to a section of the formation during use.

3700. The system of claim 3699, wherein the first conductor is further configurable to generate heat during application of an electrical current to the first conductor.

3701. The system of claim 3699, wherein the first conductor comprises a pipe.

3702. The system of claim 3699, wherein the first conductor comprises stainless steel.

3703. The system of claim 3699, wherein the first conduit comprises stainless steel.

3704. The system of claim 3699, further comprising a centralizer configurable to maintain a location of the first conductor within the first conduit.

3705. The system of claim 3699, further comprising a centralizer configurable to maintain a location of the first conductor within the first conduit, wherein the centralizer comprises ceramic material.

3706. The system of claim 3699, further comprising a centralizer configurable to maintain a location of the first conductor within the first conduit, wherein the centralizer comprises ceramic material and stainless steel.

3707. The system of claim 3699, wherein the opening comprises a diameter of at least approximately 5 cm.

3708. The system of claim 3699, further comprising a lead-in conductor coupled to the first conductor, wherein the lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.

3709. The system of claim 3699, further comprising a lead-in conductor coupled to the first conductor, wherein the lead-in conductor comprises copper.

3710. The system of claim 3699, further comprising a sliding electrical connector coupled to the first conductor.

3711. The system of claim 3699, further comprising a sliding electrical connector coupled to the first conductor, wherein the sliding electrical connector is further coupled to the first conduit.

3712. The system of claim 3699, further comprising a sliding electrical connector coupled to the first conductor, wherein the sliding electrical connector is further coupled to the first conduit, and wherein the sliding electrical connector is configurable to complete an electrical circuit with the first conductor and the first conduit.

3713. The system of claim 3699, further comprising a second conductor disposed within the first conduit and at least one sliding electrical connector coupled to the first conductor and the second conductor, wherein at least the one sliding electrical connector is configurable to generate less heat than the first conductor or the second conductor during use.

3714. The system of claim 3699, wherein the first conduit comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the first conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.

3715. The system of claim 3699, further comprising a fluid disposed within the first conduit, wherein the fluid is configurable to maintain a pressure within the first conduit to substantially inhibit deformation of the first conduit during use.

3716. The system of claim 3699, further comprising a thermally conductive fluid disposed within the first conduit.

3717. The system of claim 3699, further comprising a thermally conductive fluid disposed within the first conduit, wherein the thermally conductive fluid comprises helium.

3718. The system of claim 3699, further comprising a fluid disposed within the first conduit, wherein the fluid is configurable to substantially inhibit arcing between the first conductor and the first conduit during use.

3719. The system of claim 3699, further comprising a tube disposed within the opening external to the first conduit, wherein the tube is configurable to remove vapor produced from at least the heated portion of the formation such that a pressure balance is maintained between the first conduit and the opening to substantially inhibit deformation of the first conduit during use.

3720. The system of claim 3699, wherein the first conductor is further configurable to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.

3721. The system of claim 3699, further comprising a second conductor disposed within a second conduit and a third conductor disposed within a third conduit, wherein the first conduit, the second conduit and the third conduit are disposed in different openings of the formation, wherein the first conductor is electrically coupled to the second conductor and the third conductor, and wherein the first, second, and third conductors are configurable to operate in a 3-phase Y configuration during use.

3722. The system of claim 3699, further comprising a second conductor disposed within the first conduit, wherein the second conductor is electrically coupled to the first conductor to form an electrical circuit.

3723. The system of claim 3699, further comprising a second conductor disposed within the first conduit, wherein the second conductor is electrically coupled to the first conductor to form an electrical circuit with a connector.

3724. The system of claim 3699, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3725. The system of claim 3699, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3726. The system of claim 3699, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3727. The system of claim 3699, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3728. The system of claim 3699, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3729. The system of claim 3699, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to the first conductor.

3730. The system of claim 3699, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to the first conductor, and wherein the substantially low resistance conductor comprises carbon steel.

3731. The system of claim 3699, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing and a centralizer configurable to support the substantially low resistance conductor within the overburden casing.

3732. The system of claim 3699, wherein the heated section of the formation is substantially pyrolyzed.

3733. The system of claim 3699, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

a first conductor disposed in a first conduit, wherein the first conduit is disposed within an opening in the formation, and wherein the first conductor is configured to provide heat to at least a portion of the formation during use; and

wherein the system is configured to allow heat to transfer from the first conductor to a section of the formation during use.

3734. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to a first conductor to provide heat to at least a portion of the formation, wherein the first conductor is disposed in a first conduit, and wherein the first conduit is disposed within an opening in the formation; and

allowing the heat to transfer from the first conductor to a section of the formation.

3735. The method of claim 3734, wherein the first conductor comprises a pipe.

3736. The method of claim 3734, wherein the first conductor comprises stainless steel.

3737. The method of claim 3734, wherein the first conduit comprises stainless steel.

3738. The method of claim 3734, further comprising maintaining a location of the first conductor in the first conduit with a centralizer.

3739. The method of claim 3734, further comprising maintaining a location of the first conductor in the first conduit with a centralizer, wherein the centralizer comprises ceramic material.

3740. The method of claim 3734, further comprising maintaining a location of the first conductor in the first conduit with a centralizer, wherein the centralizer comprises ceramic material and stainless steel.

3741. The method of claim 3734, further comprising coupling a sliding electrical connector to the first conductor.

3742. The method of claim 3734, further comprising electrically coupling a sliding electrical connector to the first conductor and the first conduit, wherein the first conduit comprises an electrical lead configured to complete an electrical circuit with the first conductor.

3743. The method of claim 3734, further comprising coupling a sliding electrical connector to the first conductor and the first conduit, wherein the first conduit comprises an electrical lead configured to complete an electrical circuit with the first conductor, and wherein the generated heat comprises approximately 20 percent generated by the first conduit.

3744. The method of claim 3734, wherein the provided heat comprises approximately 650 W/m to approximately 1650 W/m.

3745. The method of claim 3734, further comprising determining a temperature distribution in the first conduit using an electromagnetic signal provided to the conduit.

3746. The method of claim 3734, further comprising monitoring the applied electrical current.

3747. The method of claim 3734, further comprising monitoring a voltage applied to the first conductor.

3748. The method of claim 3734, further comprising monitoring a temperature in the conduit with at least one thermocouple.

3749. The method of claim 3734, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3750. The method of claim 3734, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3751. The method of claim 3734, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3752. The method of claim 3734, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3753. The method of claim 3734, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with a packing material.

3754. The method of claim 3734, further comprising coupling an overburden casing to the opening, wherein a substantially low resistance conductor is disposed within the overburden casing, and wherein the substantially low resistance conductor is electrically coupled to the first conductor.

3755. The method of claim 3734, further comprising coupling an overburden casing to the opening, wherein a substantially low resistance conductor is disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to the first conductor, and wherein the substantially low resistance conductor comprises carbon steel.

3756. The method of claim 3734, further comprising coupling an overburden casing to the opening, wherein a substantially low resistance conductor is disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to the first conductor, and wherein the method further comprises maintaining a location of the substantially low resistance conductor in the overburden casing with a centralizer support.

3757. The method of claim 3734, further comprising electrically coupling a lead-in conductor to the first conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

3758. The method of claim 3734, further comprising electrically coupling a lead-in conductor to the first conductor, wherein the lead-in conductor comprises copper.

3759. The method of claim 3734, further comprising maintaining a sufficient pressure between the first conduit and the formation to substantially inhibit deformation of the first conduit.

3760. The method of claim 3734, further comprising providing a thermally conductive fluid within the first conduit.

3761. The method of claim 3734, further comprising providing a thermally conductive fluid within the first conduit, wherein the thermally conductive fluid comprises helium.

3762. The method of claim 3734, further comprising inhibiting arcing between the first conductor and the first conduit with a fluid disposed within the first conduit.

3763. The method of claim 3734, further comprising removing a vapor from the opening using a perforated tube disposed proximate to the first conduit in the opening to control a pressure in the opening.

3764. The method of claim 3734, further comprising flowing a corrosion inhibiting fluid through a perforated tube disposed proximate to the first conduit in the opening.

3765. The method of claim 3734, wherein a second conductor is disposed within the first conduit, wherein the second conductor is electrically coupled to the first conductor to form an electrical circuit.

3766. The method of claim 3734, wherein a second conductor is disposed within the first conduit, wherein the second conductor is electrically coupled to the first conductor with a connector.

3767. The method of claim 3734, wherein a second conductor is disposed within a second conduit and a third conductor is disposed within a third conduit, wherein the second conduit and the third conduit are disposed in different openings of the formation, wherein the first conductor is electrically coupled to the second conductor and the third conductor, and wherein the first, second, and third conductors are configured to operate in a 3-phase Y configuration.

3768. The method of claim 3734, wherein a second conductor is disposed within the first conduit, wherein at least one sliding electrical connector is coupled to the first conductor and the second conductor, and wherein heat generated by at least the one sliding electrical connector is less than heat generated by the first conductor or the second conductor.

3769. The method of claim 3734, wherein the first conduit comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the first conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.

3770. The method of claim 3734, further comprising flowing an oxidizing fluid through an orifice in the first conduit.

3771. The method of claim 3734, further comprising disposing a perforated tube proximate to the first conduit and flowing an oxidizing fluid through the perforated tube.

3772. The method of claim 3734, further comprising heating at least the portion of the formation to substantially pyrolyze at least some of the hydrocarbons within the formation.

3773. A system configured to heat a hydrocarbon containing formation, comprising:

a first conductor disposed in a first conduit, wherein the first conduit is disposed within a first opening in the formation;

a second conductor disposed in a second conduit, wherein the second conduit is disposed within a second opening in the formation;

a third conductor disposed in a third conduit, wherein the third conduit is disposed within a third opening in the formation, wherein the first, second, and third conductors are electrically coupled in a 3-phase Y configuration, and wherein the first, second, and third conductors are configured to provide heat to at least a portion of the formation during use; and

wherein the system is configured to allow heat to transfer from the first, second, and third conductors to a selected section of the formation during use.

3774. The system of claim 3773, wherein the first, second, and third conductors are further configured to generate heat during application of an electrical current to the first conductor.

3775. The system of claim 3773, wherein the first, second, and third conductors comprise a pipe.

3776. The system of claim 3773, wherein the first, second, and third conductors comprise stainless steel.

3777. The system of claim 3773, wherein the first, second, and third openings comprise a diameter of at least approximately 5 cm.

3778. The system of claim 3773, further comprising a first sliding electrical connector coupled to the first conductor and a second sliding electrical connector coupled to the second conductor and a third sliding electrical connector coupled to the third conductor.

3779. The system of claim 3773, further comprising a first sliding electrical connector coupled to the first conductor, wherein the first sliding electrical connector is further coupled to the first conduit.

3780. The system of claim 3773, further comprising a second sliding electrical connector coupled to the second conductor, wherein the second sliding electrical connector is further coupled to the second conduit.

3781. The system of claim 3773, further comprising a third sliding electrical connector coupled to the third conductor, wherein the third sliding electrical connector is further coupled to the third conduit.

3782. The system of claim 3773, wherein each of the first, second, and third conduits comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from each of the first, second, and third conductors to the section along the first section of each of the conduits is less than heat radiated from the first, second, and third conductors to the section along the second section of each of the conduits.

3783. The system of claim 3773, further comprising a fluid disposed within the first, second, and third conduits, wherein the fluid is configured to maintain a pressure within the first conduit to substantially inhibit deformation of the first, second, and third conduits during use.

3784. The system of claim 3773, further comprising a thermally conductive fluid disposed within the first, second, and third conduits.

3785. The system of claim 3773, further comprising a thermally conductive fluid disposed within the first, second, and third conduits, wherein the thermally conductive fluid comprises helium.

3786. The system of claim 3773, further comprising a fluid disposed within the first, second, and third conduits, wherein the fluid is configured to substantially inhibit arcing between the first, second, and third conductors and the first, second, and third conduits during use.

3787. The system of claim 3773, further comprising at least one tube disposed within the first, second, and third openings external to the first, second, and third conduits, wherein at least the one tube is configured to remove vapor produced from at least the heated portion of the formation such that a pressure balance is maintained between the first, second, and third conduits and the first, second, and third openings to substantially inhibit deformation of the first, second, and third conduits during use.

3788. The system of claim 3773, wherein the first, second, and third conductors are further configured to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.

3789. The system of claim 3773, further comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the formation.

3790. The system of claim 3773, further comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the formation, and wherein at least the one overburden casing comprises steel.

3791. The system of claim 3773, further comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the formation, and wherein at least the one overburden casing is further disposed in cement.

3792. The system of claim 3773, further comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of at least the one overburden casing and the first, second, and third openings.

3793. The system of claim 3773, further comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of at least the one overburden casing and the first, second, and third openings, and wherein the packing material is further configured to substantially inhibit a flow of fluid between the first, second, and third openings and at least the one overburden casing during use.

3794. The system of claim 3773, wherein the heated section of the formation is substantially pyrolyzed.

3795. A system configurable to heat a hydrocarbon containing formation, comprising:

a first conductor configurable to be disposed in a first conduit, wherein the first conduit is configurable to be disposed within a first opening in the formation;

a second conductor configurable to be disposed in a second conduit, wherein the second conduit is configurable to be disposed within a second opening in the formation;

a third conductor configurable to be disposed in a third conduit, wherein the third conduit is configurable to be disposed within a third opening in the formation, wherein the first, second, and third conductors are further configurable to be electrically coupled in a 3-phase Y configuration, and wherein the first, second, and third conductors are further configurable to provide heat to at least a portion of the formation during use; and

wherein the system is configurable to allow heat to transfer from the first, second, and third conductors to a selected section of the formation during use.

3796. The system of claim 3795, wherein the first, second, and third conductors are further configurable to generate heat during application of an electrical current to the first conductor.

3797. The system of claim 3795, wherein the first, second, and third conductors comprise a pipe.

3798. The system of claim 3795, wherein the first, second, and third conductors comprise stainless steel.

3799. The system of claim 3795, wherein the first, second, and third openings comprise a diameter of at least approximately 5 cm.

3800. The system of claim 3795, further comprising a first sliding electrical connector coupled to the first conductor and a second sliding electrical connector coupled to the second conductor and a third sliding electrical connector coupled to the third conductor.

3801. The system of claim 3795, further comprising a first sliding electrical connector coupled to the first conductor, wherein the first sliding electrical connector is further coupled to the first conduit.

3802. The system of claim 3795, further comprising a second sliding electrical connector coupled to the second conductor, wherein the second sliding electrical connector is further coupled to the second conduit.

3803. The system of claim 3795, further comprising a third sliding electrical connector coupled to the third conductor, wherein the third sliding electrical connector is further coupled to the third conduit.

3804. The system of claim 3795, wherein each of the first, second, and third conduits comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from each of the first, second, and third conductors to the section along the first section of each of the conduits is less than heat radiated from the first, second, and third conductors to the section along the second section of each of the conduits.

3805. The system of claim 3795, further comprising a fluid disposed within the first, second, and third conduits, wherein the fluid is configurable to maintain a pressure within the first conduit to substantially inhibit deformation of the first, second, and third conduits during use.

3806. The system of claim 3795, further comprising a thermally conductive fluid disposed within the first, second, and third conduits.

3807. The system of claim 3795, further comprising a thermally conductive fluid disposed within the first, second, and third conduits, wherein the thermally conductive fluid comprises helium.

3808. The system of claim 3795, further comprising a fluid disposed within the first, second, and third conduits, wherein the fluid is configurable to substantially inhibit arcing between the first, second, and third conductors and the first, second, and third conduits during use.

3809. The system of claim 3795, further comprising at least one tube disposed within the first, second, and third openings external to the first, second, and third conduits, wherein at least the one tube is configurable to remove vapor produced from at least the heated portion of the formation such that a pressure balance is maintained between the first, second, and third conduits and the first, second, and third openings to substantially inhibit deformation of the first, second, and third conduits during use.

3810. The system of claim 3795, wherein the first, second, and third conductors are further configurable to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.

3811. The system of claim 3795, further comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the formation.

3812. The system of claim 3795, further comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the formation, and wherein at least the one overburden casing comprises steel.

3813. The system of claim 3795, further comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the formation, and wherein at least the one overburden casing is further disposed in cement.

3814. The system of claim 3795, further comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of at least the one overburden casing and the first, second, and third openings.

3815. The system of claim 3795, further comprising at least one overburden casing coupled to the first, second, and third openings, wherein at least the one overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of at least the one overburden casing and the first, second, and third openings, and wherein the packing material is further configurable to substantially inhibit a flow of fluid between the first, second, and third openings and at least the one overburden casing during use.

3816. The system of claim 3795, wherein the heated section of the formation is substantially pyrolyzed.

3817. The system of claim 3795, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

a first conductor disposed in a first conduit, wherein the first conduit is disposed within a first opening in the formation;

a second conductor disposed in a second conduit, wherein the second conduit is disposed within a second opening in the formation;

a third conductor disposed in a third conduit, wherein the third conduit is disposed within a third opening in the formation, wherein the first, second, and third conductors are electrically coupled in a 3-phase Y configuration, and wherein the first, second, and third conductors are configured to provide heat to at least a portion of the formation during use; and

wherein the system is configured to allow heat to transfer from the first, second, and third conductors to a selected section of the formation during use.

3818. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to a first conductor to provide heat to at least a portion of the formation, wherein the first conductor is disposed in a first conduit, and wherein the first conduit is disposed within a first opening in the formation;

applying an electrical current to a second conductor to provide heat to at least a portion of the formation, wherein the second conductor is disposed in a second conduit, and wherein the second conduit is disposed within a second opening in the formation;

applying an electrical current to a third conductor to provide heat to at least a portion of the formation, wherein the third conductor is disposed in a third conduit, and wherein the third conduit is disposed within a third opening in the formation; and

allowing the heat to transfer from the first, second, and third conductors to a selected section of the formation.

3819. The method of claim 3818, wherein the first, second, and third conductors comprise a pipe.

3820. The method of claim 3818, wherein the first, second, and third conductors comprise stainless steel.

3821. The method of claim 3818, wherein the first, second, and third conduits comprise stainless steel.

3822. The method of claim 3818, wherein the provided heat comprises approximately 650 W/m to approximately 1650 W/m.

3823. The method of claim 3818, further comprising determining a temperature distribution in the first, second, and third conduits using an electromagnetic signal provided to the first, second, and third conduits.

3824. The method of claim 3818, further comprising monitoring the applied electrical current.

3825. The method of claim 3818, further comprising monitoring a voltage applied to the first, second, and third conductors.

3826. The method of claim 3818, further comprising monitoring a temperature in the first, second, and third conduits with at least one thermocouple.

3827. The method of claim 3818, further comprising maintaining a sufficient pressure between the first, second, and third conduits and the first, second, and third openings to substantially inhibit deformation of the first, second, and third conduits.

3828. The method of claim 3818, further comprising providing a thermally conductive fluid within the first, second, and third conduits.

3829. The method of claim 3818, further comprising providing a thermally conductive fluid within the first, second, and third conduits, wherein the thermally conductive fluid comprises helium.

3830. The method of claim 3818, further comprising inhibiting arcing between the first, second, and third conductors and the first, second, and third conduits with a fluid disposed within the first, second, and third conduits.

3831. The method of claim 3818, further comprising removing a vapor from the first, second, and third openings using at least one perforated tube disposed proximate to the first, second, and third conduits in the first, second, and third openings to control a pressure in the first, second, and third openings.

3832. The method of claim 3818, wherein the first, second, and third conduits comprise a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the first, second, and third conductors to the section along the first section of the first, second, and third conduits is less than heat radiated from the first, second, and third conductors to the section along the second section of the first, second, and third conduits.

3833. The method of claim 3818, further comprising flowing an oxidizing fluid through an orifice in the first, second, and third conduits.

3834. The method of claim 3818, further comprising heating at least the portion of the formation to substantially pyrolyze at least some of the hydrocarbons within the formation.

3835. A system configured to heat a hydrocarbon containing formation, comprising:

a first conductor disposed in a conduit, wherein the conduit is disposed within an opening in the formation; and

a second conductor disposed in the conduit, wherein the second conductor is electrically coupled to the first conductor with a connector, and wherein the first and second conductors are configured to provide heat to at least a portion of the formation during use; and

wherein the system is configured to allow heat to transfer from the first and second conductors to a selected section of the formation during use.

3836. The system of claim 3835, wherein the first conductor is further configured to generate heat during application of an electrical current to the first conductor.

3837. The system of claim 3835, wherein the first and second conductors comprise a pipe.

3838. The system of claim 3835, wherein the first and second conductors comprise stainless steel.

3839. The system of claim 3835, wherein the conduit comprises stainless steel.

3840. The system of claim 3835, further comprising a centralizer configured to maintain a location of the first and second conductors within the conduit.

3841. The system of claim 3835, further comprising a centralizer configured to maintain a location of the first and second conductors within the conduit, wherein the centralizer comprises ceramic material.

3842. The system of claim 3835, further comprising a centralizer configured to maintain a location of the first and second conductors within the conduit, wherein the centralizer comprises ceramic material and stainless steel.

3843. The system of claim 3835, wherein the opening comprises a diameter of at least approximately 5 cm.

3844. The system of claim 3835, further comprising a lead-in conductor coupled to the first and second conductors, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

3845. The system of claim 3835, further comprising a lead-in conductor coupled to the first and second conductors, wherein the lead-in conductor comprises copper.

3846. The system of claim 3835, wherein the conduit comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the first conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.

3847. The system of claim 3835, further comprising a fluid disposed within the conduit, wherein the fluid is configured to maintain a pressure within the conduit to substantially inhibit deformation of the conduit during use.

3848. The system of claim 3835, further comprising a thermally conductive fluid disposed within the conduit.

3849. The system of claim 3835, further comprising a thermally conductive fluid disposed within the conduit, wherein the thermally conductive fluid comprises helium.

3850. The system of claim 3835, further comprising a fluid disposed within the conduit, wherein the fluid is configured to substantially inhibit arcing between the first and second conductors and the conduit during use.

3851. The system of claim 3835, further comprising a tube disposed within the opening external to the conduit, wherein the tube is configured to remove vapor produced from at least the heated portion of the formation such that a pressure balance is maintained between the conduit and the opening to substantially inhibit deformation of the conduit during use.

3852. The system of claim 3835, wherein the first and second conductors are further configured to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.

3853. The system of claim 3835, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3854. The system of claim 3835, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3855. The system of claim 3835, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3856. The system of claim 3835, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3857. The system of claim 3835, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3858. The system of claim 3835, wherein the heated section of the formation is substantially pyrolyzed.

3859. A system configurable to heat a hydrocarbon containing formation, comprising:

a first conductor configurable to be disposed in a conduit, wherein the conduit is configurable to be disposed within an opening in the formation;

a second conductor configurable to be disposed in the conduit, wherein the second conductor is configurable to be electrically coupled to the first conductor with a connector, and wherein the first and second conductors are further configurable to provide heat to at least a portion of the formation during use; and

wherein the system is configurable to allow heat to transfer from the first and second conductors to a selected section of the formation during use.

3860. The system of claim 3859, wherein the first conductor is further configurable to generate heat during application of an electrical current to the first conductor.

3861. The system of claim 3859, wherein the first and second conductors comprise a pipe.

3862. The system of claim 3859, wherein the first and second conductors comprise stainless steel.

3863. The system of claim 3859, wherein the conduit comprises stainless steel.

3864. The system of claim 3859, further comprising a centralizer configurable to maintain a location of the first and second conductors within the conduit.

3865. The system of claim 3859, further comprising a centralizer configurable to maintain a location of the first and second conductors within the conduit, wherein the centralizer comprises ceramic material.

3866. The system of claim 3859, further comprising a centralizer configurable to maintain a location of the first and second conductors within the conduit, wherein the centralizer comprises ceramic material and stainless steel.

3867. The system of claim 3859, wherein the opening comprises a diameter of at least approximately 5 cm.

3868. The system of claim 3859, further comprising a lead-in conductor coupled to the first and second conductors, wherein the lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.

3869. The system of claim 3859, further comprising a lead-in conductor coupled to the first and second conductors, wherein the lead-in conductor comprises copper.

3870. The system of claim 3859, wherein the conduit comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the first conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.

3871. The system of claim 3859, further comprising a fluid disposed within the conduit, wherein the fluid is configurable to maintain a pressure within the conduit to substantially inhibit deformation of the conduit during use.

3872. The system of claim 3859, further comprising a thermally conductive fluid disposed within the conduit.

3873. The system of claim 3859, further comprising a thermally conductive fluid disposed within the conduit, wherein the thermally conductive fluid comprises helium.

3874. The system of claim 3859, further comprising a fluid disposed within the conduit, wherein the fluid is configurable to substantially inhibit arcing between the first and second conductors and the conduit during use.

3875. The system of claim 3859, further comprising a tube disposed within the opening external to the conduit, wherein the tube is configurable to remove vapor produced from at least the heated portion of the formation such that a pressure balance is maintained between the conduit and the opening to substantially inhibit deformation of the conduit during use.

3876. The system of claim 3859, wherein the first and second conductors are further configurable to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.

3877. The system of claim 3859, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3878. The system of claim 3859, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3879. The system of claim 3859, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3880. The system of claim 3859, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3881. The system of claim 3859, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3882. The system of claim 3859, wherein the heated section of the formation is substantially pyrolyzed.

3883. The system of claim 3859, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

a first conductor disposed in a conduit, wherein the conduit is disposed within an opening in the formation;

a second conductor disposed in the conduit, wherein the second conductor is electrically coupled to the first conductor with a connector, and wherein the first and second conductors are configured to provide heat to at least a portion of the formation during use; and

wherein the system is configured to allow heat to transfer from the first and second conductors to a selected section of the formation during use.

3884. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to at least two conductors to provide heat to at least a portion of the formation, wherein at least the two conductors are disposed within a conduit, wherein the conduit is disposed within an opening in the formation, and wherein at least the two conductors are electrically coupled with a connector; and

allowing heat to transfer from at least the two conductors to a selected section of the formation.

3885. The method of claim 3884, wherein at least the two conductors comprise a pipe.

3886. The method of claim 3884, wherein at least the two conductors comprise stainless steel.

3887. The method of claim 3884, wherein the conduit comprises stainless steel.

3888. The method of claim 3884, further comprising maintaining a location of at least the two conductors in the conduit with a centralizer.

3889. The method of claim 3884, further comprising maintaining a location of at least the two conductors in the conduit with a centralizer, wherein the centralizer comprises ceramic material.

3890. The method of claim 3884, further comprising maintaining a location of at least the two conductors in the conduit with a centralizer, wherein the centralizer comprises ceramic material and stainless steel.

3891. The method of claim 3884, wherein the provided heat comprises approximately 650 W/m to approximately 1650 W/m.

3892. The method of claim 3884, further comprising determining a temperature distribution in the conduit using an electromagnetic signal provided to the conduit.

3893. The method of claim 3884, further comprising monitoring the applied electrical current.

3894. The method of claim 3884, further comprising monitoring a voltage applied to at least the two conductors.

3895. The method of claim 3884, further comprising monitoring a temperature in the conduit with at least one thermocouple.

3896. The method of claim 3884, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3897. The method of claim 3884, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3898. The method of claim 3884, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3899. The method of claim 3884, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3900. The method of claim 3884, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with a packing material.

3901. The method of claim 3884, further comprising maintaining a sufficient pressure between the conduit and the formation to substantially inhibit deformation of the conduit.

3902. The method of claim 3884, further comprising providing a thermally conductive fluid within the conduit.

3903. The method of claim 3884, further comprising providing a thermally conductive fluid within the conduit, wherein the thermally conductive fluid comprises helium.

3904. The method of claim 3884, further comprising inhibiting arcing between at least the two conductors and the conduit with a fluid disposed within the conduit.

3905. The method of claim 3884, further comprising removing a vapor from the opening using a perforated tube disposed proximate to the conduit in the opening to control a pressure in the opening.

3906. The method of claim 3884, further comprising flowing a corrosion inhibiting fluid through a perforated tube disposed proximate to the conduit in the opening.

3907. The method of claim 3884, wherein the conduit comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the first conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.

3908. The method of claim 3884, further comprising flowing an oxidizing fluid through an orifice in the conduit.

3909. The method of claim 3884, further comprising disposing a perforated tube proximate to the conduit and flowing an oxidizing fluid through the perforated tube.

3910. The method of claim 3884, further comprising heating at least the portion of the formation to substantially pyrolyze at least some of the hydrocarbons within the formation.

3911. A system configured to heat a hydrocarbon containing formation, comprising:

at least one conductor disposed in a conduit, wherein the conduit is disposed within an opening in the formation, and wherein at least the one conductor is configured to provide heat to at least a first portion of the formation during use;

at least one sliding connector, wherein at least the one sliding connector is coupled to at least the one conductor, wherein at least the one sliding connector is configured to provide heat during use, and wherein heat provided by at least the one sliding connector is substantially less than the heat provided by at least the one conductor during use; and

wherein the system is configured to allow heat to transfer from at least the one conductor to a section of the formation during use.

3912. The system of claim 3911, wherein at least the one conductor is further configured to generate heat during application of an electrical current to at least the one conductor.

3913. The system of claim 3911, wherein at least the one conductor comprises a pipe.

3914. The system of claim 3911, wherein at least the one conductor comprises stainless steel.

3915. The system of claim 3911, wherein the conduit comprises stainless steel.

3916. The system of claim 3911, further comprising a centralizer configured to maintain a location of at least the one conductor within the conduit.

3917. The system of claim 3911, further comprising a centralizer configured to maintain a location of at least the one conductor within the conduit, wherein the centralizer comprises ceramic material.

3918. The system of claim 3911, further comprising a centralizer configured to maintain a location of at least the one conductor within the conduit, wherein the centralizer comprises ceramic material and stainless steel.

3919. The system of claim 3911, wherein the opening comprises a diameter of at least approximately 5 cm.

3920. The system of claim 3911, further comprising a lead-in conductor coupled to at least the one conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

3921. The system of claim 3911, further comprising a lead-in conductor coupled to at least the one conductor, wherein the lead-in conductor comprises copper.

3922. The system of claim 3911, wherein the conduit comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the first conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.

3923. The system of claim 3911, further comprising a fluid disposed within the conduit, wherein the fluid is configured to maintain a pressure within the conduit to substantially inhibit deformation of the conduit during use.

3924. The system of claim 3911, further comprising a thermally conductive fluid disposed within the conduit.

3925. The system of claim 3911, further comprising a thermally conductive fluid disposed within the conduit, wherein the thermally conductive fluid comprises helium.

3926. The system of claim 3911, further comprising a fluid disposed within the conduit, wherein the fluid is configured to substantially inhibit arcing between at least the one conductor and the conduit during use.

3927. The system of claim 3911, further comprising a tube disposed within the opening external to the conduit, wherein the tube is configured to remove vapor produced from at least the heated portion of the formation such that a pressure balance is maintained between the conduit and the opening to substantially inhibit deformation of the conduit during use.

3928. The system of claim 3911, wherein at least the one conductor is further configured to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.

3929. The system of claim 3911, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3930. The system of claim 3911, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3931. The system of claim 3911, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3932. The system of claim 3911, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3933. The system of claim 3911, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3934. The system of claim 3911, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to at least the one conductor.

3935. The system of claim 3911, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to at least the one conductor, and wherein the substantially low resistance conductor comprises carbon steel.

3936. The system of claim 3911, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing and a centralizer configured to support the substantially low resistance conductor within the overburden casing.

3937. The system of claim 3911, wherein the heated section of the formation is substantially pyrolyzed.

3938. A system configurable to heat a hydrocarbon containing formation, comprising:

at least one conductor configurable to be disposed in a conduit, wherein the conduit is configurable to be disposed within an opening in the formation, and wherein at least the one conductor is further configurable to provide heat to at least a first portion of the formation during use;

at least one sliding connector, wherein at least the one sliding connector is configurable to be coupled to at least the one conductor, wherein at least the one sliding connector is further configurable to provide heat during use, and wherein heat provided by at least the one sliding connector is substantially less than the heat provided by at least the one conductor during use; and

wherein the system is configurable to allow heat to transfer from at least the one conductor to a section of the formation during use.

3939. The system of claim 3938, wherein at least the one conductor is further configurable to generate heat during application of an electrical current to at least the one conductor.

3940. The system of claim 3938, wherein at least the one conductor comprises a pipe.

3941. The system of claim 3938, wherein at least the one conductor comprises stainless steel.

3942. The system of claim 3938, wherein the conduit comprises stainless steel.

3943. The system of claim 3938, further comprising a centralizer configurable to maintain a location of at least the one conductor within the conduit.

3944. The system of claim 3938, further comprising a centralizer configurable to maintain a location of at least the one conductor within the conduit, wherein the centralizer comprises ceramic material.

3945. The system of claim 3938, further comprising a centralizer configurable to maintain a location of at least the one conductor within the conduit, wherein the centralizer comprises ceramic material and stainless steel.

3946. The system of claim 3938, wherein the opening comprises a diameter of at least approximately 5 cm.

3947. The system of claim 3938, further comprising a lead-in conductor coupled to at least the one conductor, wherein the lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.

3948. The system of claim 3938, further comprising a lead-in conductor coupled to at least the one conductor, wherein the lead-in conductor comprises copper.

3949. The system of claim 3938, wherein the conduit comprises a first section and a second section, wherein a thickness of the first section is greater than a thickness of the second section such that heat radiated from the first conductor to the section along the first section of the conduit is less than heat radiated from the first conductor to the section along the second section of the conduit.

3950. The system of claim 3938, further comprising a fluid disposed within the conduit, wherein the fluid is configurable to maintain a pressure within the conduit to substantially inhibit deformation of the conduit during use.

3951. The system of claim 3938, further comprising a thermally conductive fluid disposed within the conduit.

3952. The system of claim 3938, further comprising a thermally conductive fluid disposed within the conduit, wherein the thermally conductive fluid comprises helium.

3953. The system of claim 3938, further comprising a fluid disposed within the conduit, wherein the fluid is configurable to substantially inhibit arcing between at least the one conductor and the conduit during use.

3954. The system of claim 3938, further comprising a tube disposed within the opening external to the conduit, wherein the tube is configurable to remove vapor produced from at least the heated portion of the formation such that a pressure balance is maintained between the conduit and the opening to substantially inhibit deformation of the conduit during use.

3955. The system of claim 3938, wherein at least the one conductor is further configurable to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.

3956. The system of claim 3938, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3957. The system of claim 3938, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3958. The system of claim 3938, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3959. The system of claim 3938, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3960. The system of claim 3938, further comprising an overburden easing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

3961. The system of claim 3938, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to at least the one conductor.

3962. The system of claim 3938, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to at least the one conductor, and wherein the substantially low resistance conductor comprises carbon steel.

3963. The system of claim 3938, further comprising an overburden casing coupled to the opening and a substantially low resistance conductor disposed within the overburden casing and a centralizer configurable to support the substantially low resistance conductor within the overburden casing.

3964. The system of claim 3938, wherein the heated section of the formation is substantially pyrolyzed.

3965. The system of claim 3938, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

at least one conductor disposed in a conduit, wherein the conduit is disposed within an opening in the formation, and wherein at least the one conductor is configured to provide heat to at least a first portion of the formation during use;

at least one sliding connector, wherein at least the one sliding connector is coupled to at least the one conductor, wherein at least the one sliding connector is configured to provide heat during use, and wherein heat provided by at least the one sliding connector is substantially less than the heat provided by at least the one conductor during use; and

wherein the system is configured to allow heat to transfer from at least the one conductor to a section of the formation during use.

3966. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to at least one conductor and at least one sliding connector to provide heat to at least a portion of the formation, wherein at least the one conductor and at least the one sliding connector are disposed within a conduit, and wherein heat provided by at least the one conductor is substantially greater than heat provided by at least the one sliding connector; and

allowing the heat to transfer from at least the one conductor and at least the one sliding connector to a section of the formation.

3967. The method of claim 3966, wherein at least the one conductor comprises a pipe.

3968. The method of claim 3966, wherein at least the one conductor comprises stainless steel.

3969. The method of claim 3966, wherein the conduit comprises stainless steel.

3970. The method of claim 3966, further comprising maintaining a location of at least the one conductor in the conduit with a centralizer.

3971. The method of claim 3966, further comprising maintaining a location of at least the one conductor in the conduit with a centralizer, wherein the centralizer comprises ceramic material.

3972. The method of claim 3966, further comprising maintaining a location of at least the one conductor in the conduit with a centralizer, wherein the centralizer comprises ceramic material and stainless steel.

3973. The method of claim 3966, wherein the provided heat comprises approximately 650 W/m to approximately 1650 W/m.

3974. The method of claim 3966, further comprising determining a temperature distribution in the conduit using an electromagnetic signal provided to the conduit.

3975. The method of claim 3966, further comprising monitoring the applied electrical current.

3976. The method of claim 3966, further comprising monitoring a voltage applied to at least the one conductor.

3977. The method of claim 3966, further comprising monitoring a temperature in the conduit with at least one thermocouple.

3978. The method of claim 3966, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

3979. The method of claim 3966, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

3980. The method of claim 3966, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

3981. The method of claim 3966, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

3982. The method of claim 3966, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with a packing material.

3983. The method of claim 3966, further comprising coupling an overburden casing to the opening, wherein a substantially low resistance conductor is disposed within the overburden casing, and wherein the substantially low resistance conductor is electrically coupled to at least the one conductor.

3984. The method of claim 3966, further comprising coupling an overburden casing to the opening, wherein a substantially low resistance conductor is disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to at least the one conductor, and wherein the substantially low resistance conductor comprises carbon steel.

3985. The method of claim 3966, further comprising coupling an overburden casing to the opening, wherein a substantially low resistance conductor is disposed within the overburden casing, wherein the substantially low resistance conductor is electrically coupled to at least the one conductor, and wherein the method further comprises maintaining a location of the substantially low resistance conductor in the overburden casing with a centralizer support.

3986. The method of claim 3966, further comprising electrically coupling a lead-in conductor to at least the one conductor, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

3987. The method of claim 3966, further comprising electrically coupling a lead-in conductor to at least the one conductor, wherein the lead-in conductor comprises copper.

3988. The method of claim 3966, further comprising maintaining a sufficient pressure between the conduit and the formation to substantially inhibit deformation of the conduit.

3989. The method of claim 3966, further comprising providing a thermally conductive fluid within the conduit.

3990. The method of claim 3966, further comprising providing a thermally conductive fluid within the conduit, wherein the thermally conductive fluid comprises helium.

3991. The method of claim 3966, further comprising inhibiting arcing between the conductor and the conduit with a fluid disposed within the conduit.

3992. The method of claim 3966, further comprising removing a vapor from the opening using a perforated tube disposed proximate to the conduit in the opening to control a pressure in the opening.

3993. The method of claim 3966, further comprising flowing a corrosion inhibiting fluid through a perforated tube disposed proximate to the conduit in the opening.

3994. The method of claim 3966, further comprising flowing an oxidizing fluid through an orifice in the conduit.

3995. The method of claim 3966, further comprising disposing a perforated tube proximate to the conduit and flowing an oxidizing fluid through the perforated tube.

3996. The method of claim 3966, further comprising heating at least the portion of the formation to substantially pyrolyze at least some of the hydrocarbons within the formation.

3997. A system configured to heat a hydrocarbon containing formation, comprising:

at least one elongated member disposed within an opening in the formation, wherein at least the one elongated member is configured to provide heat to at least a portion of the formation during use; and

wherein the system is configured to allow heat to transfer from at least the one elongated member to a section of the formation during use.

3998. The system of claim 3997, wherein at least the one elongated member comprises stainless steel.

3999. The system of claim 3997, wherein at least the one elongated member is further configured to generate heat during application of an electrical current to at least the one elongated member.

4000. The system of claim 3997, further comprising a support member coupled to at least the one elongated member, wherein the support member is configured to support at least the one elongated member.

4001. The system of claim 3997, further comprising a support member coupled to at least the one elongated member, wherein the support member is configured to support at least the one elongated member, and wherein the support member comprises openings.

4002. The system of claim 3997, further comprising a support member coupled to at least the one elongated member, wherein the support member is configured to support at least the one elongated member, wherein the support member comprises openings, wherein the openings are configured to flow a fluid along a length of at least the one elongated member during use, and wherein the fluid is configured to substantially inhibit carbon deposition on or proximate to at least the one elongated member during use.

4003. The system of claim 3997, further comprising a tube disposed in the opening, wherein the tube comprises openings, wherein the openings are configured to flow a fluid along a length of at least the one elongated member during use, and wherein the fluid is configured to substantially inhibit carbon deposition on or proximate to at least the one elongated member during use.

4004. The system of claim 3997, further comprising a centralizer coupled to at least the one elongated member, wherein the centralizer is configured to electrically isolate at least the one elongated member.

4005. The system of claim 3997, further comprising a centralizer coupled to at least the one elongated member and a support member coupled to at least the one elongated member, wherein the centralizer is configured to maintain a location of at least the one elongated member on the support member.

4006. The system of claim 3997, wherein the opening comprises a diameter of at least approximately 5 cm.

4007. The system of claim 3997, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

4008. The system of claim 3997, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises a rubber insulated conductor.

4009. The system of claim 3997, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises copper wire.

4010. The system of claim 3997, further comprising a lead-in conductor coupled to at least the one elongated member with a cold pin transition conductor.

4011. The system of claim 3997, further comprising a lead-in conductor coupled to at least the one elongated member with a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

4012. The system of claim 3997, wherein at least the one elongated member is arranged in a series electrical configuration.

4013. The system of claim 3997, wherein at least the one elongated member is arranged in a parallel electrical configuration.

4014. The system of claim 3997, wherein at least the one elongated member is configured to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.

4015. The system of claim 3997, further comprising a perforated tube disposed in the opening external to at least the one elongated member, wherein the perforated tube is configured to remove vapor from the opening to control a pressure in the opening during use.

4016. The system of claim 3997, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

4017. The system of claim 3997, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

4018. The system of claim 3997, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

4019. The system of claim 3997, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

4020. The system of claim 3997, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

4021. The system of claim 3997, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

4022. The system of claim 3997, wherein the heated section of the formation is substantially pyrolyzed.

4023. A system configurable to heat a hydrocarbon containing formation, comprising:

at least one elongated member configurable to be disposed within an opening in the formation, wherein at least the one elongated member is further configurable to provide heat to at least a portion of the formation during use; and

wherein the system is configurable to allow heat to transfer from at least the one elongated member to a section of the formation during use.

4024. The system of claim 4023, wherein at least the one elongated member comprises stainless steel.

4025. The system of claim 4023, wherein at least the one elongated member is further configurable to generate heat during application of an electrical current to at least the one elongated member.

4026. The system of claim 4023, further comprising a support member coupled to at least the one elongated member, wherein the support member is configurable to support at least the one elongated member.

4027. The system of claim 4023, further comprising a support member coupled to at least the one elongated member, wherein the support member is configurable to support at least the one elongated member, and wherein the support member comprises openings.

4028. The system of claim 4023, further comprising a support member coupled to at least the one elongated member, wherein the support member is configurable to support at least the one elongated member, wherein the support member comprises openings, wherein the openings are configurable to flow a fluid along a length of at least the one elongated member during use, and wherein the fluid is configurable to substantially inhibit carbon deposition on or proximate to at least the one elongated member during use.

4029. The system of claim 4023, further comprising a tube disposed in the opening, wherein the tube comprises openings, wherein the openings are configurable to flow a fluid along a length of at least the one elongated member during use, and wherein the fluid is configurable to substantially inhibit carbon deposition on or proximate to at least the one elongated member during use.

4030. The system of claim 4023, further comprising a centralizer coupled to at least the one elongated member, wherein the centralizer is configurable to electrically isolate at least the one elongated member.

4031. The system of claim 4023, further comprising a centralizer coupled to at least the one elongated member and a support member coupled to at least the one elongated member, wherein the centralizer is configurable to maintain a location of at least the one elongated member on the support member.

4032. The system of claim 4023, wherein the opening comprises a diameter of at least approximately 5 cm.

4033. The system of claim 4023, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.

4034. The system of claim 4023, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises a rubber insulated conductor.

4035. The system of claim 4023, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises copper wire.

4036. The system of claim 4023, further comprising a lead-in conductor coupled to at least the one elongated member with a cold pin transition conductor.

4037. The system of claim 4023, further comprising a lead-in conductor coupled to at least the one elongated member with a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

4038. The system of claim 4023, wherein at least the one elongated member is arranged in a series electrical configuration.

4039. The system of claim 4023, wherein at least the one elongated member is arranged in a parallel electrical configuration.

4040. The system of claim 4023, wherein at least the one elongated member is configurable to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.

4041. The system of claim 4023, further comprising a perforated tube disposed in the opening external to at least the one elongated member, wherein the perforated tube is configurable to remove vapor from the opening to control a pressure in the opening during use.

4042. The system of claim 4023, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

4043. The system of claim 4023, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

4044. The system of claim 4023, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

4045. The system of claim 4023, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

4046. The system of claim 4023, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

4047. The system of claim 4023, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

4048. The system of claim 4023, wherein the heated section of the formation is substantially pyrolyzed.

4049. The system of claim 4023, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

at least one elongated member disposed within an opening in the formation, wherein at least the one elongated member is configured to provide heat to at least a portion of the formation during use; and

wherein the system is configured to allow heat to transfer from at least the one elongated member to a section of the formation during use.

4050. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to at least one elongated member to provide heat to at least a portion of the formation, wherein at least the one elongated member is disposed within an opening of the formation; and

allowing heat to transfer from at least the one elongated member to a section of the formation.

4051. The method of claim 4050, wherein at least the one elongated member comprises a metal strip.

4052. The method of claim 4050, wherein at least the one elongated member comprises a metal rod.

4053. The method of claim 4050, wherein at least the one elongated member comprises stainless steel.

4054. The method of claim 4050, further comprising supporting at least the one elongated member on a center support member.

4055. The method of claim 4050, further comprising supporting at least the one elongated member on a center support member, wherein the center support member comprises a tube.

4056. The method of claim 4050, further comprising electrically isolating at least the one elongated member with a centralizer.

4057. The method of claim 4050, further comprising laterally spacing at least the one elongated member with a centralizer.

4058. The method of claim 4050, further comprising electrically coupling at least the one elongated member in a series configuration.

4059. The method of claim 4050, further comprising electrically coupling at least the one elongated member in a parallel configuration.

4060. The method of claim 4050, wherein the provided heat comprises approximately 650 W/m to approximately 1650 W/m.

4061. The method of claim 4050, further comprising determining a temperature distribution in at least the one elongated member using an electromagnetic signal provided to at least the one elongated member.

4062. The method of claim 4050, further comprising monitoring the applied electrical current.

4063. The method of claim 4050, further comprising monitoring a voltage applied to at least the one elongated member.

4064. The method of claim 4050, further comprising monitoring a temperature in at least the one elongated member with at least one thermocouple.

4065. The method of claim 4050, further comprising supporting at least the one elongated member on a center support member, wherein the center support member comprises openings, the method further comprising flowing an oxidizing fluid through the openings to substantially inhibit carbon deposition proximate to or on at least the one elongated member.

4066. The method of claim 4050, further comprising flowing an oxidizing fluid through a tube disposed proximate to at least the one elongated member to substantially inhibit carbon deposition proximate to or on at least the one elongated member.

4067. The method of claim 4050, further comprising flowing an oxidizing fluid through an opening in at least the one elongated member to substantially inhibit carbon deposition proximate to or on at least the one elongated member.

4068. The method of claim 4050, further comprising electrically coupling a lead-in conductor to at least the one elongated member, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

4069. The method of claim 4050, further comprising electrically coupling a lead-in conductor to at least the one elongated member using a cold pin transition conductor.

4070. The method of claim 4050, further comprising electrically coupling a lead-in conductor to at least the one elongated member using a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

4071. The method of claim 4050, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

4072. The method of claim 4050, further comprising coupling an overburden casing to the opening, wherein the overburden casing comprises steel.

4073. The method of claim 4050, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in cement.

4074. The method of claim 4050, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

4075. The method of claim 4050, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with the packing material.

4076. The method of claim 4050, further comprising heating at least the portion of the formation to substantially pyrolyze at least some of the hydrocarbons within the formation.

4077. A system configured to heat a hydrocarbon containing formation, comprising:

at least one elongated member disposed within an opening in the formation, wherein at least the one elongated member is configured to provide heat to at least a portion of the formation during use;

an oxidizing fluid source;

a conduit disposed within the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to the opening during use, and wherein the oxidizing fluid is selected to substantially inhibit carbon deposition on or proximate to at least the one elongated member during use; and

wherein the system is configured to allow heat to transfer from at least the one elongated member to a section of the formation during use.

4078. The system of claim 4077, wherein at least the one elongated member comprises stainless steel.

4079. The system of claim 4077, wherein at least the one elongated member is further configured to generate heat during application of an electrical current to at least the one elongated member.

4080. The system of claim 4077, wherein at least the one elongated member is coupled to the conduit, wherein the conduit is further configured to support at least the one elongated member.

4081. The system of claim 4077, wherein at least the one elongated member is coupled to the conduit, wherein the conduit is further configured to support at least the one elongated member, and wherein the conduit comprises openings.

4082. The system of claim 4077, further comprising a centralizer coupled to at least the one elongated member and the conduit, wherein the centralizer is configured to electrically isolate at least the one elongated member from the conduit.

4083. The system of claim 4077, further comprising a centralizer coupled to at least the one elongated member and the conduit, wherein the centralizer is configured to maintain a location of at least the one elongated member on the conduit.

4084. The system of claim 4077, wherein the opening comprises a diameter of at least approximately 5 cm.

4085. The system of claim 4077, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

4086. The system of claim 4077, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises a rubber insulated conductor.

4087. The system of claim 4077, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises copper wire.

4088. The system of claim 4077, further comprising a lead-in conductor coupled to at least the one elongated member with a cold pin transition conductor.

4089. The system of claim 4077, further comprising a lead-in conductor coupled to at least the one elongated member with a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

4090. The system of claim 4077, wherein at least the one elongated member is arranged in a series electrical configuration.

4091. The system of claim 4077, wherein at least the one elongated member is arranged in a parallel electrical configuration.

4092. The system of claim 4077, wherein at least the one elongated member is configured to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.

4093. The system of claim 4077, further comprising a perforated tube disposed in the opening external to at least the one elongated member, wherein the perforated tube is configured to remove vapor from the opening to control a pressure in the opening during use.

4094. The system of claim 4077, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

4095. The system of claim 4077, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

4096. The system of claim 4077, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

4097. The system of claim 4077, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

4098. The system of claim 4077, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

4099. The system of claim 4077, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configured to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

4100. The system of claim 4077, wherein the heated section of the formation is substantially pyrolyzed.

4101. A system configurable to heat a hydrocarbon containing formation, comprising:

at least one elongated member configurable to be disposed within an opening in the formation, wherein at least the one elongated member is further configurable to provide heat to at least a portion of the formation during use;

a conduit configurable to be disposed within the opening, wherein the conduit is further configurable to provide an oxidizing fluid from the oxidizing fluid source to the opening during use, and wherein the system is configurable to allow the oxidizing fluid to substantially inhibit carbon deposition on or proximate to at least the one elongated member during use; and

wherein the system is further configurable to allow heat to transfer from at least the one elongated member to a section of the formation during use.

4102. The system of claim 4101, wherein at least the one elongated member comprises stainless steel.

4103. The system of claim 4101, wherein at least the one elongated member is further configurable to generate heat during application of an electrical current to at least the one elongated member.

4104. The system of claim 4101, wherein at least the one elongated member is coupled to the conduit, wherein the conduit is further configurable to support at least the one elongated member.

4105. The system of claim 4101, wherein at least the one elongated member is coupled to the conduit, wherein the conduit is further configurable to support at least the one elongated member, and wherein the conduit comprises openings.

4106. The system of claim 4101, further comprising a centralizer coupled to at least the one elongated member and the conduit, wherein the centralizer is configurable to electrically isolate at least the one elongated member from the conduit.

4107. The system of claim 4101, further comprising a centralizer coupled to at least the one elongated member and the conduit, wherein the centralizer is configurable to maintain a location of at least the one elongated member on the conduit.

4108. The system of claim 4101, wherein the opening comprises a diameter of at least approximately 5 cm.

4109. The system of claim 4101, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises a low resistance conductor configurable to generate substantially no heat.

4110. The system of claim 4101, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises a rubber insulated conductor.

4111. The system of claim 4101, further comprising a lead-in conductor coupled to at least the one elongated member, wherein the lead-in conductor comprises copper wire.

4112. The system of claim 4101, further comprising a lead-in conductor coupled to at least the one elongated member with a cold pin transition conductor.

4113. The system of claim 4101, further comprising a lead-in conductor coupled to at least the one elongated member with a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

4114. The system of claim 4101, wherein at least the one elongated member is arranged in a series electrical configuration.

4115. The system of claim 4101, wherein at least the one elongated member is arranged in a parallel electrical configuration.

4116. The system of claim 4101, wherein at least the one elongated member is configurable to generate radiant heat of approximately 650 W/m to approximately 1650 W/m during use.

4117. The system of claim 4101, further comprising a perforated tube disposed in the opening external to at least the one elongated member, wherein the perforated tube is configurable to remove vapor from the opening to control a pressure in the opening during use.

4118. The system of claim 4101, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation.

4119. The system of claim 4101, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

4120. The system of claim 4101, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

4121. The system of claim 4101, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the opening.

4122. The system of claim 4101, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material comprises cement.

4123. The system of claim 4101, further comprising an overburden casing coupled to the opening, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the packing material is further configurable to substantially inhibit a flow of fluid between the opening and the overburden casing during use.

4124. The system of claim 4101, wherein the heated section of the formation is substantially pyrolyzed.

4125. The system of claim 4101, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

at least one elongated member disposed within an opening in the formation, wherein at least the one elongated member is configured to provide heat to at least a portion of the formation during use;

an oxidizing fluid source;

a conduit disposed within the opening, wherein the conduit is configured to provide an oxidizing fluid from the oxidizing fluid source to the opening during use, and wherein the oxidizing fluid is selected to substantially inhibit carbon deposition on or proximate to at least the one elongated member during use; and

wherein the system is configured to allow heat to transfer from at least the one elongated member to a section of the formation during use.

4126. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to at least one elongated member to provide heat to at least a portion of the formation, wherein at least the one elongated member is disposed within an opening in the formation;

providing an oxidizing fluid to at least the one elongated member to substantially inhibit carbon deposition on or proximate to at least the one elongated member; and

allowing heat to transfer from at least the one elongated member to a section of the formation.

4127. The method of claim 4126, wherein at least the one elongated member comprises a metal strip.

4128. The method of claim 4126, wherein at least the one elongated member comprises a metal rod.

4129. The method of claim 4126, wherein at least the one elongated member comprises stainless steel.

4130. The method of claim 4126, further comprising supporting at least the one elongated member on a center support member.

4131. The method of claim 4126, further comprising supporting at least the one elongated member on a center support member, wherein the center support member comprises a tube.

4132. The method of claim 4126, further comprising electrically isolating at least the one elongated member with a centralizer.

4133. The method of claim 4126, further comprising laterally spacing at least the one elongated member with a centralizer.

4134. The method of claim 4126, further comprising electrically coupling at least the one elongated member in a series configuration.

4135. The method of claim 4126, further comprising electrically coupling at least the one elongated member in a parallel configuration.

4136. The method of claim 4126, wherein the provided heat comprises approximately 650 W/m to approximately 1650 W/m.

4137. The method of claim 4126, further comprising determining a temperature distribution in at least the one elongated member using an electromagnetic signal provided to at least the one elongated member.

4138. The method of claim 4126, further comprising monitoring the applied electrical current.

4139. The method of claim 4126, further comprising monitoring a voltage applied to at least the one elongated member.

4140. The method of claim 4126, further comprising monitoring a temperature in at least the one elongated member with at least one thermocouple.

4141. The method of claim 4126, further comprising supporting at least the one elongated member on a center support member, wherein the center support member comprises openings, wherein providing the oxidizing fluid to at least the one elongated member comprises flowing the oxidizing fluid through the openings in the center support member.

4142. The method of claim 4126, wherein providing the oxidizing fluid to at least the one elongated member comprises flowing the oxidizing fluid through orifices in a tube disposed in the opening proximate to at least the one elongated member.

4143. The method of claim 4126, further comprising electrically coupling a lead-in conductor to at least the one elongated member, wherein the lead-in conductor comprises a low resistance conductor configured to generate substantially no heat.

4144. The method of claim 4126, further comprising electrically coupling a lead-in conductor to at least the one elongated member using a cold pin transition conductor.

4145. The method of claim 4126, further comprising electrically coupling a lead-in conductor to at least the one elongated member using a cold pin transition conductor, wherein the cold pin transition conductor comprises a substantially low resistance insulated conductor.

4146. The method of claim 4126, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in an overburden of the formation.

4147. The method of claim 4126, further comprising coupling an overburden casing to the opening, wherein the overburden casing comprises steel.

4148. The method of claim 4126, further comprising coupling an overburden casing to the opening, wherein the overburden casing is disposed in cement.

4149. The method of claim 4126, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening.

4150. The method of claim 4126, further comprising coupling an overburden casing to the opening, wherein a packing material is disposed at a junction of the overburden casing and the opening, and wherein the method further comprises inhibiting a flow of fluid between the opening and the overburden casing with the packing material.

4151. The method of claim 4126, further comprising heating at least the portion of the formation to substantially pyrolyze at least some of the hydrocarbons within the formation.

4152. An in situ method for heating a hydrocarbon containing formation, comprising:

oxidizing a fuel fluid in a heater;

providing at least a portion of the oxidized fuel fluid into a conduit disposed in an opening of the formation;

allowing heat to transfer from the oxidized fuel fluid to a section of the formation; and

allowing additional heat to transfer from an electric heater disposed in the opening to the section of the formation, wherein heat is allowed to transfer substantially uniformly along a length of the opening.

4153. The method of claim 4152, wherein providing at least the portion of the oxidized fuel fluid into the opening comprises flowing the oxidized fuel fluid through a perforated conduit disposed in the opening.

4154. The method of claim 4152, wherein providing at least the portion of the oxidized fuel fluid into the opening comprises flowing the oxidized fuel fluid through a perforated conduit disposed in the opening, the method further comprising removing an exhaust fluid through the opening.

4155. The method of claim 4152, further comprising initiating oxidation of the fuel fluid in the heater with a flame.

4156. The method of claim 4152, further comprising removing the oxidized fuel fluid through the conduit.

4157. The method of claim 4152, further comprising removing the oxidized fuel fluid through the conduit and providing the removed oxidized fuel fluid to at least one additional heater disposed in the formation.

4158. The method of claim 4152, wherein the conduit comprises an insulator disposed on a surface of the conduit, the method further comprising tapering a thickness of the insulator such that heat is allowed to transfer substantially uniformly along a length of the conduit.

4159. The method of claim 4152, wherein the electric heater is an insulated conductor.

4160. The method of claim 4152, wherein the electric heater is a conductor disposed in the conduit.

4161. The method of claim 4152, wherein the electric heater is an elongated conductive member.

4162. The method of claim 4152, wherein the hydrocarbon containing formation comprises a coal formation.

4163. The method of claim 4152, wherein the hydrocarbon containing formation comprises an oil shale formation.

4164. The method of claim 4152, wherein the hydrocarbon containing formation comprises a heavy oil and/or tar containing permeable formation.

4165. The method of claim 4152, wherein the hydrocarbon containing formation comprises a heavy oil and/or tar containing impermeable formation.

4166. A system configured to heat a hydrocarbon containing formation, comprising:

one or more heaters disposed within one or more open wellbores in the formation, wherein the one or more heaters are configured to provide heat to at least a portion of the formation during use; and

wherein the system is configured to allow heat to transfer from the one or more heaters to a selected section of the formation during use.

4167. The system of claim 4166, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

4168. The system of claim 4166, wherein the one or more heaters comprise electrical heaters.

4169. The system of claim 4166, wherein the one or more heaters comprise surface burners.

4170. The system of claim 4166, wherein the one or more heaters comprise flameless distributed combustors.

4171. The system of claim 4166, wherein the one or more heaters comprise natural distributed combustors.

4172. The system of claim 4166, wherein the one or more open wellbores comprise a diameter of at least approximately 5 cm.

4173. The system of claim 4166, further comprising an overburden casing coupled to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation.

4174. The system of claim 4166, further comprising an overburden casing coupled to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

4175. The system of claim 4166, further comprising an overburden casing coupled to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

4176. The system of claim 4166, further comprising an overburden casing coupled to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the at least one of the one or more open wellbores.

4177. The system of claim 4166, further comprising an overburden casing coupled to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the at least one of the one or more open wellbores, and wherein the packing material is configured to substantially inhibit a flow of fluid between at least one of the one or more open wellbores and the overburden casing during use.

4178. The system of claim 4166, further comprising an overburden casing coupled to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation, wherein a packing material is disposed at a junction of the overburden casing and the at least one of the one or more open wellbores, and wherein the packing material comprises cement.

4179. The system of claim 4166, wherein the system is further configured to transfer heat such that the transferred heat can pyrolyze at least some hydrocarbons in the selected section.

4180. The system of claim 4166, further comprising a valve coupled to at least one of the one or more heaters configured to control pressure within at least a majority of the selected section of the formation.

4181. The system of claim 4166, further comprising a valve coupled to a production well configured to control a pressure within at least a majority of the selected section of the formation.

4182. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the formation, wherein the one or more heaters are disposed within one or more open wellbores in the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

producing a mixture from the formation.

4183. The method of claim 4182, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

4184. The method of claim 4182, wherein controlling formation conditions comprises maintaining a temperature within the selected section within a pyrolysis temperature range with a lower pyrolysis temperature of about 250°

C. and an upper pyrolysis temperature of about 400°

C.

4185. The method of claim 4182, wherein the one or more heaters comprise electrical heaters.

4186. The method of claim 4182, wherein the one or more heaters comprise surface burners.

4187. The method of claim 4182, wherein the one or more heaters comprise flameless distributed combustors.

4188. The method of claim 4182, wherein the one or more heaters comprise natural distributed combustors.

4189. The method of claim 4182, wherein the one or more heaters are suspended within the one or more open wellbores.

4190. The method of claim 4182, wherein a tube is disposed in at least one of the one or more open wellbores proximate to the heater, the method further comprising flowing a substantially constant amount of fluid into at least one of the one or more open wellbores through critical flow orifices in the tube.

4191. The method of claim 4182, wherein a perforated tube is disposed in at least one of the one or more open wellbores proximate to the heater, the method further comprising flowing a corrosion inhibiting fluid into at least one of the open wellbores through the perforated tube.

4192. The method of claim 4182, further comprising coupling an overburden casing to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation.

4193. The method of claim 4182, further comprising coupling an overburden casing to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing comprises steel.

4194. The method of claim 4182, further comprising coupling an overburden casing to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation, and wherein the overburden casing is further disposed in cement.

4195. The method of claim 4182, further comprising coupling an overburden casing to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation, and wherein a packing material is disposed at a junction of the overburden casing and the at least one of the one or more open wellbores.

4196. The method of claim 4182, further comprising coupling an overburden casing to at least one of the one or more open wellbores, wherein the overburden casing is disposed in an overburden of the formation, and wherein the method further comprises inhibiting a flow of fluid between the at least one of the one or more open wellbores and the overburden casing with a packing material.

4197. The method of claim 4182, further comprising heating at least the portion of the formation to substantially pyrolyze at least some of the hydrocarbons within the formation.

4198. The method of claim 4182, further comprising controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

4199. The method of claim 4182, further comprising controlling a pressure with the wellbore.

4200. The method of claim 4182, further comprising controlling a pressure within at least a majority of the selected section of the formation with a valve coupled to at least one of the one or more heaters.

4201. The method of claim 4182, further comprising controlling a pressure within at least a majority of the selected section of the formation with a valve coupled to a production well located in the formation.

4202. The method of claim 4182, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1°

C. per day during pyrolysis.

4203. The method of claim 4182, wherein providing heat from the one or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity(C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

4204. The method of claim 4182, wherein allowing the heat to transfer from the one or more heaters to the selected section comprises transferring heat substantially by conduction.

4205. The method of claim 4182, wherein providing heat from the one or more heaters comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/(m °

C.).

4206. The method of claim 4182, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

4207. The method of claim 4182, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

4208. The method of claim 4182, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

4209. The method of claim 4182, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.

4210. The method of claim 4182, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

4211. The method of claim 4182, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

4212. The method of claim 4182, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4213. The method of claim 4182, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4214. The method of claim 4182, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

4215. The method of claim 4182, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4216. The method of claim 4182, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

4217. The method of claim 4182, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

4218. The method of claim 4182, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, and wherein the hydrogen is greater than about 10% by volume of the non-condensable component and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

4219. The method of claim 4182, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4220. The method of claim 4182, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

4221. The method of claim 4182, further comprising controlling a pressure within at least a majority of the selected section of the formation.

4222. The method of claim 4182, further comprising controlling a pressure within at least a majority of the selected section of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

4223. The method of claim 4182, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H₂ within the mixture greater than about 0.5 bars.

4224. The method of claim 4223, wherein the partial pressure of H₂ is measured when the mixture is at a production well.

4225. The method of claim 4182, wherein controlling formation conditions comprises recirculating a portion of hydrogen from the mixture into the formation.

4226. The method of claim 4182, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

4227. The method of claim 4182, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

4228. The method of claim 4182, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

4229. The method of claim 4182, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

4230. The method of claim 4182, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the selected section.

4231. The method of claim 4182, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

4232. The method of claim 4182, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for the production well.

4233. The method of claim 4182, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

4234. The method of claim 4182, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

4235. The method of claim 4182, further comprising separating the produced mixture into a gas stream and a liquid stream.

4236. The method of claim 4182, further comprising separating the produced mixture into a gas stream and a liquid stream and separating the liquid stream into an aqueous stream and a non-aqueous stream.

4237. The method of claim 4182, wherein the produced mixture comprises H₂S, the method further comprising separating a portion of the H₂S from non-condensable hydrocarbons.

4238. The method of claim 4182, wherein the produced mixture comprises CO₂, the method further comprising separating a portion of the CO₂ from non-condensable hydrocarbons.

4239. The method of claim 4182, wherein the mixture is produced from a production well, wherein the heating is controlled such that the mixture can be produced from the formation as a vapor.

4240. The method of claim 4182, wherein the mixture is produced from a production well, the method further comprising heating a wellbore of the production well to inhibit condensation of the mixture within the wellbore.

4241. The method of claim 4182, wherein the mixture is produced from a production well, wherein a wellbore of the production well comprises a heater element configured to heat the formation adjacent to the wellbore, and further comprising heating the formation with the heater element to produce the mixture, wherein the mixture comprises a large non-condensable hydrocarbon gas component and H₂.

4242. The method of claim 4182, wherein the selected section is heated to a minimum pyrolysis temperature of about 270°

C.

4243. The method of claim 4182, further comprising maintaining the pressure within the formation above about 2.0 bars absolute to inhibit production of fluids having carbon numbers above 25.

4244. The method of claim 4182, further comprising controlling pressure within the formation in a range from about atmospheric pressure to about 100 bar, as measured at a wellhead of a production well, to control an amount of condensable hydrocarbons within the produced mixture, wherein the pressure is reduced to increase production of condensable hydrocarbons, and wherein the pressure is increased to increase production of non-condensable hydrocarbons.

4245. The method of claim 4182, further comprising controlling pressure within the formation in a range from about atmospheric pressure to about 100 bar, as measured at a wellhead of a production well, to control an API gravity of condensable hydrocarbons within the produced mixture, wherein the pressure is reduced to decrease the API gravity, and wherein the pressure is increased to reduce the API gravity.

4246. A mixture produced from a portion of a hydrocarbon containing formation, the mixture comprising:

an olefin content of less than about 10% by weight; and

an average carbon number less than about 35.

4247. The mixture of claim 4246, further comprising an average carbon number less than about 30.

4248. The mixture of claim 4246, further comprising an average carbon number less than about 25.

4249. The mixture of claim 4246, further comprising:

non-condensable hydrocarbons comprising hydrocarbons having carbon numbers of less than 5; and

wherein a weight ratio of the hydrocarbons having carbon numbers from 2 through 4, to methane, in the mixture is greater than approximately 1.

4250. The mixture of claim 4246, further comprising condensable hydrocarbons, wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen, wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4251. The mixture of claim 4246, further comprising ammonia, wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4252. The mixture of claim 4246, further comprising condensable hydrocarbons, wherein an olefin content of the condensable hydrocarbons is greater than about 0.1% by weight of the condensable hydrocarbons, and wherein the olefin content of the condensable hydrocarbons is less than about 15% by weight of the condensable hydrocarbons.

4253. The mixture of claim 4246, further comprising condensable hydrocarbons, wherein less than about 15% by weight of the condensable hydrocarbons have a carbon number greater than about 25.

4254. The mixture of claim 4253, wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen, wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4255. The mixture of claim 4246, further comprising condensable hydrocarbons, wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

4256. The mixture of claim 4246, further comprising:

non-condensable hydrocarbons comprising hydrocarbons having carbon numbers of less than about 5, wherein a weight ratio of the hydrocarbons having carbon number from 2 through 4, to methane, in the mixture is greater than approximately 1;

wherein the non-condensable hydrocarbons further comprise H₂, wherein greater than about 15% by weight of the non-condensable hydrocarbons comprises H₂; and

condensable hydrocarbons, comprising;

oxygenated hydrocarbons, wherein greater than about 1.5% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons; and

aromatic compounds, wherein greater than about 20% by weight of the condensable hydrocarbons comprises aromatic compounds.

4257. The mixture of claim 4246, further comprising:

condensable hydrocarbons, wherein less than about 5% by weight of the condensable hydrocarbons comprises hydrocarbons having a carbon number greater than about 25;

wherein the condensable hydrocarbons further comprise;

oxygenated hydrocarbons, wherein greater than about 5% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons; and

aromatic compounds, wherein greater than about 30% by weight of the condensable hydrocarbons comprises aromatic compounds; and

non-condensable hydrocarbons comprising H₂, wherein greater than about 15% by weight of the non-condensable hydrocarbons comprises H₂.

4258. The mixture of claim 4246, further comprising condensable hydrocarbons, comprising:

olefins, wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons comprises olefins; and

asphaltenes, wherein less than about 0.1% by weight of the condensable hydrocarbons comprises asphaltenes.

4259. The mixture of claim 4258, further comprising oxygenated hydrocarbons, wherein less than about 15% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons.

4260. The mixture of claim 4246, further comprising condensable hydrocarbons, comprising:

olefins, wherein about 0.1% by weight to about 2% by weight of the condensable hydrocarbons comprises olefins; and

multi-ring aromatics, wherein less than about 2% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4261. The mixture of claim 4246, further comprising oxygenated hydrocarbons, wherein greater than about 25% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons.

4262. The mixture of claim 4246, further comprising:

non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise H₂, wherein greater than about 10% by weight of the non-condensable hydrocarbons comprises H₂;

ammonia, wherein greater than about 0.5% by weight of the mixture comprises ammonia; and

hydrocarbons, wherein a weight ratio of hydrocarbons having greater than about 2 carbon atoms, to methane, is greater than about 0.4.

4263. A mixture produced from a portion of a hydrocarbon containing formation, the mixture, comprising:

non-condensable hydrocarbons comprising hydrocarbons having carbon numbers of less than 5; and

wherein a weight ratio of the hydrocarbons having carbon numbers from 2 through 4, to methane, in the mixture is greater than approximately 1.

4264. The mixture of claim 4263, further comprising condensable hydrocarbons, wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

4265. The mixture of claim 4263, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

4266. The mixture of claim 4263, further comprising condensable hydrocarbons, wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

4267. The mixture of claim 4263, further comprising condensable hydrocarbons, wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

4268. The mixture of claim 4263, further comprising condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4269. The mixture of claim 4263, further comprising condensable hydrocarbons, wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4270. The mixture of claim 4263, further comprising condensable hydrocarbons, wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

4271. The mixture of claim 4263, further comprising condensable hydrocarbons, wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4272. The mixture of claim 4263, further comprising condensable hydrocarbons, wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

4273. The mixture of claim 4263, further comprising condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise cycloalkanes.

4274. The mixture of claim 4263, wherein the non-condensable hydrocarbons further comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable hydrocarbons, and wherein the hydrogen is less than about 80% by volume of the non-condensable hydrocarbons.

4275. The mixture of claim 4263, further comprising ammonia, wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4276. The mixture of claim 4263, further comprising ammonia, wherein the ammonia is used to produce fertilizer.

4277. The mixture of claim 4263, further comprising condensable hydrocarbons, wherein less than about 15 weight % of the condensable hydrocarbons have a carbon number greater than approximately 25.

4278. The mixture of claim 4263, further comprising condensable hydrocarbons, wherein the condensable hydrocarbons comprise olefins, and wherein about 0.1% to about 5% by weight of the condensable hydrocarbons comprises olefins.

4279. The mixture of claim 4263, further comprising condensable hydrocarbons, wherein the condensable hydrocarbons comprises olefins, and wherein about 0.1% to about 2.5% by weight of the condensable hydrocarbons comprises olefins.

4280. The mixture of claim 4263, further comprising condensable hydrocarbons, wherein the condensable hydrocarbons comprise oxygenated hydrocarbons, and wherein greater than about 5% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons.

4281. The mixture of claim 4263, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise H₂, and wherein greater than about 5% by weight of the non-condensable hydrocarbons comprises H₂.

4282. The mixture of claim 4263, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise H₂, and wherein greater than about 15% by weight of the non-condensable hydrocarbons comprises H₂.

4283. The mixture of claim 4263, wherein a weight ratio of hydrocarbons having greater than about 2 carbon atoms, to methane, is greater than about 0.3.

4284. A mixture produced from a portion of a hydrocarbon containing formation, the mixture comprising:

non-condensable hydrocarbons comprising hydrocarbons having carbon numbers of less than 5, wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1; and

condensable hydrocarbons comprising oxygenated hydrocarbons, wherein greater than about 5% by weight of the condensable component comprises oxygenated hydrocarbons.

4285. The mixture of claim 4284, wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

4286. The mixture of claim 4284, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

4287. The mixture of claim 4284, wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

4288. The mixture of claim 4284, wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

4289. The mixture of claim 4284, wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4290. The mixture of claim 4284, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4291. The mixture of claim 4284, wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

4292. The mixture of claim 4284, wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4293. The mixture of claim 4284, wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

4294. The mixture of claim 4284, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

4295. The mixture of claim 4284, wherein the non-condensable hydrocarbons comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable hydrocarbons, and wherein the hydrogen is less than about 80% by volume of the non-condensable hydrocarbons.

4296. The mixture of claim 4284, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4297. The mixture of claim 4284, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

4298. The mixture of claim 4284, wherein less than about 5 weight % of the condensable hydrocarbons in the mixture have a carbon number greater than approximately 25.

4299. The mixture of claim 4284, wherein the condensable hydrocarbons further comprise olefins, and wherein about 0.1% to about 5% by weight of the condensable hydrocarbons comprises olefins.

4300. The mixture of claim 4284, wherein the condensable hydrocarbons further comprise olefins, and wherein about 0.1% to about 2.5% by weight of the condensable hydrocarbons comprises olefins.

4301. The mixture of claim 4284, wherein the non-condensable hydrocarbons further comprise H₂, wherein greater than about 5% by weight of the mixture comprises H₂.

4302. The mixture of claim 4284, wherein the non-condensable hydrocarbons further comprise H₂, wherein greater than about 15% by weight of the mixture comprises H₂.

4303. The mixture of claim 4284, wherein a weight ratio of hydrocarbons having greater than about 2 carbon atoms, to methane, is greater than about 0.3.

4304. A mixture produced from a portion of a hydrocarbon containing formation, the mixture comprising:

non-condensable hydrocarbons comprising hydrocarbons having carbon numbers of less than 5, wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1;

condensable hydrocarbons;

wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons comprises nitrogen;

wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons comprises oxygen; and

wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons comprises sulfur.

4305. The mixture of claim 4304, further comprising ammonia, wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4306. The mixture of claim 4304, wherein less than about 5 weight % of the condensable hydrocarbons have a carbon number greater than approximately 25.

4307. The mixture of claim 4304, wherein the condensable hydrocarbons comprise olefins, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

4308. The mixture of claim 4304, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

4309. The mixture of claim 4304, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4310. The mixture of claim 4304, wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

4311. The mixture of claim 4304, wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4312. The mixture of claim 4304, wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

4313. The mixture of claim 4304, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

4314. The mixture of claim 4304, wherein the non-condensable hydrocarbons comprises hydrogen, and wherein the hydrogen is greater than about 10% by volume of the non-condensable hydrocarbons and wherein the hydrogen is less than about 80% by volume of the non-condensable hydrocarbons.

4315. The mixture of claim 4304, further comprising ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4316. The mixture of claim 4304, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.

4317. The mixture of claim 4304, wherein the condensable hydrocarbons comprises oxygenated hydrocarbons, and wherein greater than about 5% by weight of the condensable component comprises oxygenated hydrocarbons.

4318. The mixture of claim 4304, wherein the non-condensable hydrocarbons comprise H₂, and wherein greater than about 5% by weight of the non-condensable hydrocarbons comprises H₂.

4319. The mixture of claim 4304, wherein the non-condensable hydrocarbons comprise H₂, and wherein greater than about 15% by weight of the mixture comprises H₂.

4320. The mixture of claim 4304, wherein a weight ratio of hydrocarbons having greater than about 2 carbon atoms, to methane, is greater, than about 0.3.

4321. A mixture produced from a portion of a hydrocarbon containing formation, the mixture comprising:

non-condensable hydrocarbons comprising hydrocarbons having carbon numbers of less than 5, wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1;

ammonia, wherein greater than about 0.5% by weight of the mixture comprises ammonia; and

condensable hydrocarbons comprising oxygenated hydrocarbons, wherein greater than about 5% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons.

4322. The mixture of claim 4321, wherein the condensable hydrocarbons further comprise olefins, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

4323. The mixture of claim 4321, wherein the non-condensable hydrocarbons further comprise ethene and ethane, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

4324. The mixture of claim 4321, wherein the condensable hydrocarbons further comprise nitrogen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

4325. The mixture of claim 4321, wherein the condensable hydrocarbons further comprise oxygen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

4326. The mixture of claim 4321, wherein the condensable hydrocarbons further comprise sulfur containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4327. The mixture of claim 4321, wherein the condensable hydrocarbons further comprise oxygen containing compounds, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4328. The mixture of claim 4321, wherein the condensable hydrocarbons further comprise aromatic compounds, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

4329. The mixture of claim 4321, wherein the condensable hydrocarbons further comprise multi-aromatic rings, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4330. The mixture of claim 4321, wherein the condensable hydrocarbons further comprise asphaltenes, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

4331. The mixture of claim 4321, wherein the condensable hydrocarbons further comprise cycloalkanes, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

4332. The mixture of claim 4321, wherein the non-condensable hydrocarbons further comprise hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable hydrocarbons, and wherein the hydrogen is less than about 80% by volume of the non-condensable hydrocarbons.

4333. The mixture of claim 4321, wherein the produced mixture further comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4334. The mixture of claim 4321, wherein the produced mixture further comprises ammonia, and wherein the ammonia is used to produce fertilizer.

4335. The mixture of claim 4321, wherein the condensable hydrocarbons comprise hydrocarbons having a carbon number of greater than approximately 25, and wherein less than about 15 weight % of the hydrocarbons in the mixture have a carbon number greater than approximately 25.

4336. The mixture of claim 4321, wherein the non-condensable hydrocarbons further comprise H₂, and wherein greater than about 5% by weight of the mixture comprises H₂.

4337. The mixture of claim 4321, wherein the non-condensable hydrocarbons further comprise H₂, and wherein greater than about 15% by weight of the mixture comprises H₂.

4338. The mixture of claim 4321, wherein the non-condensable hydrocarbons further comprise hydrocarbons having carbon numbers of greater than 2, wherein a weight ratio of hydrocarbons having carbon numbers greater than 2, to methane, is greater than about 0.3.

4339. A mixture produced from a portion of a hydrocarbon containing formation, the mixture comprising:

non-condensable hydrocarbons comprising hydrocarbons having carbon numbers of less than 5, wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1; and

condensable hydrocarbons comprising olefins, wherein less than about 10% by weight of the condensable hydrocarbons comprises olefins.

4340. The mixture of claim 4339, wherein the non-condensable hydrocarbons further comprise ethene and ethane, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

4341. The mixture of claim 4339, wherein the condensable hydrocarbons further comprise nitrogen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

4342. The mixture of claim 4339, wherein the condensable hydrocarbons further comprise oxygen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

4343. The mixture of claim 4339, wherein the condensable hydrocarbons further comprise sulfur containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4344. The mixture of claim 4339, wherein the condensable hydrocarbons further comprise oxygen containing compounds, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4345. The mixture of claim 4339, wherein the condensable hydrocarbons further comprise aromatic compounds, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

4346. The mixture of claim 4339, wherein the condensable hydrocarbons further comprise multi-ring aromatics, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4347. The mixture of claim 4339, wherein the condensable hydrocarbons further comprise asphaltenes, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

4348. The mixture of claim 4339, wherein the condensable hydrocarbons further comprise cycloalkanes, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

4349. The mixture of claim 4339, wherein the non-condensable hydrocarbons further comprise hydrogen, and wherein the hydrogen is greater than about 10% by volume of the non-condensable hydrocarbons and wherein the hydrogen is less than about 80% by volume of the non-condensable hydrocarbons.

4350. The mixture of claim 4339, wherein the produced mixture further comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4351. The mixture of claim 4339, wherein the produced mixture further comprises ammonia, and wherein the ammonia is used to produce fertilizer.

4352. The mixture of claim 4339, wherein the condensable hydrocarbons further comprise hydrocarbons having a carbon number of greater than approximately 25, and wherein less than about 15% by weight of the hydrocarbons have a carbon number greater than approximately 25.

4353. The mixture of claim 4339, wherein about 0.1% to about 5% by weight of the condensable component comprises olefins.

4354. The mixture of claim 4339, wherein about 0.1% to about 2% by weight of the condensable component comprises olefins.

4355. The mixture of claim 4339, wherein the condensable hydrocarbons further comprise oxygenated hydrocarbons, and wherein greater than about 5% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons.

4356. The mixture of claim 4339, wherein the condensable hydrocarbons further comprise oxygenated hydrocarbons, and wherein greater than about 25% by weight of the condensable component comprises oxygenated hydrocarbons.

4357. The mixture of claim 4339, wherein the non-condensable hydrocarbons further comprise H₂, and wherein greater than about 5% by weight of the non-condensable hydrocarbons comprises H₂.

4358. The mixture of claim 4339, wherein the non-condensable hydrocarbons further comprise H₂, and wherein greater than about 15% by weight of the non-condensable hydrocarbons comprises H₂.

4359. The mixture of claim 4339, wherein a weight ratio of hydrocarbons having greater than about 2 carbon atoms, to methane, is greater than about 0.3.

4360. A mixture produced from a portion of a hydrocarbon containing formation, comprising:

condensable hydrocarbons, wherein less than about 15 weight % of the condensable hydrocarbons have a carbon number greater than 25; and

wherein the condensable hydrocarbons comprise oxygenated hydrocarbons, and wherein greater than about 5% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons.

4361. The mixture of claim 4360, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise hydrocarbons having carbon numbers of less than 5, and wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1.

4362. The mixture of claim 4360, wherein the condensable hydrocarbons further comprise olefins, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

4363. The mixture of claim 4360, further comprising non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

4364. The mixture of claim 4360, wherein the condensable hydrocarbons further comprise nitrogen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

4365. The mixture of claim 4360, wherein the condensable hydrocarbons further comprise oxygen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

4366. The mixture of claim 4360, wherein the condensable hydrocarbons further comprise sulfur containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4367. The mixture of claim 4360, wherein the condensable hydrocarbons further comprise oxygen containing compounds, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4368. The mixture of claim 4360, wherein the condensable hydrocarbons further comprise aromatic compounds, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

4369. The mixture of claim 4360, wherein the condensable hydrocarbons further comprise multi-ring aromatics, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4370. The mixture of claim 4360, wherein the condensable hydrocarbons further comprise asphaltenes, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

4371. The mixture of claim 4360, wherein the condensable hydrocarbons further comprise cycloalkanes, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

4372. The mixture of claim 4360, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise hydrogen, and wherein the hydrogen is greater than about 10% by volume of the non-condensable hydrocarbons and wherein the hydrogen is less than about 80% by volume of the non-condensable hydrocarbons.

4373. The mixture of claim 4360, further comprising ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4374. The mixture of claim 4360, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.

4375. The mixture of claim 4360, wherein the condensable hydrocarbons further comprises olefins, and wherein less than about 10% by weight of the condensable hydrocarbons comprises olefins.

4376. The mixture of claim 4360, wherein the condensable hydrocarbons further comprises olefins, and wherein about 0.1% to about 5% by weight of the condensable hydrocarbons comprises olefins.

4377. The mixture of claim 4360, wherein the condensable hydrocarbons further comprises olefins, and wherein about 0.1% to about 2% by weight of the condensable hydrocarbons comprises olefins.

4378. The mixture of claim 4360, wherein the condensable hydrocarbons further comprises oxygenated hydrocarbons, and wherein greater than about 5% by weight of the condensable hydrocarbons comprises the oxygenated hydrocarbon.

4379. The mixture of claim 4360, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise H₂, wherein greater than about 5% by weight of the non-condensable hydrocarbons comprises H₂.

4380. The mixture of claim 4360, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise H₂, wherein greater than about 15% by weight of the non-condensable hydrocarbons comprises H₂.

4381. The mixture of claim 4360, wherein a weight ratio of hydrocarbons having greater than about 2 carbon atoms, to methane, is greater than about 0.3.

4382. A mixture produced from a portion of a hydrocarbon containing formation, comprising:

condensable hydrocarbons, wherein less than about 15% by weight of the condensable hydrocarbons have a carbon number greater than about 25;

wherein less than about 1% by weight of the condensable hydrocarbons, when calculated on an atomic basis, is nitrogen;

wherein less than about 1% by weight of the condensable hydrocarbons, when calculated on an atomic basis, is oxygen; and

wherein less than about 1% by weight of the condensable hydrocarbons, when calculated on an atomic basis, is sulfur.

4383. The mixture of claim 4382, further comprising non-condensable hydrocarbons, wherein the non-condensable component comprises hydrocarbons having carbon numbers of less than 5, and wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1.

4384. The mixture of claim 4382, wherein the condensable hydrocarbons further comprise olefins, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

4385. The mixture of claim 4382, further comprising non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

4386. The mixture of claim 4382, wherein the condensable hydrocarbons further comprise oxygen containing compounds, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4387. The mixture of claim 4382, wherein the condensable hydrocarbons further comprise aromatic compounds, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

4388. The mixture of claim 4382, wherein the condensable hydrocarbons further comprise multi-ring aromatics, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4389. The mixture of claim 4382, wherein the condensable hydrocarbons further comprise asphaltenes, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

4390. The mixture of claim 4382, wherein the condensable hydrocarbons further comprise cycloalkanes, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

4391. The mixture of claim 4382, further comprising non-condensable hydrocarbons, and wherein the non-condensable hydrocarbons comprise hydrogen, and wherein greater than about 10% by volume and less than about 80% by volume of the non-condensable component comprises hydrogen.

4392. The mixture of claim 4382, further comprising ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4393. The mixture of claim 4382, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.

4394. The mixture of claim 4382, wherein the condensable component further comprises olefins, and wherein about 0.1% to about 5% by weight of the condensable component comprises olefins.

4395. The mixture of claim 4382, wherein the condensable component further comprises olefins, and wherein about 0.1% to about 2.5% by weight of the condensable component comprises olefins.

4396. The mixture of claim 4382, wherein the condensable hydrocarbons further comprise oxygenated hydrocarbons, and wherein greater than about 5% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons.

4397. The mixture of claim 4382, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise H₂, and wherein greater than about 5% by weight of the non-condensable hydrocarbons comprises H₂.

4398. The mixture of claim 4382, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise H₂, and wherein greater than about 15% by weight of the non-condensable hydrocarbons comprises H₂.

4399. The mixture of claim 4382, further comprising non-condensable hydrocarbons, wherein a weight ratio of compounds within the non-condensable hydrocarbons having greater than about 2 carbon atoms, to methane, is greater than about 0.3.

4400. A mixture produced from a portion of a hydrocarbon containing formation, comprising:

condensable hydrocarbons, wherein less than about 15% by weight of the condensable hydrocarbons have a carbon number greater than 20; and

wherein the condensable hydrocarbons comprise olefins, wherein an olefin content of the condensable component is less than about 10% by weight of the condensable component.

4401. The mixture of claim 4400, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise hydrocarbons having carbon numbers of less than 5, and wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1.

4402. The mixture of claim 4400, wherein the condensable hydrocarbons further comprise olefins, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

4403. The mixture of claim 4400, further comprising non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

4404. The mixture of claim 4400, wherein the condensable hydrocarbons further comprise nitrogen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

4405. The mixture of claim 4400, wherein the condensable hydrocarbons further comprise oxygen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

4406. The mixture of claim 4400, wherein the condensable hydrocarbons further comprise sulfur containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4407. The mixture of claim 4400, wherein the condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4408. The mixture of claim 4400, wherein the condensable hydrocarbons further comprise aromatic compounds, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

4409. The mixture of claim 4400, wherein the condensable hydrocarbons further comprise multi-ring aromatics, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4410. The mixture of claim 4400, wherein the condensable hydrocarbons further comprise asphaltenes, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

4411. The mixture of claim 4400, wherein the condensable hydrocarbons further comprise cycloalkanes, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

4412. The mixture of claim 4400, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprises hydrogen, and wherein the hydrogen is about 10% by volume to about 80% by volume of the non-condensable hydrocarbons.

4413. The mixture of claim 4400, further comprising ammonia, wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4414. The mixture of claim 4400, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.

4415. The mixture of claim 4400, wherein about 0.1% to about 5% by weight of the condensable component comprises olefins.

4416. The mixture of claim 4400, wherein about 0.1% to about 2% by weight of the condensable component comprises olefins.

4417. The mixture of claim 4400, wherein the condensable component further comprises oxygenated hydrocarbons, and wherein greater than about 1.5% by weight of the condensable component comprises oxygenated hydrocarbons.

4418. The mixture of claim 4400, wherein the condensable component further comprises oxygenated hydrocarbons, and wherein greater than about 25% by weight of the condensable component comprises oxygenated hydrocarbons.

4419. The mixture of claim 4400, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise H₂, and wherein greater than about 5% by weight of the non-condensable hydrocarbons comprises H₂.

4420. The mixture of claim 4400, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise H₂, and wherein greater than about 15% by weight of the non-condensable hydrocarbons comprises H₂.

4421. The mixture of claim 4400, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise hydrocarbons having carbon numbers of less than 5, and wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 0.3.

4422. A mixture produced from a portion of a hydrocarbon containing formation, comprising:

condensable hydrocarbons, wherein less than about 5% by weight of the condensable hydrocarbons comprises hydrocarbons having a carbon number greater than about 25; and

wherein the condensable hydrocarbons further comprise aromatic compounds, wherein more than about 20% by weight of the condensable hydrocarbons comprises aromatic compounds.

4423. The mixture of claim 4422, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise hydrocarbons having carbon numbers of less than 5, and wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1.

4424. The mixture of claim 4422, wherein the condensable hydrocarbons further comprise olefins, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

4425. The mixture of claim 4422, further comprising non-condensable hydrocarbons, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

4426. The mixture of claim 4422, wherein the condensable hydrocarbons further comprise nitrogen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

4427. The mixture of claim 4422, wherein the condensable hydrocarbons further comprise oxygen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

4428. The mixture of claim 4422, wherein the condensable hydrocarbons further comprise sulfur containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4429. The mixture of claim 4422, wherein the condensable hydrocarbons further comprise oxygen containing compounds, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4430. The mixture of claim 4422, wherein the condensable hydrocarbons further comprise multi-ring aromatics, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4431. The mixture of claim 4422, wherein the condensable hydrocarbons further comprise asphaltenes, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

4432. The mixture of claim 4422, wherein the condensable hydrocarbons comprise cycloalkanes, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

4433. The mixture of claim 4422, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise hydrogen, and wherein the hydrogen is greater than about 10% by volume and less than about 80% by volume of the non-condensable hydrocarbons.

4434. The mixture of claim 4422, further comprising ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4435. The mixture of claim 4422, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.

4436. The mixture of claim 4422, wherein the condensable hydrocarbons further comprise olefins, and wherein about 0.1% to about 5% by weight of the condensable hydrocarbons comprises olefins.

4437. The mixture of claim 4422, wherein the condensable hydrocarbons further comprises olefins, and wherein about 0.1% to about 2% by weight of the condensable hydrocarbons comprises olefins.

4438. The mixture of claim 4422, wherein the condensable hydrocarbons further comprises multi-ring aromatic compounds, and wherein less than about 2% by weight of the condensable hydrocarbons comprises multi-ring aromatic compounds.

4439. The mixture of claim 4422, wherein the condensable hydrocarbons comprises oxygenated hydrocarbons, and wherein greater than about 1.5% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons.

4440. The mixture of claim 4422, wherein the condensable hydrocarbons comprises oxygenated hydrocarbons, and wherein greater than about 25% by weight of the condensable component comprises oxygenated hydrocarbons.

4441. The mixture of claim 4422, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise H₂, and wherein greater than about 5% by weight of the non-condensable hydrocarbons comprises H₂.

4442. The mixture of claim 4422, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise H₂, and wherein greater than about 15% by weight of the non-condensable hydrocarbons comprises H₂.

4443. The mixture of claim 4422, further comprising non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprises hydrocarbons having carbon numbers of less than 5, and wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 0.3.

4444. A mixture produced from a portion of a hydrocarbon containing formation, comprising:

non-condensable hydrocarbons comprising hydrocarbons having carbon numbers of less than about 5, wherein a weight ratio of the hydrocarbons having carbon number from 2 through 4, to methane, in the mixture is greater than approximately 1;

wherein the non-condensable hydrocarbons further comprise H₂, wherein greater than about 15% by weight of the non-condensable hydrocarbons comprises H₂; and

condensable hydrocarbons, comprising;

oxygenated hydrocarbons, wherein greater than about 1.5% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons;

olefins, wherein less than about 10% by weight of the condensable hydrocarbons comprises olefins; and

aromatic compounds, wherein greater than about 20% by weight of the condensable hydrocarbons comprises aromatic compounds.

4445. The mixture of claim 4444, wherein the non-condensable hydrocarbons further comprise ethene and ethane, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

4446. The mixture of claim 4444, wherein the condensable hydrocarbons further comprise nitrogen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

4447. The mixture of claim 4444, wherein the condensable hydrocarbons further comprise oxygen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

4448. The mixture of claim 4444, wherein the condensable hydrocarbons further comprise sulfur containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4449. The mixture of claim 4444, wherein the condensable hydrocarbons further comprise oxygen containing compounds, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4450. The mixture of claim 4444, wherein the condensable hydrocarbons comprise multi-ring aromatics, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4451. The mixture of claim 4444, wherein the condensable hydrocarbons comprise asphaltenes, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

4452. The mixture of claim 4444, wherein the condensable hydrocarbons comprise cycloalkanes, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

4453. The mixture of claim 4444, wherein the non-condensable hydrocarbons further comprises hydrogen, and wherein greater than about 10% by volume and less than about 80% by volume of the non-condensable hydrocarbons comprises hydrogen.

4454. The mixture of claim 4444, further comprising ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4455. The mixture of claim 4444, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.

4456. The mixture of claim 4444, wherein the condensable hydrocarbons further comprise hydrocarbons having a carbon number of greater than approximately 25, wherein less than about 15% by weight of the hydrocarbons have a carbon number greater than approximately 25.

4457. The mixture of claim 4444, wherein about 0.1% to about 5% by weight of the condensable hydrocarbons comprises olefins.

4458. The mixture of claim 4444, wherein about 0.1% to about 2% by weight of the condensable hydrocarbons comprises olefins.

4459. The mixture of claim 4444, wherein greater than about 25% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons.

4460. The mixture of claim 4444, wherein the mixture comprises hydrocarbons having greater than about 2 carbon atoms, and wherein the weight ratio of hydrocarbons having greater than about 2 carbon atoms to methane is greater than about 0.3.

4461. A mixture produced from a portion of a hydrocarbon containing formation, comprising:

condensable hydrocarbons, wherein less than about 5% by weight of the condensable hydrocarbons comprises hydrocarbons having a carbon number greater than about 25;

wherein the condensable hydrocarbons further comprise;

oxygenated hydrocarbons, wherein greater than about 5% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons;

olefins, wherein less than about 10% by weight of the condensable hydrocarbons comprises olefins; and

aromatic compounds, wherein greater than about 30% by weight of the condensable hydrocarbons comprises aromatic compounds; and

non-condensable hydrocarbons comprising H₂, wherein greater than about 15% by weight of the non-condensable hydrocarbons comprises H₂.

4462. The mixture of claim 4461, wherein the non-condensable hydrocarbons further comprises hydrocarbons having carbon numbers of less than 5, and wherein a weight ratio of hydrocarbons having carbon numbers from 2 through 4, to methane, is greater than approximately 1.

4463. The mixture of claim 4461, wherein the non-condensable hydrocarbons comprise ethene and ethane, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

4464. The mixture of claim 4461, wherein the condensable hydrocarbons further comprise nitrogen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

4465. The mixture of claim 4461, wherein the condensable hydrocarbons further comprise oxygen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

4466. The mixture of claim 4461, wherein the condensable hydrocarbons further comprise sulfur containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4467. The mixture of claim 4461, wherein the condensable hydrocarbons further comprise oxygen containing compounds, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4468. The mixture of claim 4461, wherein the condensable hydrocarbons further comprise multi-ring aromatics, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4469. The mixture of claim 4461, wherein the condensable hydrocarbons further comprise asphaltenes, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

4470. The mixture of claim 4461, wherein the condensable hydrocarbons comprise cycloalkanes, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

4471. The mixture of claim 4461, wherein greater than about 10% by volume and less than about 80% by volume of the non-condensable hydrocarbons is hydrogen.

4472. The mixture of claim 4461, further comprising ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4473. The mixture of claim 4461, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.

4474. The mixture of claim 4461, wherein about 0.1% to about 5% by weight of the condensable hydrocarbons comprises olefins.

4475. The mixture of claim 4461, wherein about 0.1% to about 2% by weight of the condensable hydrocarbons comprises olefins.

4476. The mixture of claim 4461, wherein the condensable hydrocarbons comprises oxygenated hydrocarbons, and wherein greater than about 15% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons.

4477. The mixture of claim 4461, wherein the mixture comprises hydrocarbons having greater than about 2 carbon atoms, and wherein the weight ratio of hydrocarbons having greater than about 2 carbon atoms to methane is greater than about 0.3.

4478. A mixture of condensable hydrocarbons produced from a portion of a hydrocarbon containing formation, comprising:

olefins, wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons comprises olefins;

oxygenated hydrocarbons, wherein less than about 15% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons; and

asphaltenes, wherein less than about 0.1% by weight of the condensable hydrocarbons comprises asphaltenes.

4479. The mixture of claim 4478, wherein the condensable hydrocarbons further comprises hydrocarbons having a carbon number of greater than approximately 25, and wherein less than about 15 weight % of the hydrocarbons in the mixture have a carbon number greater than approximately 25.

4480. The mixture of claim 4478, wherein about 0.1% by weight to about 5% by weight of the condensable hydrocarbons comprises olefins.

4481. The mixture of claim 4478, wherein the condensable hydrocarbons further comprises non-condensable hydrocarbons, wherein the non-condensable hydrocarbons comprise ethene and ethane, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

4482. The mixture of claim 4478, wherein the condensable hydrocarbons further comprises nitrogen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

4483. The mixture of claim 4478, wherein the condensable hydrocarbons further comprises oxygen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

4484. The mixture of claim 4478, wherein the condensable hydrocarbons further comprises sulfur containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4485. The mixture of claim 4478, wherein the condensable hydrocarbons further comprises oxygen containing compounds, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4486. The mixture of claim 4478, wherein the condensable hydrocarbons further comprises aromatic compounds, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

4487. The mixture of claim 4478, wherein the condensable hydrocarbons further comprises multi-ring aromatics, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4488. The mixture of claim 4478, wherein the condensable hydrocarbons further comprises cycloalkanes, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

4489. The mixture of claim 4478, wherein the condensable hydrocarbons comprises non-condensable hydrocarbons, and wherein the non-condensable hydrocarbons comprise hydrogen, and wherein the hydrogen is greater than about 10% by volume of the non-condensable hydrocarbons and wherein the hydrogen is less than about 80% by volume of the non-condensable hydrocarbons.

4490. The mixture of claim 4478, further comprising ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4491. The mixture of claim 4478, further comprising ammonia, and wherein the ammonia is used to produce fertilizer.

4492. The mixture of claim 4478, wherein about 0.1% by weight to about 2% by weight of the condensable hydrocarbons comprises olefins.

4493. A mixture of condensable hydrocarbons produced from a portion of a hydrocarbon containing formation, comprising:

olefins, wherein about 0.1% by weight to about 2% by weight of the condensable hydrocarbons comprises olefins;

multi-ring aromatics, wherein less than about 2% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings; and

oxygenated hydrocarbons, wherein greater than about 25% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons.

4494. The mixture of claim 4493, further comprising hydrocarbons having a carbon number of greater than approximately 25, wherein less than about 5 weight % of the hydrocarbons in the mixture have a carbon number greater than approximately 25.

4495. The mixture of claim 4493, wherein the condensable hydrocarbons further comprises nitrogen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

4496. The mixture of claim 4493, wherein the condensable hydrocarbons further comprises oxygen containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

4497. The mixture of claim 4493, wherein the condensable hydrocarbons further comprises sulfur containing compounds, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4498. The mixture of claim 4493, wherein the condensable hydrocarbons further comprises oxygen containing compounds, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4499. The mixture of claim 4493, wherein the condensable hydrocarbons further comprises aromatic compounds, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

4500. The mixture of claim 4493, wherein the condensable hydrocarbons further comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

4501. The mixture of claim 4493, wherein the condensable hydrocarbons further comprises cycloalkanes, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

4502. The mixture of claim 4493, further comprising ammonia, wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4503. The mixture of claim 4493, further comprising ammonia, wherein the ammonia is used to produce fertilizer.

4504. A mixture produced from a portion of a hydrocarbon containing formation, comprising:

non-condensable hydrocarbons and H₂, wherein greater than about 10% by volume of the non-condensable hydrocarbons and H₂ comprises H₂;

ammonia and water, wherein greater than about 0.5% by weight of the mixture comprises ammonia; and

condensable hydrocarbons.

4505. The mixture of claim 4504, wherein the non-condensable hydrocarbons further comprise hydrocarbons having carbon numbers of less than 5, and wherein a weight ratio of the hydrocarbons having carbon numbers from 2 through 4 to methane, in the mixture is greater than approximately 1.

4506. The mixture of claim 4504, wherein greater than about 0.1% by weight of the condensable hydrocarbons are olefins, and wherein less than about 15% by weight of the condensable hydrocarbons are olefins.

4507. The mixture of claim 4504, wherein the non-condensable hydrocarbons further comprise ethene and ethane, wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is greater than about 0.001, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons is less than about 0.15.

4508. The mixture of claim 4504, wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

4509. The mixture of claim 4504, wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

4510. The mixture of claim 4504, wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4511. The mixture of claim 4504, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4512. The mixture of claim 4504, wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

4513. The mixture of claim 4504, wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4514. The mixture of claim 4504, wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.

4515. The mixture of claim 4504, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

4516. The mixture of claim 4504, wherein the H₂ is less than about 80% by volume of the non-condensable hydrocarbons and H₂.

4517. The mixture of claim 4504, wherein the condensable hydrocarbons further comprise sulfur containing compounds.

4518. The mixture of claim 4504, wherein the ammonia is used to produce fertilizer.

4519. The mixture of claim 4504, wherein less than about 5% of the condensable hydrocarbons have carbon numbers greater than 25.

4520. The mixture of claim 4504, wherein the condensable hydrocarbons comprise olefins, wherein greater than about about 0.001% by weight of the condensable hydrocarbons comprise olefins, and wherein less than about 15% by weight of the condensable hydrocarbons comprise olefins.

4521. The mixture of claim 4504, wherein the condensable hydrocarbons comprise olefins, wherein greater than about about 0.001% by weight of the condensable hydrocarbons comprise olefins, and wherein less than about 10% by weight of the condensable hydrocarbons comprise olefins.

4522. The mixture of claim 4504, wherein the condensable hydrocarbons comprise oxygenated hydrocarbons, and wherein greater than about 1.5% by weight of the condensable hydrocarbons comprises oxygenated hydrocarbons.

4523. The mixture of claim 4504, wherein the condensable hydrocarbons further comprise nitrogen containing compounds.

4524. A method of treating a hydrocarbon containing formation in situ comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

4525. The method of claim 4524, wherein three or more of the heaters are located in the formation in a plurality of the units, and wherein the plurality of units are repeated over an area of the formation to form a repetitive pattern of units.

4526. The method of claim 4524, wherein three or more of the heaters are located in the formation in a plurality of the units, wherein the plurality of units are repeated over an area of the formation to form a repetitive pattern of units, and wherein a ratio of heaters in the repetitive pattern of units to production wells in the repetitive pattern is greater than approximately 5.

4527. The method of claim 4524, wherein three or more of the heaters are located in the formation in a plurality of the units, wherein the plurality of units are repeated over an area of the formation to form a repetitive pattern of units, wherein three or more production wells are located within an area defined by the plurality of units, wherein the three or more production wells are located in the formation in a unit of production wells, and wherein the unit of production wells comprises a triangular pattern.

4528. The method of claim 4524, wherein three or more of the heaters are located in the formation in a plurality of the units, wherein the plurality of units are repeated over an area of the formation to form a repetitive pattern of units, wherein three or more injection wells are located within an area defined by the plurality of units, wherein the three or more injection wells are located in the formation in a unit of injection wells, and wherein the unit of injection wells comprises a triangular pattern.

4529. The method of claim 4524, wherein three or more of the heaters are located in the formation in a plurality of the units, wherein the plurality of units are repeated over an area of the formation to form a repetitive pattern of units, wherein three or more production wells and three or more injection wells are located within an area defined by the plurality of units, wherein the three or more production wells are located in the formation in a unit of production wells, wherein the unit of production wells comprises a first triangular pattern, wherein the three or more injection wells are located in the formation in a unit of injection wells, wherein the unit of injection wells comprises a second triangular pattern, and wherein the first triangular pattern is substantially different than the second triangular pattern.

4530. The method of claim 4524, wherein three or more of the heaters are located in the formation in a plurality of the units, wherein the plurality of units are repeated over an area of the formation to form a repetitive pattern of units, wherein three or more monitoring wells are located within an area defined by the plurality of units, wherein the three or more monitoring wells are located in the formation in a unit of monitoring wells, and wherein the unit of monitoring wells comprises a triangular pattern.

4531. The method of claim 4524, wherein a production well is located in an area defined by the unit of heaters.

4532. The method of claim 4524, wherein three or more of the heaters are located in the formation in a first unit and a second unit, wherein the first unit is adjacent to the second unit, and wherein the first unit is inverted with respect to the second unit.

4533. The method of claim 4524, wherein a distance between each of the heaters in the unit of heaters varies by less than about 20%.

4534. The method of claim 4524, wherein a distance between each of the heaters in the unit of heaters is approximately equal.

4535. The method of claim 4524, wherein providing heat from three or more heaters comprises substantially uniformly providing heat to at least the portion of the formation.

4536. The method of claim 4524, wherein the heated portion comprises a substantially uniform temperature distribution.

4537. The method of claim 4524, wherein the heated portion comprises a substantially uniform temperature distribution, and wherein a difference between a highest temperature in the heated portion and a lowest temperature in the heated portion comprises less than about 200°

C.

4538. The method of claim 4524, wherein a temperature at an outer lateral boundary of the triangular pattern and a temperature at a center of the triangular pattern are approximately equal.

4539. The method of claim 4524, wherein a temperature at an outer lateral boundary of the triangular pattern and a temperature at a center of the triangular pattern increase substantially linearly after an initial period of time, and wherein the initial period of time comprises less than approximately 3 months.

4540. The method of claim 4524, wherein a time required to increase an average temperature of the heated portion to a selected temperature with the triangular pattern of heaters is substantially less than a time required to increase the average temperature of the heated portion to the selected temperature with a hexagonal pattern of heaters, and wherein a space between each of the heaters in the triangular pattern is approximately equal to a space between each of the heaters in the hexagonal pattern.

4541. The method of claim 4524, wherein a time required to increase a temperature at a coldest point within the heated portion to a selected temperature with the triangular pattern of heaters is substantially less than a time required to increase a temperature at the coldest point within the heated portion to the selected temperature with a hexagonal pattern of heaters, and wherein a space between each of the heaters in the triangular pattern is approximately equal to a space between each of the heaters in the hexagonal pattern.

4542. The method of claim 4524, wherein a time required to increase a temperature at a coldest point within the heated portion to a selected temperature with the triangular pattern of heaters is substantially less than a time required to increase a temperature at the coldest point within the heated portion to the selected temperature with a hexagonal pattern of heaters, and wherein a number of heaters per unit area in the triangular pattern is equal to the number of heaters per unit are in the hexagonal pattern of heaters.

4543. The method of claim 4524, wherein a time required to increase a temperature at a coldest point within the heated portion to a selected temperature with the triangular pattern of heaters is substantially equal to a time required to increase a temperature at the coldest point within the heated portion to the selected temperature with a hexagonal pattern of heaters, and wherein a space between each of the heaters in the triangular pattern is approximately 5 m greater than a space between each of the heaters in the hexagonal pattern.

4544. The method of claim 4524, wherein providing heat from three or more heaters to at least the portion of formation comprises:

heating a selected volume (V) of the hydrocarbon containing formation from three or more of the heaters, wherein the formation has an average heat capacity (C_v), and wherein heat from three or more of the heaters pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

4545. The method of claim 4524, wherein three or more of the heaters comprise electrical heaters.

4546. The method of claim 4524, wherein three or more of the heaters comprise surface burners.

4547. The method of claim 4524, wherein three or more of the heaters comprise flameless distributed combustors.

4548. The method of claim 4524, wherein three or more of the heaters comprise natural distributed combustors.

4549. The method of claim 4524, further comprising:

allowing the heat to transfer from three or more of the heaters to a selected section of the formation such that heat from three or more of the heaters pyrolyzes at least some hydrocarbons within the selected section of the formation; and

producing a mixture of fluids from the formation.

4550. The method of claim 4549, further comprising controlling a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

4551. The method of claim 4549, further comprising controlling the heat such that an average heating rate of the selected section is less than about 1.0°

C. per day during pyrolysis.

4552. The method of claim 4549, wherein allowing the heat to transfer from three or more of the heaters to the selected section comprises transferring heat substantially by conduction.

4553. The method of claim 4549, wherein providing heat from three or more of the heaters to at least the portion of the formation comprises heating the selected section such that a thermal conductivity of at least a portion of the selected section is greater than about 0.5 W/m °

C.

4554. The method of claim 4549, wherein the produced mixture comprises an API gravity of at least 25°

.

4555. The method of claim 4549, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins.

4556. The method of claim 4549, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0.001 to about 0.15.

4557. The method of claim 4549, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen.

4558. The method of claim 4549, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen.

4559. The method of claim 4549, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.

4560. The method of claim 4549, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.

4561. The method of claim 4549, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.

4562. The method of claim 4549, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings.

4563. The method of claim 4549, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.1% by weight of the condensable hydrocarbons are asphaltenes.

4564. The method of claim 4549, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.

4565. The method of claim 4549, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises hydrogen, wherein the hydrogen is greater than about 10% by volume of the non-condensable component, and wherein the hydrogen is less than about 80% by volume of the non-condensable component.

4566. The method of claim 4549, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.

4567. The method of claim 4549, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

4568. The method of claim 4549, further comprising controlling formation conditions to produce a mixture of hydrocarbon fluids and H₂, wherein a partial pressure of H₂ within the mixture is greater than about 2.0 bars absolute.

4569. The method of claim 4549, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

4570. The method of claim 4549, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

4571. The method of claim 4549, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

4572. The method of claim 4549, further comprising:

producing hydrogen from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

4573. The method of claim 4549, wherein allowing the heat to transfer from three or more of the heaters to the selected section of the formation comprises increasing a permeability of a majority of the selected section to greater than about 100 millidarcy.

4574. The method of claim 4549, wherein allowing the heat to transfer from three or more of the heaters to the selected section of the formation comprises substantially uniformly increasing a permeability of a majority of the selected section.

4575. The method of claim 4549, further comprising controlling the heat from three or more heaters to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.

4576. The method of claim 4549, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.

4577. The method of claim 4576, wherein at least about 20 heaters are disposed in the formation for each production well.

4578. The method of claim 4549, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

4579. The method of claim 4549, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

4580. A method for in situ production of synthesis gas from a hydrocarbon containing formation, comprising:

heating a section of the formation to a temperature sufficient to allow synthesis gas generation, wherein a permeability of the section is substantially uniform and greater than a permeability of an unheated section of the formation when the temperature sufficient to allow synthesis gas generation within the formation is achieved;

providing a synthesis gas generating fluid to the section to generate synthesis gas; and

removing synthesis gas from the formation.

4581. The method of claim 4580, wherein the permeability of the section is greater than about 100 millidarcy when the temperature sufficient to allow synthesis gas generation within the formation is achieved.

4582. The method of claim 4580, wherein the temperature sufficient to allow synthesis gas generation ranges from approximately 400°

C. to approximately 1200°

C.

4583. The method of claim 4580, further comprising heating the section when providing the synthesis gas generating fluid to inhibit temperature decrease in the section due to synthesis gas generation.

4584. The method of claim 4580, wherein heating the section comprises convecting an oxidizing fluid into a portion of the section, wherein the temperature within the section is above a temperature sufficient to support oxidation of carbon within the section with the oxidizing fluid, and reacting the oxidizing fluid with carbon in the section to generate heat within the section.

4585. The method of claim 4584, wherein the oxidizing fluid comprises air.

4586. The method of claim 4585, wherein an amount of the oxidizing fluid convected into the section is configured to inhibit formation of oxides of nitrogen by maintaining a reaction temperature below a temperature sufficient to produce oxides of nitrogen compounds.

4587. The method of claim 4580, wherein heating the section comprises diffusing an oxidizing fluid to reaction zones adjacent to wellbores within the formation, oxidizing carbon within the reaction zone to generate heat, and transferring the heat to the section.

4588. The method of claim 4580, wherein heating the section comprises heating the section by transfer of heat from one or more of electrical heaters.

4589. The method of claim 4580, wherein heating the section to a temperature sufficient to allow synthesis gas generation and providing a synthesis gas generating fluid to the section comprises introducing steam into the section to heat the formation and to generate synthesis gas.

4590. The method of claim 4580, further comprising controlling the heating of the section and provision of the synthesis gas generating fluid to maintain a temperature within the section above the temperature sufficient to generate synthesis gas.

4591. The method of claim 4580, further comprising:

monitoring a composition of the produced synthesis gas; and

controlling heating of the section and provision of the synthesis gas generating fluid to maintain the composition of the produced synthesis gas within a selected range.

4592. The method of claim 4591, wherein the selected range comprises a ratio of H₂ to CO of about 2:

1.

4593. The method of claim 4580, wherein the synthesis gas generating fluid comprises liquid water.

4594. The method of claim 4580, wherein the synthesis gas generating fluid comprises steam.

4595. The method of claim 4580, wherein the synthesis gas generating fluid comprises water and carbon dioxide, and wherein the carbon dioxide inhibits production of carbon dioxide from hydrocarbon containing material within the section.

4596. The method of claim 4595, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.

4597. The method of claim 4580, wherein the synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.

4598. The method of claim 4597, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.

4599. The method of claim 4580, wherein providing the synthesis gas generating fluid to the section comprises raising a water table of the formation to allow water to flow into the section.

4600. The method of claim 4580, wherein the synthesis gas is removed from a producer well equipped with a heating source, and wherein a portion of the heating source adjacent to a synthesis gas producing zone operates at a substantially constant temperature to promote production of the synthesis gas wherein the synthesis gas has a selected composition.

4601. The method of claim 4600, wherein the substantially constant temperature is about 700°

C., and wherein the selected composition has a H₂ to CO ratio of about 2;

1.

4602. The method of claim 4580, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons are subjected to a reaction within the section to increase a H₂ concentration of the generated synthesis gas.

4603. The method of claim 4580, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within the section to increase an energy content of the synthesis gas removed from the formation.

4604. The method of claim 4580, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate electricity.

4605. The method of claim 4580, further comprising generating electricity from the synthesis gas using a fuel cell.

4606. The method of claim 4580, further comprising generating electricity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent section of the formation.

4607. The method of claim 4580, further comprising using a portion of the synthesis gas as a combustion fuel to heat the formation.

4608. The method of claim 4580, further comprising converting at least a portion of the produced synthesis gas to condensable hydrocarbons using a Fischer-Tropsch synthesis process.

4609. The method of claim 4580, further comprising converting at least a portion of the produced synthesis gas to methanol.

4610. The method of claim 4580, further comprising converting at least a portion of the produced synthesis gas to gasoline.

4611. The method of claim 4580, further comprising converting at least a portion of the synthesis gas to methane using a catalytic methanation process.

4612. The method of claim 4580, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

4613. The method of claim 4580, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

4614. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to substantially uniformly increase a permeability of the portion and to increase a temperature of the portion to a temperatrue sufficient to allow synthesis gas generation;

providing a synthesis gas generating fluid to at least the portion of the selected section, wherein the synthesis gas generating fluid comprises carbon dioxide;

obtaining a portion of the carbon dioxide of the synthesis gas generating fluid from the formation; and

producing synthesis gas from the formation.

4615. The method of claim 4614, wherein the temperature sufficient to allow synthesis gas generation is within a range from about 400°

C. to about 1200°

C.

4616. The method of claim 4614, further comprising using a second portion of the separated carbon dioxide as a flooding agent to produce hydrocarbon bed methane from a hydrocarbon containing fromation.

4617. The method of claim 4616, wherein the hydrocarbon containing formation is a deep hydrocarbon containing formation over 760 m below ground surface.

4618. The method of claim 4616, wherein the hydrocarbon containing formation adsorbs some of the carbon dioxide to sequester the carbon dioxide.

4619. The method of claim 4614, further comprising using a second portion of the separated carbon dioxide as a flooding agent for enhanced oil recovery.

4620. The method of claim 4614, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons undergo a reaction within the selected section to increase a H₂ concentration within the produced synthesis gas.

4621. The method of claim 4614, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within the selected section to increase an energy content of the produced synthesis gas.

4622. The method of claim 4614, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate electricity.

4623. The method of claim 4614, further comprising generating electricity from the synthesis gas using a fuel cell.

4624. The method of claim 4614, further comprising generating electricity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent portion of the formation.

4625. The method of claim 4614, further comprising using a portion of the synthesis gas as a combustion fuel for heating the formation.

4626. The method of claim 4614, further comprising converting at least a portion of the produced synthesis gas to condensable hydrocarbons using a Fischer-Tropsch synthesis process.

4627. The method of claim 4614, further comprising converting at least a portion of the produced synthesis gas to methanol.

4628. The method of claim 4614, further comprising converting at least a portion of the produced synthesis gas to gasoline.

4629. The method of claim 4614, further comprising converting at least a portion of the synthesis gas to methane using a catalytic methanation process.

4630. The method of claim 4614, wherein a temperature of the one or more heaters is maintained at a temperature of less than approximately 700°

C. to produce a synthesis gas having a ratio of H₂ to carbon monoxide of greater than about 2.

4631. The method of claim 4614, wherein a temperature of the one or more heaters is maintained at a temperature of greater than approximately 700°

C. to produce a synthesis gas having a ratio of H₂ to carbon monoxide of less than about 2.

4632. The method of claim 4614, wherein a temperature of the one or more heaters is maintained at a temperature of approximately 700°

C. to produce a synthesis gas having a ratio of H₂ to carbon monoxide of approximately 2.

4633. The method of claim 4614, wherein a heater of the one or more of heaters comprises an electrical heater.

4634. The method of claim 4614, wherein a heater of the one or more heaters comprises a natural distributed heater.

4635. The method of claim 4614, wherein a heater of the one or more heaters comprises a flameless distributed combustor (FDC) heater, and wherein fluids are produced from the wellbore of the FDC heater through a conduit positioned within the wellbore.

4636. The method of claim 4614, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

4637. The method of claim 4614, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

4638. A method of in situ synthesis gas production, comprising:

providing heat from one or more flameless distributed combustor heaters to at least a first portion of a hydrocarbon containing formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat from the one or more heaters substantially uniformly increases a permeability of the selected section, and to raise a temperature of the selected section to a temperature sufficient to generate synthesis gas;

introducing a synthesis gas producing fluid into the selected section to generate synthesis gas; and

removing synthesis gas from the formation.

4639. The method of claim 4638, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters substantially uniformly increases a permeability of the selected section, and raises a temperature of the selected section to a temperature sufficient to generate synthesis gas.

4640. The method of claim 4638, further comprising producing the synthesis gas from the formation under pressure, and generating electricity from the produced synthesis gas by passing the produced synthesis gas through a turbine.

4641. The method of claim 4638, further comprising producing pyrolyzation products from the formation when raising the temperature of the selected section to the temperature sufficient to generate synthesis gas.

4642. The method of claim 4638, further comprising separating a portion of carbon dioxide from the removed synthesis gas, and storing the carbon dioxide within a spent portion of the formation.

4643. The method of claim 4638, further comprising storing carbon dioxide within a spent portion of the formation, wherein an amount of carbon dioxide stored within the spent portion of the formation is equal to or greater than an amount of carbon dioxide within the removed synthesis gas.

4644. The method of claim 4638, further comprising separating a portion of H₂ from the removed synthesis gas;

and using a portion of the separated H₂ as fuel for the one or more heaters.

4645. The method of claim 4638, further comprising using a portion of exhaust products from one or more heaters as a portion of the synthesis gas producing fluid.

4646. The method of claim 4638, further comprising using a portion of the removed synthesis gas with a fuel cell to generate electricity.

4647. The method of claim 4646, wherein the fuel cell produces steam, and wherein a portion of the steam is used as a portion of the synthesis gas producing fluid.

4648. The method of claim 4646, wherein the fuel cell produces carbon dioxide, and wherein a portion of the carbon dioxide is introduced into the formation to react with carbon within the formation to produce carbon monoxide.

4649. The method of claim 4646, wherein the fuel cell produces carbon dioxide, and further comprising storing an amount of carbon dioxide within a spent portion of the formation equal or greater to an amount of the carbon dioxide produced by the fuel cell.

4650. The method of claim 4638, further comprising using a portion of the removed synthesis gas as a feed product for formation of hydrocarbons.

4651. The method of claim 4638, wherein the synthesis gas producing fluid comprises hydrocarbons having carbon numbers less than 5, and wherein the hydrocarbons crack within the formation to increase an amount of H₂ within the generated synthesis gas.

4652. The method of claim 4638, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

4653. The method of claim 4638, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

4654. A method of treating a hydrocarbon containing formation, comprising:

heating a portion of the formation with one or more electrical heaters to a temperature sufficient to pyrolyze hydrocarbons within the portion;

producing pyrolyzation fluid from the formation;

separating a fuel cell feed stream from the pyrolyzation fluid; and

directing the fuel cell feed stream to a fuel cell to produce electricity.

4655. The method of claim 4654, wherein the fuel cell is a molten carbonate fuel cell.

4656. The method of claim 4654, wherein the fuel cell is a solid oxide fuel cell.

4657. The method of claim 4654, further comprising using a portion of the produced electricity to power the electrical heaters.

4658. The method of claim 4654, wherein heating the portion of the formation is performed at a rate sufficient to increase a permeability of the portion and to produce a substantially uniform permeability within the portion.

4659. The method of claim 4654, wherein the fuel cell feed stream comprises H₂ and hydrocarbons having a carbon number of less than 5.

4660. The method of claim 4654, wherein the fuel cell feed stream comprises H₂ and hydrocarbons having a carbon number of less than 3.

4661. The method of claim 4654, further comprising hydrogenating the pyrolyzation fluid with a portion of H₂ from the pyrolyzation fluid.

4662. The method of claim 4654, wherein the hydrogenation is done in situ by directing the H₂ into the formation.

4663. The method of claim 4654, wherein the hydrogenation is done in a surface unit.

4664. The method of claim 4654, further comprising directing hydrocarbon fluid having carbon numbers less than 5 adjacent to at least one of the electrical heaters, cracking a portion of the hydrocarbons to produce H₂, and producing a portion of the hydrogen from the formation.

4665. The method of claim 4664, further comprising directing an oxidizing fluid adjacent to at least the one of the electrical heaters, oxidizing coke deposited on or near the at least one of the electrical heaters with the oxidizing fluid.

4666. The method of claim 4654, further comprising storing CO₂ from the fuel cell within the formation.

4667. The method of claim 4666, wherein the CO₂ is adsorbed to carbon material within a spent portion of the formation.

4668. The method of claim 4654, further comprising cooling the portion to form a spent portion of formation.

4669. The method of claim 4668, wherein cooling the portion comprises introducing water into the portion to produce steam, and removing steam from the formation.

4670. The method of claim 4669, further comprising using a portion of the removed steam to heat a second portion of the formation.

4671. The method of claim 4669, further comprising using a portion of the removed steam as a synthesis gas producing fluid in a second portion of the formation.

4672. The method of claim 4654, further comprising:

heating the portion to a temperature sufficient to support generation of synthesis gas after production of the pyrolyzation fluids;

introducing a synthesis gas producing fluid into the portion to generate synthesis gas; and

removing a portion of the synthesis gas from the formation.

4673. The method of claim 4672, further comprising producing the synthesis gas from the formation under pressure, and generating electricity from the produced synthesis gas by passing the produced synthesis gas through a turbine.

4674. The method of claim 4672, further comprising using a first portion of the removed synthesis gas as fuel cell feed.

4675. The method of claim 4672, further comprising producing steam from operation of the fuel cell, and using the steam as part of the synthesis gas producing fluid.

4676. The method of claim 4672, further comprising using carbon dioxide from the fuel cell as a part of the synthesis gas producing fluid.

4677. The method of claim 4672, further comprising using a portion of the synthesis gas to produce hydrocarbon product.

4678. The method of claim 4672, further comprising cooling the portion to form a spent portion of formation.

4679. The method of claim 4678, wherein cooling the portion comprises introducing water into the portion to produce steam, and removing steam from the formation.

4680. The method of claim 4679, further comprising using a portion of the removed steam to heat a second portion of the formation.

4681. The method of claim 4679, further comprising using a portion of the removed steam as a synthesis gas producing fluid in a second portion of the formation.

4682. The method of claim 4654, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

4683. The method of claim 4654, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

4684. A method for in situ production of synthesis gas from a hydrocarbon containing formation, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat from the one or more heaters pyrolyzes at least some of the hydrocarbons within the selected section of the formation;

producing pyrolysis products from the formation;

heating at least a portion of the selected section to a temperature sufficient to generate synthesis gas;

providing a synthesis gas generating fluid to at least the portion of the selected section to generate synthesis gas; and

producing a portion of the synthesis gas from the formation.

4685. The method of claim 4684, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

4686. The method of claim 4684, further comprising allowing the heat to transfer from the one or more heaters to the selected section to substantially uniformly increase a permeability of the selected section.

4687. The method of claim 4684, further comprising controlling heat transfer from the one or more heaters to produce a permeability within the selected section of greater than about 100 millidarcy.

4688. The method of claim 4684, further comprising heating at least the portion of the selected section when providing the synthesis gas generating fluid to inhibit temperature decrease within the selected section during synthesis gas generation.

4689. The method of claim 4684, wherein the temperature sufficient to allow synthesis gas generation is within a range from approximately 400°

C. to approximately 1200°

C.

4690. The method of claim 4684, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises:

heating zones adjacent to wellbores of one or more heaters with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material within the zones with an oxidizing fluid;

introducing the oxidizing fluid to the zones substantially by diffusion;

allowing the oxidizing fluid to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and

transferring heat from the zones to the selected section.

4691. The method of claim 4684, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises:

introducing an oxidizing fluid into the formation through a wellbore;

transporting the oxidizing fluid substantially by convection into the portion of the selected section, wherein the portion of the selected section is at a temperature sufficient to support an oxidation reaction with the oxidizing fluid; and

reacting the oxidizing fluid within the portion of the selected section to generate heat and raise the temperature of the portion.

4692. The method of claim 4684, wherein the one or more heaters comprise one or more electrical heaters disposed in the formation.

4693. The method of claim 4684, wherein the one or more heaters comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.

4694. The method of claim 4684, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation and providing a synthesis gas generating fluid to at least the portion of the selected section comprises introducing steam into the portion.

4695. The method of claim 4684, further comprising controlling the heating of at least the portion of selected section and provision of the synthesis gas generating fluid to maintain a temperature within at least the portion of the selected section above the temperature sufficient to generate synthesis gas.

4696. The method of claim 4684, further comprising:

monitoring a composition of the produced synthesis gas; and

controlling heating of at least the portion of selected section and provision of the synthesis gas generating fluid to maintain the composition of the produced synthesis gas within a desired range.

4697. The method of claim 4684, wherein the synthesis gas generating fluid comprises liquid water.

4698. The method of claim 4684, wherein the synthesis gas generating fluid comprises steam.

4699. The method of claim 4684, wherein the synthesis gas generating fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.

4700. The method of claim 4699, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.

4701. The method of claim 4684, wherein the synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.

4702. The method of claim 4701, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.

4703. The method of claim 4684, wherein providing the synthesis gas generating fluid to at least the portion of the selected section comprises raising a water table of the formation to allow water to flow into the at least the portion of the selected section.

4704. The method of claim 4684, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons are subjected to a reaction within at least the portion of the selected section to increase a H₂ concentration within the produced synthesis gas.

4705. The method of claim 4684, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within at least the portion of the selected section to increase an energy content of the produced synthesis gas.

4706. The method of claim 4684, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate electricity.

4707. The method of claim 4684, further comprising generating electricity from the synthesis gas using a fuel cell.

4708. The method of claim 4684, further comprising generating electricity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent section of the formation.

4709. The method of claim 4684, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heaters.

4710. The method of claim 4684, further comprising converting at least a portion of the produced synthesis gas to condensable hydrocarbons using a Fischer-Tropsch synthesis process.

4711. The method of claim 4684, further comprising converting at least a portion of the produced synthesis gas to methanol.

4712. The method of claim 4684, further comprising converting at least a portion of the produced synthesis gas to gasoline.

4713. The method of claim 4684, further comprising converting at least a portion of the synthesis gas to methane using a catalytic methanation process.

4714. The method of claim 4684, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

4715. The method of claim 4684, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

4716. A method for in situ production of synthesis gas from a hydrocarbon containing formation, comprising:

heating a first portion of the formation to pyrolyze some hydrocarbons within the first portion;

allowing the heat to transfer from one or more heaters to a selected section of the formation,

pyrolyzing hydrocarbons within the selected section;

producing fluid from the first portion, wherein the fluid comprises an aqueous fluid and a hydrocarbon fluid;

heating a second portion of the formation to a temperature sufficient to allow synthesis gas generation;

introducing at least a portion of the aqueous fluid to the second section after the section reaches the temperature sufficient to allow synthesis gas generation; and

producing synthesis gas from the formation.

4717. The method of claim 4716, wherein the temperature sufficient to allow synthesis gas generation ranges from approximately 400°

C. to approximately 1200°

C.

4718. The method of claim 4716, further comprising separating ammonia within the aqueous phase from the aqueous phase prior to introduction of at least the portion of the aqueous fluid to the second section.

4719. The method of claim 4716, wherein a permeability of the second portion of the formation is substantially uniform and greater than about 100 millidarcy when the temperature sufficient to allow synthesis gas generation is achieved.

4720. The method of claim 4716, further comprising heating the second portion of the formation during introduction of at least the portion of the aqueous fluid to the second section to inhibit temperature decrease in the second section due to synthesis gas generation.

4721. The method of claim 4716, wherein heating the second portion of the formation comprises convecting an oxidizing fluid into a portion of the second portion that is above a temperature sufficient to support oxidation of carbon within the portion with the oxidizing fluid, and reacting the oxidizing fluid with carbon in the portion to generate heat within the portion.

4722. The method of claim 4716, wherein heating the second portion of the formation comprises diffusing an oxidizing fluid to reaction zones adjacent to wellbores within the formation, oxidizing carbon within the reaction zones to generate heat, and transferring the heat to the second portion.

4723. The method of claim 4716, wherein heating the second portion of the formation comprises heating the second section by transfer of heat from one or more electrical heaters.

4724. The method of claim 4716, wherein heating the second portion of the formation comprises heating the second section with a flameless distributed combustor.

4725. The method of claim 4716, wherein heating the second portion of the formation comprises injecting steam into at least the portion of the formation.

4726. The method of claim 4716, wherein at least the portion of the aqueous fluid comprises a liquid phase.

4727. The method of claim 4716, wherein the aqueous fluid comprises a vapor phase.

4728. The method of claim 4716, further comprising adding carbon dioxide to at least the portion of aqueous fluid to inhibit production of carbon dioxide from carbon within the formation.

4729. The method of claim 4728, wherein a portion of the carbon dioxide comprises carbon dioxide removed from the formation.

4730. The method of claim 4716, further comprising adding hydrocarbons with carbon numbers less than 5 to at least the portion of the aqueous fluid to increase a H₂ concentration within the produced synthesis gas.

4731. The method of claim 4716, further comprising adding hydrocarbons with carbon numbers less than 5 to at least the portion of the aqueous fluid to increase a H₂ concentration within the produced synthesis gas, wherein the hydrocarbons are obtained from the produced fluid.

4732. The method of claim 4716, further comprising adding hydrocarbons with carbon numbers greater than 4 to at least the portion of the aqueous fluid to increase energy content of the produced synthesis gas.

4733. The method of claim 4716, further comprising adding hydrocarbons with carbon numbers greater than 4 to at least the portion of the aqueous fluid to increase energy content of the produced synthesis gas, wherein the hydrocarbons are obtained from the produced fluid.

4734. The method of claim 4716, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate electricity.

4735. The method of claim 4716, further comprising generating electricity from the synthesis gas using a fuel cell.

4736. The method of claim 4716, further comprising generating electricity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent portion of the formation.

4737. The method of claim 4716, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heaters.

4738. The method of claim 4716, further comprising converting at least a portion of the produced synthesis gas to condensable hydrocarbons using a Fischer-Tropsch synthesis process.

4739. The method of claim 4716, further comprising converting at least a portion of the produced synthesis gas to methanol.

4740. The method of claim 4716, further comprising converting at least a portion of the produced synthesis gas to gasoline.

4741. The method of claim 4716, further comprising converting at least a portion of the synthesis gas to methane using a catalytic methanation process.

4742. The method of claim 4716, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

4743. The method of claim 4716, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

4744. A method for in situ production of synthesis gas from a hydrocarbon containing formation, comprising:

heating a portion of the formation with one or more heaters to create increased and substantially uniform permeability within a portion of the formation and to raise a temperature within the portion to a temperature sufficient to allow synthesis gas generation;

providing a synthesis gas generating fluid into the portion through at least one injection wellbore to generate synthesis gas from hydrocarbons and the synthesis gas generating fluid; and

producing synthesis gas from at least one wellbore in which is positioned a heater of the one or more heaters.

4745. The method of claim 4744, wherein the temperature sufficient to allow synthesis gas generation is within a range from about 400°

C. to about 1200°

C.

4746. The method of claim 4744, wherein creating a substantially uniform permeability comprises heating the portion to a temperature within a range sufficient to pyrolyze hydrocarbons within the portion, raising the temperature within the portion at a rate of less than about 5°

C. per day during pyrolyzation and removing a portion of pyrolyzed fluid from the formation.

4747. The method of claim 4744, further comprising removing fluid from the formation through at least the one injection wellbore prior to heating the selected section to the temperature sufficient to allow synthesis gas generation.

4748. The method of claim 4744, wherein the injection wellbore comprises a wellbore of a heater in which is positioned a heater of the one or more heaters.

4749. The method of claim 4744, further comprising heating the selected portion during providing the synthesis gas generating fluid to inhibit temperature decrease in at least the portion of the selected section due to synthesis gas generation.

4750. The method of claim 4744, further comprising providing a portion of the heat needed to raise the temperature sufficient to allow synthesis gas generation by convecting an oxidizing fluid to hydrocarbons within the selected section to oxidize a portion of the hydrocarbons and generate heat.

4751. The method of claim 4744, further comprising controlling the heating of the selected section and provision of the synthesis gas generating fluid to maintain a temperature within the selected section above the temperature sufficient to generate synthesis gas.

4752. The method of claim 4744, further comprising:

monitoring a composition of the produced synthesis gas; and

controlling heating of the selected section and provision of the synthesis gas generating fluid to maintain the composition of the produced synthesis gas within a desired range.

4753. The method of claim 4744, wherein the synthesis gas generating fluid comprises liquid water.

4754. The method of claim 4744, wherein the synthesis gas generating fluid comprises steam.

4755. The method of claim 4744, wherein the synthesis gas generating fluid comprises steam to heat the selected section and to generate synthesis gas.

4756. The method of claim 4744, wherein the synthesis gas generating fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.

4757. The method of claim 4756, wherein a portion of the carbon dioxide comprises carbon dioxide removed from the formation.

4758. The method of claim 4744, wherein the synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.

4759. The method of claim 4758, wherein a portion of the carbon dioxide comprises carbon dioxide removed from the formation.

4760. The method of claim 4744, wherein providing the synthesis gas generating fluid to the selected section comprises raising a water table of the formation to allow water to enter the selected section.

4761. The method of claim 4744, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons undergo a reaction within the selected section to increase a H₂ concentration within the produced synthesis gas.

4762. The method of claim 4744, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within the selected section to increase an energy content of the produced synthesis gas.

4763. The method of claim 4744, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate electricity.

4764. The method of claim 4744, further comprising generating electricity from the synthesis gas using a fuel cell.

4765. The method of claim 4744, further comprising generating electricity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent portion of the formation.

4766. The method of claim 4744, further comprising using a portion of the synthesis gas as a combustion fuel for heating the formation.

4767. The method of claim 4744, further comprising converting at least a portion of the produced synthesis gas to condensable hydrocarbons using a Fischer-Tropsch synthesis process.

4768. The method of claim 4744, further comprising converting at least a portion of the produced synthesis gas to methanol.

4769. The method of claim 4744, further comprising converting at least a portion of the produced synthesis gas to gasoline.

4770. The method of claim 4744, further comprising converting at least a portion of the synthesis gas to methane using a catalytic methanation process.

4771. The method of claim 4744, wherein a temperature of at least the one heater wellbore is maintained at a temperature of less than approximately 700°

C. to produce a synthesis gas having a ratio of H₂ to carbon monoxide of greater than about 2.

4772. The method of claim 4744, wherein a temperature of at least the one heater wellbore is maintained at a temperature of greater than approximately 700°

C. to produce a synthesis gas having a ratio of H₂ to carbon monoxide of less than about 2.

4773. The method of claim 4744, wherein a temperature of at least the one heater wellbore is maintained at a temperature of approximately 700°

C. to produce a synthesis gas having a ratio of H₂ to carbon monoxide of approximately 2.

4774. The method of claim 4744, wherein a heater of the one or more heaters comprises an electrical heater.

4775. The method of claim 4744, wherein a heater of the one or more heaters comprises a natural distributed heater.

4776. The method of claim 4744, wherein a heater of the one or more heaters comprises a flameless distributed combustor (FDC) heater, and wherein fluids are produced from the wellbore of the FDC heater through a conduit positioned within the wellbore.

4777. The method of claim 4744, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

4778. The method of claim 4744, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

4779. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat from the one or more heaters pyrolyzes at least a portion of the hydrocarbon containing material within the selected section of the formation;

producing pyrolysis products from the formation;

heating a first portion of a formation with one or more heaters to a temperature sufficient to allow generation of synthesis gas;

providing a first synthesis gas generating fluid to the first portion to generate a first synthesis gas;

removing a portion of the first synthesis gas from the formation;

heating a second portion of a formation with one or more heaters to a temperature sufficient to allow generation of synthesis gas having a H₂ to CO ratio greater than a H₂ to CO ratio of the first synthesis gas;

providing a second synthesis gas generating component to the second portion to generate a second synthesis gas;

removing a portion of the second synthesis gas from the formation; and

blending a portion of the first synthesis gas with a portion of the second synthesis gas to produce a blended synthesis gas having a selected H₂ to CO ratio.

4780. The method of claim 4779, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

4781. The method of claim 4779, wherein the first synthesis gas generating fluid and second synthesis gas generating fluid comprise the same component.

4782. The method of claim 4779, further comprising controlling the temperature in the first portion to control a composition of the first synthesis gas.

4783. The method of claim 4779, further comprising controlling the temperature in the second portion to control a composition of the second synthesis gas.

4784. The method of claim 4779, wherein the selected ratio is controlled to be approximately 2:

1 H₂ to CO.

4785. The method of claim 4779, wherein the selected ratio is controlled to range from approximately 1.8:

1 to approximately 2.2;

1 H₂ to CO.

4786. The method of claim 4779, wherein the selected ratio is controlled to be approximately 3:

1 H₂ to CO.

4787. The method of claim 4779, wherein the selected ratio is controlled to range from approximately 2.8:

1 to approximately 3.2;

1 H₂ to CO.

4788. The method of claim 4779, further comprising providing at least a portion of the produced blended synthesis gas to a condensable hydrocarbon synthesis process to produce condensable hydrocarbons.

4789. The method of claim 4788, wherein the condensable hydrocarbon synthesis process comprises a Fischer-Tropsch process.

4790. The method of claim 4789, further comprising cracking at least a portion of the condensable hydrocarbons to form middle distillates.

4791. The method of claim 4779, further comprising providing at least a portion of the produced blended synthesis gas to a catalytic methanation process to produce methane.

4792. The method of claim 4779, further comprising providing at least a portion of the produced blended synthesis gas to a methanol-synthesis process to produce methanol.

4793. The method of claim 4779, further comprising providing at least a portion of the produced blended synthesis gas to a gasoline-synthesis process to produce gasoline.

4794. The method of claim 4779, wherein removing a portion of the second synthesis gas comprises withdrawing second synthesis gas through a production well, wherein a temperature of the production well adjacent to a second syntheses gas production zone is maintained at a substantially constant temperature configured to produce second synthesis gas having the H₂ to CO ratio greater the first synthesis gas.

4795. The method of claim 4779, wherein the first synthesis gas producing fluid comprises CO₂ and wherein the temperature of the first portion is at a temperature that will result in conversion of CO₂ and carbon from the first portion to CO to generate a CO rich first synthesis gas.

4796. The method of claim 4779, wherein the second synthesis gas producing fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons react within the formation to increase a H₂ concentration within the produced second synthesis gas.

4797. The method of claim 4779, wherein blending a portion of the first synthesis gas with a portion of the second synthesis gas comprises producing an intermediate mixture having a H₂ to CO mixture of less than the selected ratio, and subjecting the intermediate mixture to a shift reaction to reduce an amount of CO and increase an amount of H₂ to produce the selected ratio of H₂ to CO.

4798. The method of claim 4779, further comprising removing an excess of first synthesis gas from the first portion to have an excess of CO, subjecting the first synthesis gas to a shift reaction to reduce an amount of CO and increase an amount of H₂ before blending the first synthesis gas with the second synthesis gas.

4799. The method of claim 4779, further comprising removing the first synthesis gas from the formation under pressure, and passing removed first synthesis gas through a turbine to generate electricity.

4800. The method of claim 4779, further comprising removing the second synthesis gas from the formation under pressure, and passing removed second synthesis gas through a turbine to generate electricity.

4801. The method of claim 4779, further comprising generating electricity from the blended synthesis gas using a fuel cell.

4802. The method of claim 4779, further comprising generating electricity from the blended synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent portion of the formation.

4803. The method of claim 4779, further comprising using at least a portion of the blended synthesis gas as a combustion fuel for heating the formation.

4804. The method of claim 4779, further comprising allowing the heat to transfer from the one or more heaters to the selected section to substantially uniformly increase a permeability of the selected section.

4805. The method of claim 4779, further comprising controlling heat transfer from the one or more heaters to produce a permeability within the selected section of greater than about 100 millidarcy.

4806. The method of claim 4779, further comprising heating at least the portion of the selected section when providing the synthesis gas generating fluid to inhibit temperature decrease within the selected section during synthesis gas generation.

4807. The method of claim 4779, wherein the temperature sufficient to allow synthesis gas generation is within a range from approximately 400°

C. to approximately 1200°

C.

4808. The method of claim 4779, wherein heating the first a portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises:

heating zones adjacent to wellbores of one or more heaters with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material within the zones with an oxidizing fluid;

introducing the oxidizing fluid to the zones substantially by diffusion;

allowing the oxidizing fluid to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and

transferring heat from the zones to the selected section.

4809. The method of claim 4779, wherein heating the second portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises:

heating zones adjacent to wellbores of one or more heaters with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material within the zones with an oxidizing fluid;

introducing the oxidizing fluid to the zones substantially by diffusion;

allowing the oxidizing fluid to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and

transferring heat from the zones to the selected section.

4810. The method of claim 4779, wherein heating the first portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises:

introducing an oxidizing fluid into the formation through a wellbore;

transporting the oxidizing fluid substantially by convection into the first portion of the selected section, wherein the first portion of the selected section is at a temperature sufficient to support an oxidation reaction with the oxidizing fluid; and

reacting the oxidizing fluid within the first portion of the selected section to generate heat and raise the temperature of the first portion.

4811. The method of claim 4779, wherein heating the second portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises:

introducing an oxidizing fluid into the formation through a wellbore;

transporting the oxidizing fluid substantially by convection into the second portion of the selected section, wherein the second portion of the selected section is at a temperature sufficient to support an oxidation reaction with the oxidizing fluid; and

reacting the oxidizing fluid within the second portion of the selected section to generate heat and raise the temperature of the second portion.

4812. The method of claim 4779, wherein the one or more heaters comprise one or more electrical heaters disposed in the formation.

4813. The method of claim 4779, wherein the one or more heaters comprises one or more natural distributed combustors.

4814. The method of claim 4779, wherein the one or more heaters comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.

4815. The method of claim 4779, wherein heating the first portion of the selected section to a temperature sufficient to allow synthesis gas generation and providing a first synthesis gas generating fluid to the first portion of the selected section comprises introducing steam into the first portion.

4816. The method of claim 4779, wherein heating the second portion of the selected section to a temperature sufficient to allow synthesis gas generation and providing a second synthesis gas generating fluid to the second portion of the selected section comprises introducing steam into the second portion.

4817. The method of claim 4779, further comprising controlling the heating of the first portion of selected section and provision of the first synthesis gas generating fluid to maintain a temperature within the first portion of the selected section above the temperature sufficient to generate synthesis gas.

4818. The method of claim 4779, further comprising controlling the heating of the second portion of selected section and provision of the second synthesis gas generating fluid to maintain a temperature within the second portion of the selected section above the temperature sufficient to generate synthesis gas.

4819. The method of claim 4779, wherein the first synthesis gas generating fluid comprises liquid water.

4820. The method of claim 4779, wherein the second synthesis gas generating fluid comprises liquid water.

4821. The method of claim 4779, wherein the first synthesis gas generating fluid comprises steam.

4822. The method of claim 4779, wherein the second synthesis gas generating fluid comprises steam.

4823. The method of claim 4779, wherein the first synthesis gas generating fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.

4824. The method of claim 4823, wherein a portion of the carbon dioxide within the first synthesis gas generating fluid comprises carbon dioxide removed from the formation.

4825. The method of claim 4779, wherein the second synthesis gas generating fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.

4826. The method of claim 4825, wherein a portion of the carbon dioxide within the second synthesis gas generating fluid comprises carbon dioxide removed from the formation.

4827. The method of claim 4779, wherein the first synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.

4828. The method of claim 4827, wherein a portion of the carbon dioxide within the first synthesis gas generating fluid comprises carbon dioxide removed from the formation.

4829. The method of claim 4779, wherein the second synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.

4830. The method of claim 4829, wherein a portion of the carbon dioxide within the second synthesis gas generating fluid comprises carbon dioxide removed from the formation.

4831. The method of claim 4779, wherein providing the first synthesis gas generating fluid to the first portion of the selected section comprises raising a water table of the formation to allow water to flow into the first portion of the selected section.

4832. The method of claim 4779, wherein providing the second synthesis gas generating fluid to the second portion of the selected section comprises raising a water table of the formation to allow water to flow into the second portion of the selected section.

4833. The method of claim 4779, wherein the first synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons are subjected to a reaction within the first portion of the selected section to increase a H₂ concentration within the produced first synthesis gas.

4834. The method of claim 4779, wherein the second synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons are subjected to a reaction within the second portion of the selected section to increase a H₂ concentration within the produced second synthesis gas.

4835. The method of claim 4779, wherein the first synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within the first portion of the selected section to increase an energy content of the produced first synthesis gas.

4836. The method of claim 4779, wherein the second synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within at least the second portion of the selected section to increase an energy content of the second produced synthesis gas.

4837. The method of claim 4779, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced blended synthesis gas through a turbine to generate electricity.

4838. The method of claim 4779, further comprising generating electricity from the blended synthesis gas using a fuel cell.

4839. The method of claim 4779, further comprising generating electricity from the blended synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent section of the formation.

4840. The method of claim 4779, further comprising using a portion of the blended synthesis gas as a combustion fuel for the one or more heaters.

4841. The method of claim 4779, further comprising using a portion of the first synthesis gas as a combustion fuel for the one or more heaters.

4842. The method of claim 4779, further comprising using a portion of the second synthesis gas as a combustion fuel for the one or more heaters.

4843. The method of claim 4779, further comprising using a portion of the blended synthesis gas as a combustion fuel for the one or more heaters.

4844. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat from the one or more heaters pyrolyzes at least some of the hydrocarbons within the selected section of the formation;

producing pyrolysis products from the formation;

heating at least a portion of the selected section to a temperature sufficient to generate synthesis gas;

controlling a temperature of at least a portion of the selected section to generate synthesis gas having a selected H₂ to CO ratio;

providing a synthesis gas generating fluid to at least the portion of the selected section to generate synthesis gas; and

producing a portion of the synthesis gas from the formation.

4845. The method of claim 4844, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

4846. The method of claim 4844, wherein the selected ratio is controlled to be approximately 2:

1 H₂ to CO.

4847. The method of claim 4844, wherein the selected ratio is controlled to range from approximately 1.8:

1 to approximately 2.2;

1 H₂to CO.

4848. The method of claim 4844, wherein the selected ratio is controlled to be approximately 3:

1 H₂ to CO.

4849. The method of claim 4844, wherein the selected ratio is controlled to range from approximately 2.8:

1 to approximately 3.2;

1 H₂ to CO.

4850. The method of claim 4844, further comprising providing at least a portion of the produced synthesis gas to a condensable hydrocarbon synthesis process to produce condensable hydrocarbons.

4851. The method of claim 4850, wherein the condensable hydrocarbon synthesis process comprises a Fischer-Tropsch process.

4852. The method of claim 4851, further comprising cracking at least a portion of the condensable hydrocarbons to form middle distillates.

4853. The method of claim 4844, further comprising providing at least a portion of the produced synthesis gas to a catalytic methanation process to produce methane.

4854. The method of claim 4844, further comprising providing at least a portion of the produced synthesis gas to a methanol-synthesis process to produce methanol.

4855. The method of claim 4844, further comprising providing at least a portion of the produced synthesis gas to a gasoline-synthesis process to produce gasoline.

4856. The method of claim 4844, further comprising allowing the heat to transfer from the one or more heaters to the selected section to substantially uniformly increase a permeability of the selected section.

4857. The method of claim 4844, further comprising controlling heat transfer from the one or more heaters to produce a permeability within the selected section of greater than about 100 millidarcy.

4858. The method of claim 4844, further comprising heating at least the portion of the selected section when providing the synthesis gas generating fluid to inhibit temperature decrease within the selected section during synthesis gas generation.

4859. The method of claim 4844, wherein the temperature sufficient to allow synthesis gas generation is within a range from approximately 400°

C. to approximately 1200°

C.

4860. The method of claim 4844, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises:

heating zones adjacent to wellbores of one or more heaters with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material within the zones with an oxidizing fluid;

introducing the oxidizing fluid to the zones substantially by diffusion;

allowing the oxidizing fluid to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and

transferring heat from the zones to the selected section.

4861. The method of claim 4844, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises:

introducing an oxidizing fluid into the formation through a wellbore;

transporting the oxidizing fluid substantially by convection into the portion of the selected section, wherein the portion of the selected section is at a temperature sufficient to support an oxidation reaction with the oxidizing fluid; and

reacting the oxidizing fluid within the portion of the selected section to generate heat and raise the temperature of the portion.

4862. The method of claim 4844, wherein the one or more heaters comprise one or more electrical heaters disposed in the formation.

4863. The method of claim 4844, wherein the one or more heaters comprises one or more natural distributed combustors.

4864. The method of claim 4844, wherein the one or more heaters comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.

4865. The method of claim 4844, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation and providing a synthesis gas generating fluid to at least the portion of the selected section comprises introducing steam into the portion.

4866. The method of claim 4844, further comprising controlling the heating of at least the portion of selected section and provision of the synthesis gas generating fluid to maintain a temperature within at least the portion of the selected section above the temperature sufficient to generate synthesis gas.

4867. The method of claim 4844, wherein the synthesis gas generating fluid comprises liquid water.

4868. The method of claim 4844, wherein the synthesis gas generating fluid comprises steam.

4869. The method of claim 4844, wherein the synthesis gas generating fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.

4870. The method of claim 4869, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.

4871. The method of claim 4844, wherein the synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.

4872. The method of claim 4871, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.

4873. The method of claim 4844, wherein providing the synthesis gas generating fluid to at least the portion of the selected section comprises raising a water table of the formation to allow water to flow into the at least the portion of the selected section.

4874. The method of claim 4844, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons are subjected to a reaction within at least the portion of the selected section to increase a H₂ concentration within the produced synthesis gas.

4875. The method of claim 4844, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within at least the portion of the selected section to increase an energy content of the produced synthesis gas.

4876. The method of claim 4844, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate electricity.

4877. The method of claim 4844, further comprising generating electricity from the synthesis gas using a fuel cell.

4878. The method of claim 4844, further comprising generating electricity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent section of the formation.

4879. The method of claim 4844, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heaters.

4880. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat from the one or more heaters pyrolyzes at least some of the hydrocarbons within the selected section of the formation;

producing pyrolysis products from the formation;

heating at least a portion of the selected section to a temperature sufficient to generate synthesis gas;

controlling a temperature in or proximate to a synthesis gas production well to generate synthesis gas having a selected H₂ to CO ratio;

providing a synthesis gas generating fluid to at least the portion of the selected section to generate synthesis gas; and

producing synthesis gas from the formation.

4881. The method of claim 4880, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

4882. The method of claim 4880, wherein the selected ratio is controlled to be approximately 2:

1 H₂ to CO.

4883. The method of claim 4880, wherein the selected ratio is controlled to range from approximately 1.8:

1 to approximately 2.2;

1 H₂ to CO.

4884. The method of claim 4880, wherein the selected ratio is controlled to be approximately 3:

1 H₂ to CO.

4885. The method of claim 4880, wherein the selected ratio is controlled to range from approximately 2.8:

1 to approximately 3.2;

1 H₂ to CO.

4886. The method of claim 4880, further comprising providing at least a portion of the produced synthesis gas to a condensable hydrocarbon synthesis process to produce condensable hydrocarbons.

4887. The method of claim 4886, wherein the condensable hydrocarbon synthesis process comprises a Fischer-Tropsch process.

4888. The method of claim 4887, further comprising cracking at least a portion of the condensable hydrocarbons to form middle distillates.

4889. The method of claim 4880, further comprising providing at least a portion of the produced synthesis gas to a catalytic methanation process to produce methane.

4890. The method of claim 4880, further comprising providing at least a portion of the produced synthesis gas to a methanol-synthesis process to produce methanol.

4891. The method of claim 4880, further comprising providing at least a portion of the produced synthesis gas to a gasoline-synthesis process to produce gasoline.

4892. The method of claim 4880, further comprising allowing the heat to transfer from the one or more heaters to the selected section to substantially uniformly increase a permeability of the selected section.

4893. The method of claim 4880, further comprising controlling heat transfer from the one or more heaters to produce a permeability within the selected section of greater than about 100 millidarcy.

4894. The method of claim 4880, further comprising heating at least the portion of the selected section when providing the synthesis gas generating fluid to inhibit temperature decrease within the selected section during synthesis gas generation.

4895. The method of claim 4880, wherein the temperature sufficient to allow synthesis gas generation is within a range from approximately 400°

C. to approximately 1200°

C.

4896. The method of claim 4880, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises:

heating zones adjacent to wellbores of one or more heaters with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material within the zones with an oxidizing fluid;

introducing the oxidizing fluid to the zones substantially by diffusion;

allowing the oxidizing fluid to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and

transferring heat from the zones to the selected section.

4897. The method of claim 4880, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises:

introducing an oxidizing fluid into the formation through a wellbore;

transporting the oxidizing fluid substantially by convection into the portion of the selected section, wherein the portion of the selected section is at a temperature sufficient to support an oxidation reaction with the oxidizing fluid; and

reacting the oxidizing fluid within the portion of the selected section to generate heat and raise the temperature of the portion.

4898. The method of claim 4880, wherein the one or more heaters comprise one or more electrical heaters disposed in the formation.

4899. The method of claim 4880, wherein the one or more heaters comprises one or more natural distributed combustors.

4900. The method of claim 4880, wherein the one or more heaters comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.

4901. The method of claim 4880, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation and providing a synthesis gas generating fluid to at least the portion of the selected section comprises introducing steam into the portion.

4902. The method of claim 4880, further comprising controlling the heating of at least the portion of selected section and provision of the synthesis gas generating fluid to maintain a temperature within at least the portion of the selected section above the temperature sufficient to generate synthesis gas.

4903. The method of claim 4880, wherein the synthesis gas generating fluid comprises liquid water.

4904. The method of claim 4880, wherein the synthesis gas generating fluid comprises steam.

4905. The method of claim 4880, wherein the synthesis gas generating fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.

4906. The method of claim 4905, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.

4907. The method of claim 4880, wherein the synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.

4908. The method of claim 4907, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.

4909. The method of claim 4880, wherein providing the synthesis gas generating fluid to at least the portion of the selected section comprises raising a water table of the formation to allow water to flow into the at least the portion of the selected section.

4910. The method of claim 4880, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons are subjected to a reaction within at least the portion of the selected section to increase a H₂ concentration within the produced synthesis gas.

4911. The method of claim 4880, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within at least the portion of the selected section to increase an energy content of the produced synthesis gas.

4912. The method of claim 4880, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate electricity.

4913. The method of claim 4880, further comprising generating electricity from the synthesis gas using a fuel cell.

4914. The method of claim 4880, further comprising generating electricity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent section of the formation.

4915. The method of claim 4880, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heaters.

4916. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat from the one or more heaters pyrolyzes at least some of the hydrocarbons within the selected section of the formation;

producing pyrolysis products from the formation;

heating at least a portion of the selected section to a temperature sufficient to generate synthesis gas;

controlling a temperature of at least a portion of the selected section to generate synthesis gas having a H₂ to CO ratio different than a selected H₂ to CO ratio;

providing a synthesis gas generating fluid to at least the portion of the selected section to generate synthesis gas; and

producing synthesis gas from the formation;

providing at least a portion of the produced synthesis gas to a shift process wherein an amount of carbon monoxide is converted to carbon dioxide;

separating at least a portion of the carbon dioxide to obtain a gas having a selected H₂ to CO ratio.

4917. The method of claim 4916, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

4918. The method of claim 4916, wherein the selected ratio is controlled to be approximately 2:

1 H₂ to CO.

4919. The method of claim 4916, wherein the selected ratio is controlled to range from approximately 1.8:

1 to 2.2;

1 H₂to CO.

4920. The method of claim 4916, wherein the selected ratio is controlled to be approximately 3:

1 H₂ to CO.

4921. The method of claim 4916, wherein the selected ratio is controlled to range from approximately 2.8:

1 to 3.2;

1 H₂to CO.

4922. The method of claim 4916, further comprising providing at least a portion of the produced synthesis gas to a condensable hydrocarbon synthesis process to produce condensable hydrocarbons.

4923. The method of claim 4922, wherein the condensable hydrocarbon synthesis process comprises a Fischer-Tropsch process.

4924. The method of claim 4923, further comprising cracking at least a portion of the condensable hydrocarbons to form middle distillates.

4925. The method of claim 4916, further comprising providing at least a portion of the produced synthesis gas to a catalytic methanation process to produce methane.

4926. The method of claim 4916, further comprising providing at least a portion of the produced synthesis gas to a methanol-synthesis process to produce methanol.

4927. The method of claim 4916, further comprising providing at least a portion of the produced synthesis gas to a gasoline-synthesis process to produce gasoline.

4928. The method of claim 4916, further comprising allowing the heat to transfer from the one or more heaters to the selected section to substantially uniformly increase a permeability of the selected section.

4929. The method of claim 4916, further comprising controlling heat transfer from the one or more heaters to produce a permeability within the selected section of greater than about 100 millidarcy.

4930. The method of claim 4916, further comprising heating at least the portion of the selected section when providing the synthesis gas generating fluid to inhibit temperature decrease within the selected section during synthesis gas generation.

4931. The method of claim 4916, wherein the temperature sufficient to allow synthesis gas generation is within a range from approximately 400°

C. to approximately 1200°

C.

4932. The method of claim 4916, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises:

heating zones adjacent to wellbores of one or more heaters with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material within the zones with an oxidizing fluid;

introducing the oxidizing fluid to the zones substantially by diffusion;

allowing the oxidizing fluid to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and

transferring heat from the zones to the selected section.

4933. The method of claim 4916, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation comprises:

introducing an oxidizing fluid into the formation through a wellbore;

transporting the oxidizing fluid substantially by convection into the portion of the selected section, wherein the portion of the selected section is at a temperature sufficient to support an oxidation reaction with the oxidizing fluid; and

reacting the oxidizing fluid within the portion of the selected section to generate heat and raise the temperature of the portion.

4934. The method of claim 4916, wherein the one or more heaters comprise one or more electrical heaters disposed in the formation.

4935. The method of claim 4916, wherein the one or more heaters comprises one or more natural distributed combustors.

4936. The method of claim 4916, wherein the one or more heaters comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.

4937. The method of claim 4916, wherein heating at least the portion of the selected section to a temperature sufficient to allow synthesis gas generation and providing a synthesis gas generating fluid to at least the portion of the selected section comprises introducing steam into the portion.

4938. The method of claim 4916, further comprising controlling the heating of at least the portion of selected section and provision of the synthesis gas generating fluid to maintain a temperature within at least the portion of the selected section above the temperature sufficient to generate synthesis gas.

4939. The method of claim 4916, wherein the synthesis gas generating fluid comprises liquid water.

4940. The method of claim 4916, wherein the synthesis gas generating fluid comprises steam.

4941. The method of claim 4916, wherein the synthesis gas generating fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.

4942. The method of claim 4941, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.

4943. The method of claim 4916, wherein the synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.

4944. The method of claim 4943, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.

4945. The method of claim 4916, wherein providing the synthesis gas generating fluid to at least the portion of the selected section comprises raising a water table of the formation to allow water to flow into the at least the portion of the selected section.

4946. The method of claim 4916, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers less than 5, and wherein at least a portion of the hydrocarbons are subjected to a reaction within at least the portion of the selected section to increase a H₂ concentration within the produced synthesis gas.

4947. The method of claim 4916, wherein the synthesis gas generating fluid comprises water and hydrocarbons having carbon numbers greater than 4, and wherein at least a portion of the hydrocarbons react within at least the portion of the selected section to increase an energy content of the produced synthesis gas.

4948. The method of claim 4916, further comprising maintaining a pressure within the formation during synthesis gas generation, and passing produced synthesis gas through a turbine to generate electricity.

4949. The method of claim 4916, further comprising generating electricity from the synthesis gas using a fuel cell.

4950. The method of claim 4916, further comprising generating electricity from the synthesis gas using a fuel cell, separating carbon dioxide from a fluid exiting the fuel cell, and storing a portion of the separated carbon dioxide within a spent section of the formation.

4951. The method of claim 4916, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heaters.

4952. A method of forming a spent portion of formation within a hydrocarbon containing formation, comprising:

heating a first portion of the formation to pyrolyze hydrocarbons within the first portion and to establish a substantially uniform permeability within the first portion; and

cooling the first portion.

4953. The method of claim 4952, wherein heating the first portion comprises transferring heat to the first portion from one or more electrical heaters.

4954. The method of claim 4952, wherein heating the first portion comprises transferring heat to the first portion from one or more natural distributed combustors.

4955. The method of claim 4952, wherein heating the first portion comprises transferring heat to the first portion from one or more flameless distributed combustors.

4956. The method of claim 4952, wherein heating the first portion comprises transferring heat to the first portion from heat transfer fluid flowing within one or more wellbores within the formation.

4957. The method of claim 4956, wherein the heat transfer fluid comprises steam.

4958. The method of claim 4956, wherein the heat transfer fluid comprises combustion products from a burner.

4959. The method of claim 4952, wherein heating the first portion comprises transferring heat to the first portion from at least two heater wells positioned within the formation, wherein the at least two heater wells are placed in a substantially regular pattern, wherein the substantially regular pattern comprises repetition of a base heater unit, and wherein the base heater unit is formed of a number of heater wells.

4960. The method of claim 4959, wherein a spacing between a pair of adjacent heater wells is within a range from about 6 m to about 15 m.

4961. The method of claim 4959, further comprising removing fluid from the formation through one or more production wells.

4962. The method of claim 4961, wherein the one or more production wells are located in a pattern, and wherein the one or more production wells are positioned substantially at centers of base heater units.

4963. The method of claim 4959, wherein the heater unit comprises three heater wells positioned substantially at apexes of an equilateral triangle.

4964. The method of claim 4959, wherein the heater unit comprises four heater wells positioned substantially at apexes of a rectangle.

4965. The method of claim 4959, wherein the heater unit comprises five heater wells positioned substantially at apexes of a regular pentagon.

4966. The method of claim 4959, wherein the heater unit comprises six heater wells positioned substantially at apexes of a regular hexagon.

4967. The method of claim 4952, further comprising introducing water to the first portion to cool the formation.

4968. The method of claim 4952, further comprising removing steam from the formation.

4969. The method of claim 4968, further comprising using a portion of the removed steam to heat a second portion of the formation.

4970. The method of claim 4952, further comprising removing pyrolyzation products from the formation.

4971. The method of claim 4952, further comprising generating synthesis gas within the portion by introducing a synthesis gas generating fluid into the portion, and removing synthesis gas from the formation.

4972. The method of claim 4952, further comprising heating a second section of the formation to pyrolyze hydrocarbons within the second portion, removing pyrolyzation fluid from the second portion, and storing a portion of the removed pyrolyzation fluid within the first portion.

4973. The method of claim 4972, wherein the portion of the removed pyrolyzation fluid is stored within the first portion when surface facilities that process the removed pyrolyzation fluid are not able to process the portion of the removed pyrolyzation fluid.

4974. The method of claim 4972, further comprising heating the first portion to facilitate removal of the stored pyrolyzation fluid from the first portion.

4975. The method of claim 4952, further comprising generating synthesis gas within a second portion of the formation, removing synthesis gas from the second portion, and storing a portion of the removed synthesis gas within the first portion.

4976. The method of claim 4975, wherein the portion of the removed synthesis gas from the second portion is stored within the first portion when surface facilities that process the removed synthesis gas are not able to process the portion of the removed synthesis gas.

4977. The method of claim 4975, further comprising heating the first portion to facilitate removal of the stored synthesis gas from the first portion.

4978. The method of claim 4952, further comprising removing at least a portion of hydrocarbon containing material in the first portion and, further comprising using at least a portion of the hydrocarbon containing material removed from the formation in a metallurgical application.

4979. The method of claim 4978, wherein the metallurgical application comprises steel manufacturing.

4980. A method of sequestering carbon dioxide within a hydrocarbon containing formation, comprising:

heating a portion of the formation to increase permeability and form a substantially uniform permeability within the portion;

allowing the portion to cool; and

storing carbon dioxide within the portion.

4981. The method of claim 4980, wherein the permeability of the portion is increased to over 100 millidarcy.

4982. The method of claim 4980, further comprising raising a water level within the portion to inhibit migration of the carbon dioxide from the portion.

4983. The method of claim 4980, further comprising heating the portion to release carbon dioxide, and removing carbon dioxide from the portion.

4984. The method of claim 4980, further comprising pyrolyzing hydrocarbons within the portion during heating of the portion, and removing pyrolyzation product from the formation.

4985. The method of claim 4980, further comprising producing synthesis gas from the portion during the heating of the portion, and removing synthesis gas from the formation.

4986. The method of claim 4980, wherein heating the portion comprises:

heating hydrocarbon containing material adjacent to one or more wellbores to a temperature sufficient to support oxidation of the hydrocarbon containing material with an oxidizing fluid;

introducing the oxidizing fluid to hydrocarbon containing material adjacent to the one or more wellbores to oxidize the hydrocarbons and produce heat; and

conveying produced heat to the portion.

4987. The method of claim 4986, wherein heating hydrocarbon containing material adjacent to the one or more wellbores comprises electrically heating the hydrocarbon containing material.

4988. The method of claim 4986, wherein the temperature sufficient to support oxidation is in a range from approximately 200°

C. to approximately 1200°

C.

4989. The method of claim 4980, wherein heating the portion comprises circulating heat transfer fluid through one or more heating wells within the formation.

4990. The method of claim 4989, wherein the heat transfer fluid comprises combustion products from a burner.

4991. The method of claim 4989, wherein the heat transfer fluid comprises steam.

4992. The method of claim 4980, further comprising removing fluid from the formation during heating of the formation, and combusting a portion of the removed fluid to generate heat to heat the formation.

4993. The method of claim 4980, further comprising using at least a portion of the carbon dioxide for hydrocarbon bed demethanation prior to storing the carbon dioxide within the portion.

4994. The method of claim 4980, further comprising using a portion of the carbon dioxide for enhanced oil recovery prior to storing the carbon dioxide within the portion.

4995. The method of claim 4980, wherein at least a portion of the carbon dioxide comprises carbon dioxide generated in a fuel cell.

4996. The method of claim 4980, wherein at least a portion of the carbon dioxide comprises carbon dioxide formed as a combustion product.

4997. The method of claim 4980, further comprising allowing the portion to cool by introducing water to the portion;

and removing the water from the formation as steam.

4998. The method of claim 4997, further comprising using the steam as a heat transfer fluid to heat a second portion of the formation.

4999. The method of claim 4980, wherein storing carbon dioxide in the portion comprises adsorbing carbon dioxide to hydrocarbon containing material within the formation.

5000. The method of claim 4980, wherein storing carbon dioxide comprises passing a first fluid stream comprising the carbon dioxide and other fluid through the portion;

adsorbing carbon dioxide onto hydrocarbon containing material within the formation; and

removing a second fluid stream from the formation, wherein a concentration of the other fluid in the second fluid stream is greater than concentration of other fluid in the first stream due to the absence of the adsorbed carbon dioxide in the second stream.

5001. The method of claim 4980, wherein an amount of carbon dioxide stored within the portion is equal to or greater than an amount of carbon dioxide generated within the portion and removed from the formation during heating of the portion.

5002. The method of claim 4980, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

5003. The method of claim 4980, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

5004. A method of in situ sequestration of carbon dioxide within a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a first portion of the formation;

allowing the heat to transfer from one or more sources to a selected section of the formation such that the heat from the one or more heaters pyrolyzes at least some of the hydrocarbons within the selected section of the formation;

producing pyrolyzation fluids, wherein the pyrolyzation fluids comprise carbon dioxide; and

storing an amount of carbon dioxide in the formation, wherein the amount of stored carbon dioxide is equal to or greater than an amount of carbon dioxide within the pyrolyzation fluids.

5005. The method of claim 5004, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

5006. The method of claim 5004, wherein the carbon dioxide is stored within a spent portion of the formation.

5007. The method of claim 5004, wherein a portion of the carbon dioxide stored within the formation is carbon dioxide separated from the pyrolyzation fluids.

5008. The method of claim 5004, further comprising separating a portion of carbon dioxide from the pyrolyzation fluids, and using the carbon dioxide as a flooding agent in enhanced oil recovery.

5009. The method of claim 5004, further comprising separating a portion of carbon dioxide from the pyrolyzation fluids, and using the carbon dioxide as a synthesis gas generating fluid for the generation of synthesis gas from a section of the formation that is heated to a temperature sufficient to generate synthesis gas upon introduction of the synthesis gas generating fluid.

5010. The method of claim 5004, further comprising separating a portion of carbon dioxide from the pyrolyzation fluids, and using the carbon dioxide to displace hydrocarbon bed methane.

5011. The method of claim 5010, wherein the hydrocarbon bed is a deep hydrocarbon bed located over 760 m below ground surface.

5012. The method of claim 5010, further comprising adsorbing a portion of the carbon dioxide within the hydrocarbon bed.

5013. The method of claim 5004, further comprising using at least a portion of the pyrolyzation fluids as a feed stream for a fuel cell.

5014. The method of claim 5013, wherein the fuel cell generates carbon dioxide, and further comprising storing an amount of carbon dioxide equal to or greater than an amount of carbon dioxide generated by the fuel cell within the formation.

5015. The method of claim 5004, wherein a spent portion of the formation comprises hydrocarbon containing material within a section of the formation that has been heated and from which condensable hydrocarbons have been produced, and wherein the spent portion of the formation is at a temperature at which carbon dioxide adsorbs onto the hydrocarbon containing material.

5016. The method of claim 5004, further comprising raising a water level within the spent portion to inhibit migration of the carbon dioxide from the portion.

5017. The method of claim 5004, wherein producing fluids from the formation comprises removing pyrolyzation products from the formation.

5018. The method of claim 5004, wherein producing fluids from the formation comprises heating the selected section to a temperature sufficient to generate synthesis gas;

introducing a synthesis gas generating fluid into the selected section; and

removing synthesis gas from the formation.

5019. The method of claim 5018, wherein the temperature sufficient to generate synthesis gas ranges from about 400°

C. to about 1200°

C.

5020. The method of claim 5018, wherein heating the selected section comprises introducing an oxidizing fluid into the selected section, reacting the oxidizing fluid within the selected section to heat the selected section.

5021. The method of claim 5018, wherein heating the selected section comprises:

heating hydrocarbon containing material adjacent to one or more wellbores to a temperature sufficient to support oxidation of the hydrocarbon containing material with an oxidant;

introducing the oxidant to hydrocarbon containing material adjacent to the one or more wellbores to oxidize the hydrocarbons and produce heat; and

conveying produced heat to the portion.

5022. The method of claim 5004, wherein the spent portion of the formation comprises a substantially uniform permeability created by heating the spent formation and removing fluid during formation of the spent portion.

5023. The method of claim 5004, wherein the one or more heaters comprise electrical heaters.

5024. The method of claim 5004, wherein the one or more heaters comprise flameless distributed combustors.

5025. The method of claim 5024, wherein a portion of fuel for the one or more flameless distributed combustors is obtained from the formation.

5026. The method of claim 5004, wherein the one or more heaters comprise heater wells in the formation through which heat transfer fluid is circulated.

5027. The method of claim 5026, wherein the heat transfer fluid comprises combustion products.

5028. The method of claim 5026, wherein the heat transfer fluid comprises steam.

5029. The method of claim 5004, wherein condensable hydrocarbons are produced under pressure, and further comprising generating electricity by passing a portion of the produced fluids through a turbine.

5030. The method of claim 5004, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.

5031. The method of claim 5004, further comprising providing heat from three or more heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.

5032. A method for in situ production of energy from a hydrocarbon containing formation, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat from the one or more heaters pyrolyzes at least a portion of the hydrocarbons within the selected section of the formation;

producing pyrolysis products from the formation;

providing at least a portion of the pyrolysis products to a reformer to generate synthesis gas;

producing the synthesis gas from the reformer;

providing at least a portion of the produced synthesis gas to a fuel cell to produce electricity, wherein the fuel cell produces a carbon dioxide containing exit stream; and

storing at least a portion of the carbon dioxide in the carbon dioxide containing exit stream in a subsurface formation.

5033. The method of claim 5032, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

5034. The method of claim 5032, wherein at least a portion of the pyrolysis products are used as fuel in the reformer.

5035. The method of claim 5032, wherein the synthesis gas comprises substantially of H₂.

5036. The method of claim 5032, wherein the subsurface formation is a spent portion of the formation.

5037. The method of claim 5032, wherein the subsurface formation is an oil reservoir.

5038. The method of claim 5037, wherein at least a portion of the carbon dioxide is used as a drive fluid for enhanced oil recovery in the oil reservoir.

5039. The method of claim 5032, wherein the subsurface formation is a coal formation.

5040. The method of claim 5039, wherein at least a portion of the carbon dioxide is used to produce methane from the coal formation.

5041. The method of claim 5039, wherein the coal formation is located over about 760 m below ground surface.

5042. The method of claim 5040, further comprising sequestering at least a portion of the carbon dioxide within the coal formation.

5043. The method of claim 5032, wherein the reformer produces a reformer carbon dioxide containing exit stream.

5044. The method of claim 5032, further comprising storing at least a portion of the carbon dioxide in the reformer carbon dioxide containing exit stream in the subsurface formation.

5045. The method of claim 5044, wherein the subsurface formation is a spent portion of the formation.

5046. The method of claim 5044, wherein the subsurface formation is an oil reservoir.

5047. The method of claim 5046, wherein at least a portion of the carbon dioxide in the reformer carbon dioxide containing exit stream is used as a drive fluid for enhanced oil recovery in the oil reservoir.

5048. The method of claim 5044, wherein the subsurface formation is a coal formation.

5049. The method of claim 5048, wherein at least a portion of the carbon dioxide in the reformer carbon dioxide containing exit stream is used to produce methane from the coal formation.

5050. The method of claim 5048, wherein the coal formation is located over about 760 m below ground surface.

5051. The method of claim 5049, further comprising sequestering at least a portion of the carbon dioxide in the reformer carbon dioxide containing exit stream within the coal formation.

5052. The method of claim 5032, wherein the fuel cell is a molten carbonate fuel cell.

5053. The method of claim 5032, wherein the fuel cell is a solid oxide fuel cell.

5054. The method of claim 5032, further comprising using a portion of the produced electricity to power electrical heaters within the formation.

5055. The method of claim 5032, further comprising using a portion of the produced pyrolysis products as a feed stream for the fuel cell.

5056. The method of claim 5032, wherein the one or more heaters comprise one or more electrical heaters disposed in the formation.

5057. The method of claim 5032, wherein the one or more heaters comprise one or more flameless distributed combustors disposed in the formation.

5058. The method of claim 5057, wherein a portion of fuel for the flameless distributed combustors is obtained from the formation.

5059. The method of claim 5032, wherein the one or more heaters comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.

5060. The method of claim 5032, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heaters.

5061. A method for producing ammonia using a hydrocarbon containing formation, comprising:

separating air to produce an O₂ rich stream and a N₂ rich stream;

heating a selected section of the formation to a temperature sufficient to support reaction of hydrocarbon containing material in the formation to form synthesis gas;

providing synthesis gas generating fluid and at least a portion of the O₂ rich stream to the selected section;

allowing the synthesis gas generating fluid and O₂ in the O₂ rich stream to react with at least a portion of the hydrocarbon containing material in the formation to generate synthesis gas;

producing synthesis gas from the formation, wherein the synthesis gas comprises H₂ and CO;

providing at least a portion of the H₂ in the synthesis gas to an ammonia synthesis process;

providing N₂ to the ammonia synthesis process; and

using the ammonia synthesis process to generate ammonia.

5062. The method of claim 5061, wherein the ratio of the H₂ to N₂ provided to the ammonia synthesis process is approximately 3:

1.

5063. The method of claim 5061, wherein the ratio of the H₂ to N₂ provided to the ammonia synthesis process ranges from approximately 2.8:

1 to approximately 3.2;

1.

5064. The method of claim 5061, wherein the temperature sufficient to support reaction of hydrocarbon containing material in the formation to form synthesis gas ranges from approximately 400°

C. to approximately 1200°

C.

5065. The method of claim 5061, further comprising separating at least a portion of carbon dioxide in the synthesis gas from at least a portion of the synthesis gas.

5066. The method of claim 5065, wherein the carbon dioxide is separated from the synthesis gas by an amine separator.

5067. The method of claim 5066, further comprising providing at least a portion of the carbon dioxide to a urea synthesis process to produce urea.

5068. The method of claim 5061, wherein at least a portion of the N₂ stream is used to condense hydrocarbons with 4 or more carbon atoms from a pyrolyzation fluid.

5069. The method of claim 5061, wherein at least a portion of the N₂ rich stream is provided to the ammonia synthesis process.

5070. The method of claim 5061, wherein the air is separated by cryogenic distillation.

5071. The method of claim 5061, wherein the air is separated by membrane separation.

5072. The method of claim 5061, wherein fluids produced during pyrolysis of a hydrocarbon containing formation comprise ammonia and, further comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.

5073. The method of claim 5061, wherein fluids produced during pyrolysis of a hydrocarbon formation are hydrotreated and at least some ammonia is produced during hydrotreating, and, further comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.

5074. The method of claim 5061, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea.

5075. The method of claim 5061, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea and, further comprising providing carbon dioxide from the formation to the urea synthesis process.

5076. The method of claim 5061, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea and, further comprising shifting at least a portion of the carbon monoxide to carbon dioxide in a shift process, and further comprising providing at least a portion of the carbon dioxide from the shift process to the urea synthesis process.

5077. The method of claim 5061, wherein heating the selected section of the formation to a temperature to support reaction of hydrocarbon containing material in the formation to form synthesis gas comprises:

heating zones adjacent to wellbores of one or more heaters with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material within the zones with O₂ in the O₂ rich stream;

introducing the O₂ to the zones substantially by diffusion;

allowing O₂ in the O₂ rich stream to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and

transferring heat from the zones to the selected section.

5078. The method of claim 5077, wherein temperatures sufficient to support reaction of hydrocarbon containing material within the zones with O₂ range from approximately 200 °

C. to approximately 1200°

C.

5079. The method of claim 5077, wherein the one or more heaters comprises one or more electrical heaters disposed in the formation.

5080. The method of claim 5077, wherein the one or more heaters comprises one or more natural distributed combustors.

5081. The method of claim 5077, wherein the one or more heaters comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.

5082. The method of claim 5077, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heaters.

5083. The method of claim 5061, wherein heating the selected section of the formation to a temperature to support reaction of hydrocarbon containing material in the formation to form synthesis gas comprises:

introducing the O₂ rich stream into the formation through a wellbore;

transporting O₂ in the O₂ rich stream substantially by convection into the portion of the selected section, wherein the portion of the selected section is at a temperature sufficient to support an oxidation reaction with O₂ in the O₂ rich stream; and

reacting the O₂ within the portion of the selected section to generate heat and raise the temperature of the portion.

5084. The method of claim 5083, wherein the temperature sufficient to support an oxidation reaction with O₂ ranges from approximately 200°

C. to approximately 120°

C.

5085. The method of claim 5083, wherein the one or more heaters comprises one or more electrical heaters disposed in the formation.

5086. The method of claim 5083, wherein the one or more heaters comprises one or more natural distributed combustors.

5087. The method of claim 5083, wherein the one or more heaters comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.

5088. The method of claim 5083, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heaters.

5089. The method of claim 5061, further comprising controlling the heating of at least the portion of the selected section and provision of the synthesis gas generating fluid to maintain a temperature within at least the portion of the selected section above the temperature sufficient to generate synthesis gas.

5090. The method of claim 5061, wherein the synthesis gas generating fluid comprises liquid water.

5091. The method of claim 5061, wherein the synthesis gas generating fluid comprises steam.

5092. The method of claim 5061, wherein the synthesis gas generating fluid comprises water and carbon dioxide wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.

5093. The method of claim 5092, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.

5094. The method of claim 5061, wherein the synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.

5095. The method of claim 5094, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.

5096. The method of claim 5061, wherein providing the synthesis gas generating fluid to at least the portion of the selected section comprises raising a water table of the formation to allow water to flow into the at least the portion of the selected section.

5097. A method for producing ammonia using a hydrocarbon containing formation, comprising:

generating a first ammonia feed stream from a first portion of the formation;

generating a second ammonia feed stream from a second portion of the formation, wherein the second ammonia feed stream has a H₂ to N₂ ratio greater than a H₂ to N₂ ratio of the first ammonia feed stream;

blending at least a portion of the first ammonia feed stream with at least a portion of the second ammonia feed stream to produce a blended ammonia feed stream having a selected H₂ to N₂ ratio;

providing the blended ammonia feed stream to an ammonia synthesis process; and

using the ammonia synthesis process to generate ammonia.

5098. The method of claim 5097, wherein the selected ratio is approximately 3:

1.

5099. The method of claim 5097, wherein the selected ratio ranges from approximately 2.8:

1 to approximately 3.2;

1.

5100. The method of claim 5097, further comprising separating at least a portion of carbon dioxide in the first ammonia feed stream from at least a portion of the first ammonia feed stream.

5101. The method of claim 5100, wherein the carbon dioxide is separated from the first ammonia feed stream by an amine separator.

5102. The method of claim 5101, further comprising providing at least a portion of the carbon dioxide to a urea synthesis process.

5103. The method of claim 5097, further comprising separating at least a portion of carbon dioxide in the blended ammonia feed stream from at least a portion of the blended ammonia feed stream.

5104. The method of claim 5103, wherein the carbon dioxide is separated from the blended ammonia feed stream by an amine separator.

5105. The method of claim 5104, further comprising providing at least a portion of the carbon dioxide to a urea synthesis process.

5106. The method of claim 5097, further comprising separating at least a portion of carbon dioxide in the second ammonia feed stream from at least a portion of the second ammonia feed stream.

5107. The method of claim 5106, wherein the carbon dioxide is separated from the second ammonia feed stream by an amine separator.

5108. The method of claim 5107, further comprising providing at least a portion of the carbon dioxide to a urea synthesis process.

5109. The method of claim 5097, wherein fluids produced during pyrolysis of a hydrocarbon containing formation comprise ammonia and, further comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.

5110. The method of claim 5097, wherein fluids produced during pyrolysis of a hydrocarbon formation are hydrotreated and at least some ammonia is produced during hydrotreating, and further comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.

5111. The method of claim 5097, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea.

5112. The method of claim 5097, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea and, further comprising providing carbon dioxide from the formation to the urea synthesis process.

5113. The method of claim 5097, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea and further comprising shifting at least a portion of carbon monoxide in the blended ammonia feed stream to carbon dioxide in a shift process, and further comprising providing at least a portion of the carbon dioxide from the shift process to the urea synthesis process.

5114. A method for producing ammonia using a hydrocarbon containing formation, comprising:

heating a selected section of the formation to a temperature sufficient to support reaction of hydrocarbon containing material in the formation to form synthesis gas;

providing a synthesis gas generating fluid and an O₂ rich stream to the selected section, wherein the amount of N₂ in the O₂ rich stream is sufficient to generate synthesis gas having a selected ratio of H₂ to N₂;

allowing the synthesis gas generating fluid and O₂ in the O₂ rich stream to react with at least a portion of the hydrocarbon containing material in the formation to generate synthesis gas having a selected ratio of H₂ to N₂;

producing the synthesis gas from the formation;

providing at least a portion of the H₂ and N₂ in the synthesis gas to an ammonia synthesis process;

using the ammonia synthesis process to generate ammonia.

5115. The method of claim 5114, further comprising controlling a temperature of at least a portion of the selected section to generate synthesis gas having the selected H₂ to N₂ ratio.

5116. The method of claim 5114, wherein the selected ratio is approximately 3:

1.

5117. The method of claim 5114, wherein the selected ratio ranges from approximately 2.8:

1 to 3.2;

1.

5118. The method of claim 5114, wherein the temperature sufficient to support reaction of hydrocarbon containing material in the formation to form synthesis gas ranges from approximately 400°

C. to approximately 1200°

C.

5119. The method of claim 5114, wherein the O₂ stream and N₂ stream are obtained by cryogenic separation of air.

5120. The method of claim 5114, wherein the O₂ stream and N₂ stream are obtained by membrane separation of air.

5121. The method of claim 5114, further comprising separating at least a portion of carbon dioxide in the synthesis gas from at least a portion of the synthesis gas.

5122. The method of claim 5121, wherein the carbon dioxide is separated from the synthesis gas by an amine separator.

5123. The method of claim 5122, further comprising providing at least a portion of the carbon dioxide to a urea synthesis process.

5124. The method of claim 5114, wherein fluids produced during pyrolysis of a hydrocarbon containing formation comprise ammonia and, fturther comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.

5125. The method of claim 5114, wherein fluids produced during pyrolysis of a hydrocarbon formation are hydrotreated and at least some ammonia is produced during hydrotreating, and further comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.

5126. The method of claim 5114, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea.

5127. The method of claim 5114, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea and, further comprising providing carbon dioxide from the formation to the urea synthesis process.

5128. The method of claim 5114, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea and further comprising shifting at least a portion of carbon monoxide in the synthesis gas to carbon dioxide in a shift process, and further comprising providing at least a portion of the carbon dioxide from the shift process to the urea synthesis process.

5129. The method of claim 5114, wherein heating a selected section of the formation to a temperature to support reaction of hydrocarbon containing material in the formation to form synthesis gas comprises:

heating zones adjacent to wellbores of one or more heaters with heaters disposed in the wellbores, wherein the heaters are configured to raise temperatures of the zones to temperatures sufficient to support reaction of hydrocarbon containing material within the zones with O₂ in the O₂ rich stream;

introducing the O₂ to the zones substantially by diffusion;

allowing O₂ in the O₂ rich stream to react with at least a portion of the hydrocarbon containing material within the zones to produce heat in the zones; and

transferring heat from the zones to the selected section.

5130. The method of claim 5129, wherein temperatures sufficient to support reaction of hydrocarbon containing material within the zones with O₂ range from approximately 200°

C. to approximately 1200°

C.

5131. The method of claim 5129, wherein the one or more heaters comprises one or more electrical heaters disposed in the formation.

5132. The method of claim 5129, wherein the one or more heaters comprises one or more natural distributed combustors.

5133. The method of claim 5129, wherein the one or more heaters comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.

5134. The method of claim 5129, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heaters.

5135. The method of claim 5114, wherein heating the selected section of the formation to a temperature to support reaction of hydrocarbon containing material in the formation to form synthesis gas comprises:

introducing the O₂ rich stream into the formation through a wellbore;

transporting O₂ in the O₂ rich stream substantially by convection into the portion of the selected section, wherein the portion of the selected section is at a temperature sufficient to support an oxidation reaction with O₂ in the O₂ rich stream; and

reacting the O₂ within the portion of the selected section to generate heat and raise the temperature of the portion.

5136. The method of claim 5135, wherein the temperature sufficient to support an oxidation reaction with O₂ ranges from approximately 200 °

C. to approximately 120°

C.

5137. The method of claim 5135, wherein the one or more heaters comprises one or more electrical heaters disposed in the formation.

5138. The method of claim 5135, wherein the one or more heaters comprises one or more natural distributed combustors.

5139. The method of claim 5135, wherein the one or more heaters comprise one or more heater wells, wherein at least one heater well comprises a conduit disposed within the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.

5140. The method of claim 5135, further comprising using a portion of the synthesis gas as a combustion fuel for the one or more heaters.

5141. The method of claim 5114, further comprising controlling the heating of at least the portion of the selected section and provision of the synthesis gas generating fluid to maintain a temperature within at least the portion of the selected section above the temperature sufficient to generate synthesis gas.

5142. The method of claim 5114, wherein the synthesis gas generating fluid comprises liquid water.

5143. The method of claim 5114, wherein the synthesis gas generating fluid comprises steam.

5144. The method of claim 5114, wherein the synthesis gas generating fluid comprises water and carbon dioxide, wherein the carbon dioxide inhibits production of carbon dioxide from the selected section.

5145. The method of claim 5144, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.

5146. The method of claim 5114, wherein the synthesis gas generating fluid comprises carbon dioxide, and wherein a portion of the carbon dioxide reacts with carbon in the formation to generate carbon monoxide.

5147. The method of claim 5146, wherein a portion of the carbon dioxide within the synthesis gas generating fluid comprises carbon dioxide removed from the formation.

5148. The method of claim 5114, wherein providing the synthesis gas generating fluid to at least the portion of the selected section comprises raising a water table of the formation to allow water to flow into the at least the portion of the selected section.

5149. A method for producing ammonia using a hydrocarbon containing formation, comprising:

providing a first stream comprising N₂ and carbon dioxide to the formation;

allowing at least a portion of the carbon dioxide in the first stream to adsorb in the formation;

producing a second stream from the formation, wherein the second stream comprises a lower percentage of carbon dioxide than the first stream;

providing at least a portion of the N₂ in the second stream to an ammonia synthesis process.

5150. The method of claim 5149, wherein the second stream comprises H₂ from the formation.

5151. The method of claim 5149, wherein the first stream is produced from a hydrocarbon containing formation.

5152. The method of claim 5151, wherein the first stream is generated by reacting a oxidizing fluid with hydrocarbon containing material in the formation.

5153. The method of claim 5149, wherein the second stream comprises H₂ from the formation and, further comprising providing such H₂ to the ammonia synthesis process.

5154. The method of claim 5149, further comprising using the ammonia synthesis process to generate ammonia.

5155. The method of claim 5154, wherein fluids produced during pyrolysis of a hydrocarbon containing formation comprise ammonia and, further comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.

5156. The method of claim 5154, wherein fluids produced during pyrolysis of a hydrocarbon formation are hydrotreated and at least some ammonia is produced during hydrotreating, and further comprising adding at least a portion of such ammonia to the ammonia generated from the ammonia synthesis process.

5157. The method of claim 5154, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea.

5158. The method of claim 5154, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea and, further comprising providing carbon dioxide from the formation to the urea synthesis process.

5159. The method of claim 5154, further comprising providing at least a portion of the ammonia to a urea synthesis process to produce urea and further comprising shifting at least a portion of carbon monoxide in the synthesis gas to carbon dioxide in a shift process, and further comprising providing at least a portion of the carbon dioxide from the shift process to the urea synthesis process.

5160. A method of treating a hydrocarbon containing permeable formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the permeable formation;

allowing the heat to transfer from the one or more heaters to a selected mobilization section of the permeable formation such that the heat from the one or more heaters can mobilize at least some of the hydrocarbons within the selected mobilization section of the permeable formation;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected mobilization section of the permeable formation is less than about 150°

C.;

allowing the heat to transfer from the one or more heaters to a selected pyrolyzation section of the permeable formation such that the heat from the one or more heaters can pyrolyze at least some of the hydrocarbons within the selected pyrolyzation section of the permeable formation;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected pyrolyzation section of the permeable formation is less than about 375°

C.; and

producing a mixture from the permeable formation.

5161. The method of claim 5160, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from the one or more heaters can mobilize at least some of the hydrocarbons within the selected mobilization section of the permeable formation.

5162. The method of claim 5160, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from the one or more heaters can mobilize at least some of the hydrocarbons within the selected pyrolyzation section of the permeable formation.

5163. The method of claim 5160, wherein the one or more heaters comprise electrical heaters.

5164. The method of claim 5160, wherein the one or more heaters comprise surface burners.

5165. The method of claim 5160, wherein the one or more heaters comprise flameless distributed combustors.

5166. The method of claim 5160, wherein the one or more heaters comprise natural distributed combustors.

5167. The method of claim 5160, further comprising disposing the one or more heaters horizontally within the permeable formation.

5168. The method of claim 5160, further comprising controlling a pressure and a temperature within at least a majority of the permeable formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

5169. The method of claim 5160, further comprising controlling the heat such that an average heating rate of the selected pyrolyzation section is less than about 15°

C./day during pyrolysis.

5170. The method of claim 5160, wherein providing heat from the one or more heaters to at least the portion of permeable formation comprises:

heating a selected volume (V) of the hydrocarbon containing permeable formation from the one or more heaters, wherein the formation has an average heat capacity(C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

5171. The method of claim 5160, wherein allowing the heat to transfer from the one or more heaters to the selected mobilization section and/or the selected pyrolyzation section comprises transferring heat substantially by conduction.

5172. The method of claim 5160, wherein producing the mixture from the permeable formation further comprises producing mixture having an API gravity of at least about 25°

.

5173. The method of claim 5160, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.5% by weight, of the condensable hydrocarbons, when calculated on an atomic basis, is nitrogen.

5174. The method of claim 5160, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 7% by weight, of the condensable hydrocarbons, when calculated on an atomic basis, is oxygen.

5175. The method of claim 5160, wherein the produced mixture comprises sulfur, and wherein less than about 5% by weight, of the condensable hydrocarbons, when calculated on an atomic basis, is sulfur.

5176. The method of claim 5160, further comprising controlling a pressure within at least a majority of the permeable formation, wherein the controlled pressure is at least about 2 bars absolute.

5177. The method of claim 5160, further comprising altering a pressure within the permeable formation to inhibit production of hydrocarbons from the permeable formation having carbon numbers greater than about 25.

5178. The method of claim 5160, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

5179. The method of claim 5160, wherein the produced mixture comprises condensable hydrocarbons and hydrogen, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

5180. The method of claim 5160, wherein producing the mixture from the permeable formation further comprises producing the mixture in a production well, wherein the heating is controlled such that the mixture can be produced from the permeable formation, and wherein at least about 4 heaters are disposed in the permeable formation for each production well.

5181. The method of claim 5160, wherein producing the mixture from the permeable formation further comprises producing the mixture in a production well, wherein the heating is controlled such that the mixture can be produced from the permeable formation, and wherein the production well is disposed substantially horizontally within the permeable formation.

5182. The method of claim 5160, further comprising separating the mixture into a gas stream and a liquid stream.

5183. The method of claim 5160, further comprising separating the mixture into a gas stream and a liquid stream and separating the liquid stream into an aqueous stream and a non-aqueous stream.

5184. The method of claim 5160, wherein the mixture is produced from a production well, the method further comprising heating a wellbore of the production well to inhibit condensation of the mixture within the wellbore.

5185. The method of claim 5160, wherein the mixture is produced from a production well, wherein a wellbore of the production well comprises a heater element configured to heat the permeable formation adjacent to the wellbore, and further comprising heating the permeable formation with the heater element to produce the mixture, wherein the mixture comprises non-condensable hydrocarbons and H₂.

5186. The method of claim 5160, wherein a minimum mobilization temperature is about 75°

C.

5187. The method of claim 5160, wherein a minimum pyrolysis temperature is about 270°

C.

5188. The method of claim 5160, further comprising maintaining the pressure within the permeable formation above about 2 bars absolute to inhibit production of fluids having carbon numbers above 25.

5189. The method of claim 5160, further comprising controlling pressure within the permeable formation in a range from about atmospheric pressure to about 100 bars absolute, as measured at a wellhead of a production well, to control an amount of condensable fluids within the mixture, wherein the pressure is reduced to increase production of condensable fluids, and wherein the pressure is increased to increase production of non-condensable fluids.

5190. The method of claim 5160, further comprising controlling pressure within the permeable formation in a range from about atmospheric pressure to about 100 bars absolute, as measured at a wellhead of a production well, to control an API gravity of condensable fluids within the mixture, wherein the pressure is reduced to decrease the API gravity, and wherein the pressure is increased to reduce the API gravity.

5191. The method of claim 5160, wherein mobilizing the hydrocarbons within the selected mobilization section comprises reducing a viscosity of the hydrocarbons.

5192. The method of claim 5160, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation.

5193. The method of claim 5160, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation, and wherein the gas comprises carbon dioxide.

5194. The method of claim 5160, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation, and wherein the gas comprises nitrogen.

5195. The method of claim 5160, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation, the method further comprising controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled.

5196. The method of claim 5160, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation, the method further comprising controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled, wherein the pressure of the provided gas is above about 2 bars absolute.

5197. The method of claim 5160, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation, the method further comprising controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled, wherein the pressure of the provided gas is below about 70 bars absolute.

5198. A method of treating a hydrocarbon containing permeable formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the permeable formation;

allowing the heat to transfer from the one or more heaters to a selected mobilization section of the permeable formation such that the heat from the one or more heaters can mobilize at least some of the hydrocarbons within the selected mobilization section of the permeable formation;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected mobilization section of the permeable formation is less than about 150°

C.;

allowing the heat to transfer from the one or more heaters to a selected pyrolyzation section of the permeable formation such that the heat from the one or more heaters can pyrolyze at least some of the hydrocarbons within the selected pyrolyzation section of the permeable formation;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected pyrolyzation section of the permeable formation is less than about 375°

C.;

allowing at least some of the mobilized hydrocarbons to flow from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation; and

producing a mixture from the permeable formation.

5199. The method of claim 5198, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from the one or more heaters can mobilize at least some of the hydrocarbons within the selected mobilization section of the permeable formation.

5200. The method of claim 5198, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from the one or more heaters can pyrolyze at least some of the hydrocarbons within the selected pyrolyzation section of the permeable formation.

5201. The method of claim 5198, wherein the one or more heaters comprise electrical heaters.

5202. The method of claim 5198, wherein the one or more heaters comprise surface burners.

5203. The method of claim 5198, wherein the one or more heaters comprise flameless distributed combustors.

5204. The method of claim 5198, wherein the one or more heaters comprise natural distributed combustors.

5205. The method of claim 5198, further comprising disposing the one or more heaters horizontally within the permeable formation.

5206. The method of claim 5198, further comprising controlling a pressure and a temperature within at least a majority of the permeable formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

5207. The method of claim 5198, further comprising controlling the heat such that an average heating rate of the selected pyrolyzation section is less than about 15°

C./day during pyrolysis.

5208. The method of claim 5198, wherein providing heat from the one or more heaters to at least the portion of permeable formation comprises:

heating a selected volume (V) of the hydrocarbon containing permeable formation from the one or more heaters, wherein the formation has an average heat capacity(C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

5209. The method of claim 5198, wherein allowing the heat to transfer from the one or more heaters to the selected mobilization section and/or the selected pyrolyzation section comprises transferring heat substantially by conduction.

5210. The method of claim 5198, wherein producing the mixture from the permeable formation further comprises producing a mixture having an API gravity of at least about 25°

.

5211. The method of claim 5198, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.5% by weight, of the condensable hydrocarbons, when calculated on an atomic basis, is nitrogen.

5212. The method of claim 5198, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 7% by weight, of the condensable hydrocarbons, when calculated on an atomic basis, is oxygen.

5213. The method of claim 5198, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight, of the condensable hydrocarbons, when calculated on an atomic basis, is sulfur.

5214. The method of claim 5198, further comprising controlling a pressure within at least a majority of the permeable formation, wherein the controlled pressure is at least about 2 bars absolute.

5215. The method of claim 5198, further comprising altering a pressure within the permeable formation to inhibit production of hydrocarbons from the permeable formation having carbon numbers greater than about 25.

5216. The method of claim 5198, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

5217. The method of claim 5198, wherein the produced mixture comprises condensable hydrocarbons and hydrogen, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

5218. The method of claim 5198, wherein producing the mixture from the permeable formation further comprises producing mixture in a production well, wherein the heating is controlled such that the mixture can be produced from the permeable formation, and wherein at least about 4 heaters are disposed in the permeable formation for each production well.

5219. The method of claim 5198, wherein producing the mixture from the permeable formation further comprises producing mixture in a production well, wherein the heating is controlled such that the mixture can be produced from the permeable formation, and wherein the production well is disposed substantially horizontally within the permeable formation.

5220. The method of claim 5198, further comprising separating the mixture into a gas stream and a liquid stream.

5221. The method of claim 5198, further comprising separating the mixture into a gas stream and a liquid stream and separating the liquid stream into an aqueous stream and a non-aqueous stream.

5222. The method of claim 5198, wherein the mixture is produced from a production well, the method further comprising heating a wellbore of the production well to inhibit condensation of the mixture within the wellbore.

5223. The method of claim 5198, wherein the mixture is produced from a production well, wherein a wellbore of the production well comprises a heater element configured to heat the permeable formation adjacent to the wellbore, and further comprising heating the permeable formation with the heater element to produce the mixture, wherein the mixture comprises non-condensable hydrocarbons and H₂.

5224. The method of claim 5198, wherein a minimum mobilization temperature is about 75°

C.

5225. The method of claim 5198, wherein a minimum pyrolysis temperature is about 270°

C.

5226. The method of claim 5198, further comprising maintaining the pressure within the permeable formation above about 2 bars absolute to inhibit production of fluids having carbon numbers above 25.

5227. The method of claim 5198, further comprising controlling pressure within the permeable formation in a range from about atmospheric pressure to about 100 bars absolute, as measured at a wellhead of a production well, to control an amount of condensable fluids within the mixture, wherein the pressure is reduced to increase production of condensable fluids, and wherein the pressure is increased to increase production of non-condensable fluids.

5228. The method of claim 5198, further comprising controlling pressure within the permeable formation in a range from about atmospheric pressure to about 100 bars absolute, as measured at a wellhead of a production well, to control an API gravity of condensable fluids within the mixture, wherein the pressure is reduced to decrease the API gravity, and wherein the pressure is increased to reduce the API gravity.

5229. The method of claim 5198, wherein mobilizing the hydrocarbons within the selected mobilization section comprises reducing a viscosity of the hydrocarbons.

5230. The method of claim 5198, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation.

5231. The method of claim 5198, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation, and wherein the gas comprises carbon dioxide.

5232. The method of claim 5198, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation, and wherein the gas comprises nitrogen.

5233. The method of claim 5198, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation, the method further comprising controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled.

5234. The method of claim 5198, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation, the method further comprising controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled, wherein the pressure of the provided gas is above about 2 bars absolute.

5235. The method of claim 5198, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation, the method further comprising controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled, wherein the pressure of the provided gas is below about 100 bars absolute.

5236. A method of treating a hydrocarbon containing permeable formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the permeable formation;

allowing the heat to transfer from the one or more heaters to a selected mobilization section of the permeable formation such that the heat from the one or more heaters can mobilize at least some of the hydrocarbons within the selected mobilization section of the permeable formation;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected mobilization section of the permeable formation is less than about 150°

C.;

allowing the heat to transfer front the one or more heaters to a selected pyrolyzation section of the permeable formation such that the heat from the one or more heaters can pyrolyze at least some of the hydrocarbons within the selected pyrolyzation section of the permeable formation;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected pyrolyzation section of the permeable formation is less than about 375°

C.;

allowing at least some of the mobilized hydrocarbons to flow from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation;

providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation; and

producing a mixture from the permeable formation.

5237. The method of claim 5236, wherein the one or more heaters comprise at least two heaters, and wherein the heat from the one or more heaters can mobilize at least some of the hydrocarbons within the selected mobilization section of the permeable formation.

5238. The method of claim 5236, wherein the one or more heaters comprise at least two heaters, and wherein the heat from the one or more heaters can pyrolyze at least some of the hydrocarbons within the selected pyrolyzation section of the permeable formation.

5239. The method of claim 5236, wherein the one or more heaters comprise electrical heaters.

5240. The method of claim 5236, wherein the one or more heaters comprise surface burners.

5241. The method of claim 5236, wherein the one or more heaters comprise flameless distributed combustors.

5242. The method of claim 5236, wherein the one or more heaters comprise natural distributed combustors.

5243. The method of claim 5236, further comprising disposing the one or more heaters horizontally within the permeable formation.

5244. The method of claim 5236, further comprising controlling a pressure and a temperature within at least a majority of the permeable formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

5245. The method of claim 5236, further comprising controlling the heat such that an average heating rate of the selected pyrolyzation section is less than about 15°

C./day during pyrolysis.

5246. The method of claim 5236, wherein providing heat from the one or more heaters to at least the portion of permeable formation comprises:

heating a selected volume (V) of the hydrocarbon containing permeable formation from the one or more heaters, wherein the formation has an average heat capacity(C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

5247. The method of claim 5236, wherein allowing the heat to transfer from the one or more heaters to the selected mobilization section and/or the selected pyrolyzation section comprises transferring heat substantially by conduction.

5248. The method of claim 5236, wherein producing mixture from the permeable formation further comprises producing mixture having an API gravity of at least about 25°

.

5249. The method of claim 5236, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.5% by weight, of the condensable hydrocarbons, when calculated on an atomic basis, is nitrogen.

5250. The method of claim 5236, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 7% by weight, of the condensable hydrocarbons, when calculated on an atomic basis, is oxygen.

5251. The method of claim 5236, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight, of the condensable hydrocarbons, when calculated on an atomic basis, is sulfur.

5252. The method of claim 5236, further comprising controlling a pressure within at least a majority of the permeable formation, wherein the controlled pressure is at least about 2 bars absolute.

5253. The method of claim 5236, further comprising altering a pressure within the permeable formation to inhibit production of hydrocarbons from the permeable formation having carbon numbers greater than about 25.

5254. The method of claim 5236, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

5255. The method of claim 5236, wherein the produced mixture comprises condensable hydrocarbons and hydrogen, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

5256. The method of claim 5236, wherein producing the mixture from the permeable formation further comprises producing the mixture in a production well, wherein the heating is controlled such that the mixture can be produced from the permeable formation, and wherein at least about 4 heaters are disposed in the permeable formation for each production well.

5257. The method of claim 5236, wherein producing the mixture from the permeable formation further comprises producing the mixture in a production well, wherein the heating is controlled such that the mixture can be produced from the permeable formation, and wherein the production well is disposed substantially horizontally within the permeable formation.

5258. The method of claim 5236, further comprising separating the mixture into a gas stream and a liquid stream.

5259. The method of claim 5236, further comprising separating the mixture into a gas stream and a liquid stream and separating the liquid stream into an aqueous stream and a non-aqueous stream.

5260. The method of claim 5236, wherein the mixture is produced from a production well, the method further comprising heating a wellbore of the production well to inhibit condensation of the mixture within the wellbore.

5261. The method of claim 5236, wherein the mixture is produced from a production well, wherein a wellbore of the production well comprises a heater element configured to heat the permeable formation adjacent to the wellbore, and further comprising heating the permeable formation with the heater element to produce the mixture, wherein the mixture comprise non-condensable hydrocarbons and H₂.

5262. The method of claim 5236, wherein a minimum mobilization temperature is about 75°

C.

5263. The method of claim 5236, wherein a minimum pyrolysis temperature is about 270°

C.

5264. The method of claim 5236, further comprising maintaining the pressure within the permeable formation above about 2 bars absolute to inhibit production of fluids having carbon numbers above 25.

5265. The method of claim 5236, further comprising controlling pressure within the permeable formation in a range from about atmospheric pressure to about 100 bars absolute, as measured at a wellhead of a production well, to control an amount of condensable fluids within the mixture, wherein the pressure is reduced to increase production of condensable fluids, and wherein the pressure is increased to increase production of non-condensable fluids.

5266. The method of claim 5236, further comprising controlling pressure within the permeable formation in a range from about atmospheric pressure to about 100 bars absolute, as measured at a wellhead of a production well, to control an API gravity of condensable fluids within the mixture, wherein the pressure is reduced to decrease the API gravity, and wherein the pressure is increased to reduce the API gravity.

5267. The method of claim 5236, wherein mobilizing the hydrocarbons within the selected mobilization section comprises reducing a viscosity of the hydrocarbons.

5268. The method of claim 5236, wherein the provided gas comprises carbon dioxide.

5269. The method of claim 5236, wherein the provided gas comprises nitrogen.

5270. The method of claim 5236, further comprising controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled.

5271. The method of claim 5236, further comprising controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled, wherein the pressure of the provided gas is above about 2 bars absolute.

5272. The method of claim 5236, further comprising controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled, wherein the pressure of the provided gas is below about 100 bars absolute.

5273. A method of treating a hydrocarbon containing permeable formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the permeable formation;

allowing the heat to transfer from the one or more heaters to a selected mobilization section of the permeable formation such that the heat from the one or more heaters can mobilize at least some of the hydrocarbons within the selected mobilization section of the permeable formation;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected mobilization section of the permeable formation is less than about 150°

C.;

allowing the heat to transfer from the one or more heaters to a selected pyrolyzation section of the permeable formation such that the heat from the one or more heaters can pyrolyze at least some of the hydrocarbons within the selected pyrolyzation section of the permeable formation;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected pyrolyzation section of the permeable formation is less than about 375°

C.;

allowing at least some of the mobilized hydrocarbons to flow from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation;

providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation;

controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled; and

producing a mixture from the permeable formation.

5274. The method of claim 5273, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from the one or more heaters can mobilize at least some of the hydrocarbons within the selected mobilization section of the permeable formation.

5275. The method of claim 5273, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from the one or more heaters can pyrolyze at least some of the hydrocarbons within the selected pyrolyzation section of the permeable formation.

5276. The method of claim 5273, wherein the one or more heaters comprise electrical heaters.

5277. The method of claim 5273, wherein the one or more heaters comprise surface burners.

5278. The method of claim 5273, wherein the one or more heaters comprise flameless distributed combustors.

5279. The method of claim 5273, wherein the one or more heaters comprise natural distributed combustors.

5280. The method of claim 5273, further comprising disposing the one or more heaters horizontally within the permeable formation.

5281. The method of claim 5273, further comprising controlling a pressure and a temperature within at least a majority of the permeable formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

5282. The method of claim 5273, further comprising controlling the heat such that an average heating rate of the selected pyrolyzation section is less than about 15°

C./day during pyrolysis.

5283. The method of claim 5273, wherein providing heat from the one or more heaters to at least the portion of permeable formation comprises:

heating a selected volume (V) of the hydrocarbon containing permeable formation from the one or more heaters, wherein the formation has an average heat capacity(C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

5284. The method of claim 5273, wherein allowing the heat to transfer from the one or more heaters to the selected mobilization section and/or the selected pyrolyzation section comprises transferring heat substantially by conduction.

5285. The method of claim 5273, wherein producing the mixture from the permeable formation further comprises producing mixture having an API gravity of at least about 25°

.

5286. The method of claim 5273, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.5% by weight, of the condensable hydrocarbons, when calculated on an atomic basis, is nitrogen.

5287. The method of claim 5273, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 7% by weight, of the condensable hydrocarbons, when calculated on an atomic basis, is oxygen.

5288. The method of claim 5273, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight, of the condensable hydrocarbons, when calculated on an atomic basis, is sulfur.

5289. The method of claim 5273, further comprising controlling a pressure within at least a majority of the permeable formation, wherein the controlled pressure is at least about 2 bars absolute.

5290. The method of claim 5273, further comprising altering a pressure within the permeable formation to inhibit production of hydrocarbons from the permeable formation having carbon numbers greater than about 25.

5291. The method of claim 5273, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

5292. The method of claim 5273, wherein the produced mixture comprises condensable hydrocarbons and hydrogen, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

5293. The method of claim 5273, wherein producing the mixture from the permeable formation further comprises producing the mixture in a production well, wherein the heating is controlled such that the mixture can be produced from the permeable formation, and wherein at least about 4 heaters are disposed in the permeable formation for each production well.

5294. The method of claim 5273, wherein producing the mixture from the permeable formation further comprises producing the mixture in a production well, wherein the heating is controlled such that the mixture can be produced from the permeable formation, and wherein the production well is disposed substantially horizontally within the permeable formation.

5295. The method of claim 5273, further comprising separating the mixture into a gas stream and a liquid stream.

5296. The method of claim 5273, further comprising separating the mixture into a gas stream and a liquid stream and separating the liquid stream into an aqueous stream and a non-aqueous stream.

5297. The method of claim 5273, wherein the mixture is produced from a production well, the method further comprising heating a wellbore of the production well to inhibit condensation of the mixture within the wellbore.

5298. The method of claim 5273, wherein the mixture is produced from a production well, wherein a wellbore of the production well comprises a heater element configured to heat the permeable formation adjacent to the wellbore, and further comprising heating the permeable formation with the heater element to produce the mixture, wherein the mixture comprises non-condensable hydrocarbons and H₂.

5299. The method of claim 5273, wherein a minimum mobilization temperature is about 75°

C.

5300. The method of claim 5273, wherein a minimum pyrolysis temperature is about 270°

C.

5301. The method of claim 5273, further comprising maintaining the pressure within the permeable formation above about 2 bars absolute to inhibit production of fluids having carbon numbers above 25.

5302. The method of claim 5273, further comprising controlling pressure within the permeable formation in a range from about atmospheric pressure to about 100 bars absolute, as measured at a wellhead of a production well, to control an amount of condensable fluids within the mixture, wherein the pressure is reduced to increase production of condensable fluids, and wherein the pressure is increased to increase production of non-condensable fluids.

5303. The method of claim 5273, further comprising controlling pressure within the permeable formation in a range from about atmospheric pressure to about 100 bars absolute, as measured at a wellhead of a production well, to control an API gravity of condensable fluids within the mixture, wherein the pressure is reduced to decrease the API gravity, and wherein the pressure is increased to reduce the API gravity.

5304. The method of claim 5273, wherein mobilizing the hydrocarbons within the selected mobilization section comprises reducing a viscosity of the hydrocarbons.

5305. The method of claim 5273, wherein the provided gas comprises carbon dioxide.

5306. The method of claim 5273, wherein the provided gas comprises nitrogen.

5307. The method of claim 5273, wherein the pressure of the provided gas is above about 2 bars absolute.

5308. The method of claim 5273, wherein the pressure of the provided gas is below about 70 bars absolute.

5309. A method of treating a hydrocarbon containing permeable formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the permeable formation;

allowing the heat to transfer from the one or more heaters to a selected mobilization section of the permeable formation such that the heat from the one or more heaters can mobilize at least some of the hydrocarbons within the selected mobilization section of the permeable formation;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected mobilization section of the permeable formation is less than about 150°

C.;

allowing the heat to transfer from the one or more heaters to a selected pyrolyzation section of the permeable formation such that the heat from the one or more heaters can pyrolyze at least some of the hydrocarbons within the selected pyrolyzation section of the permeable formation;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected pyrolyzation section of the permeable formation is less than about 375°

C.; and

producing a mixture from the permeable formation in a production well, wherein the production well is disposed substantially horizontally within the permeable formation.

5310. The method of claim 5309, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from the one or more heaters can mobilize at least some of the hydrocarbons within the selected mobilization section of the permeable formation.

5311. The method of claim 5309, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from the one or more heaters can pyrolyze at least some of the hydrocarbons within the selected pyrolyzation section of the permeable formation.

5312. The method of claim 5309, wherein the one or more heaters comprise electrical heaters.

5313. The method of claim 5309, wherein the one or more heaters comprise surface burners.

5314. The method of claim 5309, wherein the one or more heaters comprise flameless distributed combustors.

5315. The method of claim 5309, wherein the one or more heaters comprise natural distributed combustors.

5316. The method of claim 5309, further comprising disposing the one or more heaters horizontally within the permeable formation.

5317. The method of claim 5309, further comprising controlling a pressure and a temperature within at least a majority of the permeable formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

5318. The method of claim 5309, further comprising controlling the heat such that an average heating rate of the selected pyrolyzation section is less than about 15°

C./day during pyrolysis.

5319. The method of claim 5309, wherein providing heat from the one or more heaters to at least the portion of permeable formation comprises:

heating a selected volume (V) of the hydrocarbon containing permeable formation from the one or more heaters, wherein the formation has an average heat capacity(C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

5320. The method of claim 5309, wherein allowing the heat to transfer from the one or more heaters to the selected mobilization section and/or the selected pyrolyzation section comprises transferring heat substantially by conduction.

5321. The method of claim 5309, wherein producing mixture from the permeable formation further comprises producing mixture having an API gravity of at least about 25°

.

5322. The method of claim 5309, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.5% by weight, of the condensable hydrocarbons, when calculated on an atomic basis, is nitrogen.

5323. The method of claim 5309, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 7% by weight, of the condensable hydrocarbons, when calculated on an atomic basis, is oxygen.

5324. The method of claim 5309, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight, of the condensable hydrocarbons, when calculated on an atomic basis, is sulfur.

5325. The method of claim 5309, further comprising controlling a pressure within at least a majority of the permeable formation, wherein the controlled pressure is at least about 2 bars absolute.

5326. The method of claim 5309, further comprising altering a pressure within the permeable formation to inhibit production of hydrocarbons from the permeable formation having carbon numbers greater than about 25.

5327. The method of claim 5309, further comprising:

providing hydrogen (H₂) to the heated section to hydrogenate hydrocarbons within the section; and

heating a portion of the section with heat from hydrogenation.

5328. The method of claim 5309, wherein the produced mixture comprises condensable hydrocarbons and hydrogen, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

5329. The method of claim 5309, wherein producing the mixture from the permeable formation further comprises producing the mixture in a production well, wherein the heating is controlled such that the mixture can be produced from the permeable formation, and wherein at least about 4 heaters are disposed in the permeable formation for each production well.

5330. The method of claim 5309, further comprising separating the mixture into a gas stream and a liquid stream.

5331. The method of claim 5309, further comprising separating the mixture into a gas stream and a liquid stream and separating the liquid stream into an aqueous stream and a non-aqueous stream.

5332. The method of claim 5309, wherein the mixture is produced from a production well, the method further comprising heating a wellbore of the production well to inhibit condensation of the mixture within the wellbore.

5333. The method of claim 5309, wherein the mixture is produced from a production well, wherein a wellbore of the production well comprises a heater element configured to heat the permeable formation adjacent to the wellbore, and further comprising heating the permeable formation with the heater element to produce the mixture, wherein the mixture comprises non-condensable hydrocarbons and H₂.

5334. The method of claim 5309, wherein a minimum mobilization temperature is about 75°

C.

5335. The method of claim 5309, wherein a minimum pyrolysis temperature is about 270°

C.

5336. The method of claim 5309, further comprising maintaining the pressure within the permeable formation above about 2 bars absolute to inhibit production of fluids having carbon numbers above 25.

5337. The method of claim 5309, further comprising controlling pressure within the permeable formation in a range from about atmospheric pressure to about 100 bars absolute, as measured at a wellhead of a production well, to control an amount of condensable fluids within the mixture, wherein the pressure is reduced to increase production of condensable fluids, and wherein the pressure is increased to increase production of non-condensable fluids.

5338. The method of claim 5309, further comprising controlling pressure within the permeable formation in a range from about atmospheric pressure to about 100 bars absolute, as measured at a wellhead of a production well, to control an API gravity of condensable fluids within the mixture, wherein the pressure is reduced to decrease the API gravity, and wherein the pressure is increased to reduce the API gravity.

5339. The method of claim 5309, wherein mobilizing the hydrocarbons within the selected mobilization section comprises reducing a viscosity of the hydrocarbons.

5340. The method of claim 5309, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation.

5341. The method of claim 5309, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation, and wherein the gas comprises carbon dioxide.

5342. The method of claim 5309, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation, and wherein the gas comprises nitrogen.

5343. The method of claim 5309, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation, the method further comprising controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled.

5344. The method of claim 5309, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation, the method further comprising controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled, wherein the pressure of the provided gas is above about 2 bars absolute.

5345. The method of claim 5309, further comprising providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons from the selected mobilization section of the permeable formation to the selected pyrolyzation section of the permeable formation, the method further comprising controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled, wherein the pressure of the provided gas is below about 70 bars absolute.

5346. A method of treating a hydrocarbon containing permeable formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the permeable formation;

allowing the heat to transfer from the one or more heaters to a selected mobilization section of the permeable formation such that the heat from the one or more heaters can mobilize at least some of the hydrocarbons within the selected mobilization section of the permeable formation;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected mobilization section of the permeable formation is less than about 150°

C.;

providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons within the permeable formation; and

producing a mixture from the permeable formation.

5347. The method of claim 5346, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from the one or more heaters can mobilize at least some of the hydrocarbons within the selected mobilization section of the permeable formation.

5348. The method of claim 5346, wherein the one or more heaters comprise electrical heaters.

5349. The method of claim 5346, wherein the one or more heaters comprise surface burners.

5350. The method of claim 5346, wherein the one or more heaters comprise flameless distributed combustors.

5351. The method of claim 5346, wherein the one or more heaters comprise natural distributed combustors.

5352. The method of claim 5346, further comprising disposing the one or more heaters horizontally within the permeable formation.

5353. The method of claim 5346, further comprising controlling a pressure and a temperature within at least a majority of the permeable formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

5354. The method of claim 5346, wherein providing heat from the one or more heaters to at least the portion of permeable formation comprises:

heating a selected volume (V) of the hydrocarbon containing permeable formation from the one or more heaters, wherein the formation has an average heat capacity(C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

5355. The method of claim 5346, wherein allowing the heat to transfer from the one or more heaters to the selected mobilization section comprises transferring heat substantially by conduction.

5356. The method of claim 5346, further comprising controlling a pressure within at least a majority of the permeable formation, wherein the controlled pressure is at least about 2 bars absolute.

5357. The method of claim 5346, wherein producing the mixture from the permeable formation further comprises producing the mixture in a production well, wherein the heating is controlled such that the mixture can be produced from the permeable formation, and wherein at least about 4 heaters are disposed in the permeable formation for each production well.

5358. The method of claim 5346, wherein producing the mixture from the permeable formation further comprises producing the mixture in a production well, wherein the heating is controlled such that the mixture can be produced from the permeable formation, and wherein the production well is disposed substantially horizontally within the permeable formation.

5359. The method of claim 5346, further comprising separating the mixture into a gas stream and a liquid stream.

5360. The method of claim 5346, further comprising separating the mixture into a gas stream and a liquid stream and separating the liquid stream into an aqueous stream and a non-aqueous stream.

5361. The method of claim 5346, wherein the mixture is produced from a production well, the method further comprising heating a wellbore of the production well to inhibit condensation of the mixture within the wellbore.

5362. The method of claim 5346, wherein the mixture is produced from a production well, wherein a wellbore of the production well comprises a heater element configured to heat the permeable formation adjacent to the wellbore, and further comprising heating the permeable formation with the heater element to produce the mixture, wherein the mixture comprise non-condensable hydrocarbons and H₂.

5363. The method of claim 5346, wherein a minimum mobilization temperature is about 75°

C.

5364. The method of claim 5346, wherein mobilizing the hydrocarbons within the selected mobilization section comprises reducing a viscosity of the hydrocarbons.

5365. The method of claim 5346, wherein the provided gas comprises carbon dioxide.

5366. The method of claim 5346, wherein the provided gas comprises nitrogen.

5367. The method of claim 5346, further comprising controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled.

5368. The method of claim 5346, further comprising controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled, wherein the pressure of the provided gas is above about 2 bars absolute.

5369. The method of claim 5346, further comprising controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled, wherein the pressure of the provided gas is below about 70 bars absolute.

5370. A method of treating a hydrocarbon containing permeable formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the permeable formation;

allowing the heat to transfer from the one or more heaters to a selected mobilization section of the permeable formation such that the heat from the one or more heaters can mobilize at least some of the hydrocarbons within the selected mobilization section of the permeable formation;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected mobilization section of the permeable formation is less than about 150°

C.;

providing a gas to the permeable formation, wherein the gas is configured to increase a flow of the mobilized hydrocarbons within the permeable formation;

controlling a pressure of the provided gas such that the flow of the mobilized hydrocarbons is controlled; and

producing a mixture from the permeable formation.

5371. The method of claim 5370, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from the one or more heaters can mobilize at least some of the hydrocarbons within the selected mobilization section of the permeable formation.

5372. The method of claim 5370, wherein the one or more heaters comprise electrical heaters.

5373. The method of claim 5370, wherein the one or more heaters comprise surface burners.

5374. The method of claim 5370, wherein the one or more heaters comprise flameless distributed combustors.

5375. The method of claim 5370, wherein the one or more heaters comprise natural distributed combustors.

5376. The method of claim 5370, further comprising disposing the one or more heaters horizontally within the permeable formation.

5377. The method of claim 5370, further comprising controlling a pressure and a temperature within at least a majority of the permeable formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

5378. The method of claim 5370, wherein providing heat from the one or more heaters to at least the portion of permeable formation comprises:

heating a selected volume (V) of the hydrocarbon containing permeable formation from the one or more heaters, wherein the formation has an average heat capacity(C_v), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and

wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C_v*ρ

_B, wherein ρ

_B is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10°

C./day.

5379. The method of claim 5370, wherein allowing the heat to transfer from the one or more heaters to the selected mobilization section comprises transferring heat substantially by conduction.

5380. The method of claim 5370, further comprising controlling a pressure within at least a majority of the permeable formation, wherein the controlled pressure is at least about 2 bars absolute.

5381. The method of claim 5370, wherein producing the mixture from the permeable formation further comprises producing the mixture in a production well, wherein the heating is controlled such that the mixture can be produced from the permeable formation, and wherein at least about 4 heaters are disposed in the permeable formation for each production well.

5382. The method of claim 5370, wherein producing the mixture from the permeable formation further comprises producing the mixture in a production well, wherein the heating is controlled such that the mixture can be produced from the permeable formation, and wherein the production well is disposed substantially horizontally within the permeable formation.

5383. The method of claim 5370, further comprising separating the mixture into a gas stream and a liquid stream.

5384. The method of claim 5370, further comprising separating the mixture into a gas stream and a liquid stream and separating the liquid stream into an aqueous stream and a non-aqueous stream.

5385. The method of claim 5370, wherein the mixture is produced from a production well, the method further comprising heating a wellbore of the production well to inhibit condensation of the mixture within the wellbore.

5386. The method of claim 5370, wherein the mixture is produced from a production well, wherein a wellbore of the production well comprises a heater element configured to heat the permeable formation adjacent to the wellbore, and further comprising heating the permeable formation with the heater element to produce the mixture, wherein the mixture comprise non-condensable hydrocarbons and H₂.

5387. The method of claim 5370, wherein a minimum mobilization temperature is about 75°

C.

5388. The method of claim 5370, wherein mobilizing the hydrocarbons within the selected mobilization section comprises reducing a viscosity of the hydrocarbons.

5389. The method of claim 5370, wherein the provided gas comprises carbon dioxide.

5390. The method of claim 5370, wherein the provided gas comprises nitrogen.

5391. The method of claim 5370, wherein the pressure of the provided gas is above about 2 bars absolute.

5392. The method of claim 5370, wherein the pressure of the provided gas is below about 70 bars absolute.

5393. A method for treating hydrocarbons in at least a portion of a hydrocarbon containing formation, wherein the portion has an average permeability of less than about 10 millidarcy, comprising:

providing heat from one or more heaters to the formation;

allowing the heat to transfer from one or more of the heaters to a selected section of the formation such that heat from the heaters pyrolyzes at least some hydrocarbons within the selected section, and wherein heat from the heaters increases the permeability of at least a portion of the selected section; and

producing a mixture comprising hydrocarbons from the formation.

5394. The method of claim 5393, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation, and wherein superposition of heat from at least the two heaters increases the permeability of at least the portion of the selected section.

5395. The method of claim 5393, further comprising allowing heat to transfer from at least one of the heaters to the selected section to create thermal fractures in the formation wherein the thermal fractures substantially increase the permeability of the selected section.

5396. The method of claim 5393, wherein the heat is provided such that an average temperature in the selected section ranges from approximately about 270°

C. to about 375°

C.

5397. The method of claim 5393, wherein at least one of the heaters comprises an electrical heater located in the formation.

5398. The method of claim 5393, wherein at least one of the heaters is located in a heater well, and wherein at least one of the heater wells comprises a conduit located in the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.

5399. The method of claim 5393, wherein at least some of the heaters are arranged in a triangular pattern.

5400. The method of claim 5393, further comprising:

monitoring a composition of the produced mixture; and

controlling a pressure in at least a portion of the formation to control the composition of the produced mixture.

5401. The method of claim 5400, wherein the pressure is controlled by a valve proximate to a location where the mixture is produced.

5402. The method of claim 5400, wherein the pressure is controlled such that pressure proximate to one or more of the heaters is greater than a pressure proximate to a location where the fluid is produced.

5403. The method of claim 5393, wherein an average distance between heaters is between about 2 m and about 8 m.

5404. A method for treating hydrocarbons in at least a portion of a hydrocarbon containing formation, wherein the portion has an average permeability of less than about 10 millidarcy, comprising:

providing heat from one or more heaters to the formation;

allowing the heat to transfer from one or more of the heaters to a selected section of the formation such that heat from the heaters pyrolyzes at least some hydrocarbons within the selected section, and wherein heat from the heaters vaporizes at least a portion of the hydrocarbons in the selected section; and

producing a mixture comprising hydrocarbons from the formation.

5405. The method of claim 5404, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation, and wherein superposition of heat from at least the two heaters vaporizes at least the portion of the hydrocarbons in the selected section.

5406. The method of claim 5404, further comprising allowing heat to transfer from at least one of the heaters to the selected section to create thermal fractures in the formation, wherein the thermal fractures substantially increase the permeability of the selected section.

5407. The method of claim 5404, wherein the heat is provided such that an average temperature in the selected section ranges from approximately about 270°

C. to about 375°

C.

5408. The method of claim 5404, wherein at least one of the heaters comprises an electrical heater located in the formation.

5409. The method of claim 5404, wherein at least one of the heaters is located in a heater well, and wherein at least one of the heater wells comprises a conduit located in the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.

5410. The method of claim 5404, wherein at least some of the heaters are arranged in a triangular pattern.

5411. The method of claim 5404, further comprising:

monitoring a composition of the produced mixture; and

controlling a pressure in at least a portion of the formation to control the composition of the produced mixture.

5412. The method of claim 5411, wherein the pressure is controlled by a valve proximate to a location where the mixture is produced.

5413. The method of claim 5411, wherein the pressure is controlled such that pressure proximate to one or more of the heaters is greater than a pressure proximate to a location where the mixture is produced.

5414. The method of claim 5404, wherein an average distance between heaters is between about 2 m and about 8 m.

5415. A method for treating hydrocarbons in at least a portion of a hydrocarbon containing formation, wherein the portion has an average permeability of less than about 10 millidarcy, comprising:

providing heat from one or more heaters to the formation, wherein at least one of the heaters is located in a heater well;

allowing the heat to transfer from one or more of the heaters to a selected section of the formation such that heat from the heaters pyrolyzes at least some hydrocarbons within the selected section, and wherein heat from the heaters pressurizes at least a portion of the selected section; and

producing a mixture comprising hydrocarbons from the formation, wherein the mixture is produced from one or more heater wells.

5416. The method of claim 5415, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

5417. The method of claim 5415, further comprising producing fluid from at least one heater well in which is positioned the heater of the one or more heaters.

5418. The method of claim 5415, further comprising allowing heat to transfer from at least one of the heaters to the selected section to create thermal fractures in the formation, wherein the thermal fractures substantially increase the permeability of the selected section.

5419. The method of claim 5415, wherein the heat is provided such that an average temperature in the selected section ranges from approximately about 270°

C. to about 375°

C.

5420. The method of claim 5415, wherein at least one of the heaters comprises an electrical heater located in the formation.

5421. The method of claim 5415, wherein at least one of the heaters is located in a heater well, and wherein at least one of the heater wells comprises a conduit located in the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.

5422. The method of claim 5415, wherein at least some of the heaters are arranged in a triangular pattern.

5423. The method of claim 5415, further comprising:

monitoring a composition of the produced mixture; and

controlling a pressure in at least a portion of the formation to control the composition of the produced mixture.

5424. The method of claim 5423, wherein the pressure is controlled by a valve proximate to a location where the mixture is produced.

5425. The method of claim 5423, wherein the pressure is controlled such that pressure proximate to one or more of the heaters is greater than a pressure proximate to a location where the mixture is produced.

5426. The method of claim 5415 wherein an average distance between heaters is between about 2 m and about 8 m.

5427. A method for treating hydrocarbons in at least a portion of a hydrocarbon containing formation, wherein the portion has an average permeability of less than about 10 millidarcy, comprising:

providing heat from one or more heaters to the formation;

allowing the heat to transfer from one or more of the heaters to a selected first section of the formation such that heat from the heaters creates a pyrolysis zone wherein at least some hydrocarbons are pyrolyzed within the first selected section, and allowing the heat to transfer from one or more of the heaters to a selected second section of the formation such that heat from the heaters heats at least some hydrocarbons within the selected second section to a temperature less than the average temperature within the pyrolysis zone; and

producing a mixture comprising hydrocarbons from the formation.

5428. The method of claim 5427, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from the at least two heaters pyrolyzes at least some hydrocarbons within the selected first section of the formation, and wherein superposition of heat from the at least two heaters heats at least some hydrocarbons within the selected second section to a temperature less than the average temperature within the pyrolysis zone.

5429. The method of claim 5427, wherein at least some heated hydrocarbons within the selected second section flow into the pyrolysis zone.

5430. The method of claim 5427, wherein the heat decreases the viscosity of at least some of the hydrocarbons in the selected second section.

5431. The method of claim 5427, further comprising allowing heat to transfer from at least one of the heaters to the selected first section to create thermal fractures in the formation, wherein the thermal fractures substantially increase the permeability of the selected first section.

5432. The method of claim 5427, further comprising allowing heat to transfer from at least one of the heaters to the selected second section to create thermal fractures in the formation, wherein the thermal fractures substantially increase the permeability of the selected second section.

5433. The method of claim 5427, wherein the heat is provided such that an average temperature in the selected first section ranges from approximately about 270°

C. to about 375°

C.

5434. The method of claim 5427, wherein the heat is provided such that an average temperature in the selected second section ranges from approximately about 180°

C. to about 250°

C.

5435. The method of claim 5427, wherein a viscosity of at least some of the hydrocarbons in the selected second section ranges from approximately about 20 centipoise to about 1000 centipoise.

5436. The method of claim 5427, wherein at least one of the heaters comprises an electrical heater located in the formation.

5437. The method of claim 5427, wherein at least one of the heaters is located in a heater well, and wherein at least one of the heater wells comprises a conduit located in the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.

5438. The method of claim 5427, further comprising:

monitoring a composition of the produced mixture; and

controlling a pressure in at least a portion of the formation to control the composition of the produced mixture.

5439. The method of claim 5438, wherein the pressure is controlled by a valve proximate to a location where the mixture is produced.

5440. The method of claim 5438, wherein the pressure is controlled such that pressure proximate to one or more of the heaters is greater than a pressure proximate to a location where the fluid is produced.

5441. The method of claim 5427, wherein the pressure in the selected second section is substantially greater than the pressure in the selected first section.

5442. The method of claim 5427, wherein at least some of the heaters are arranged in a triangular pattern.

5443. The method of claim 5427, wherein an average distance between heaters in the selected first section is less than an average distance between heaters in the selected second section.

5444. The method of claim 5427, wherein the heat is provided to the selected first section before heat is provided to the selected second section.

5445. The method of claim 5427, wherein the selected first section comprises at least one production well.

5446. The method of claim 5427, wherein an average distance between heaters in the selected first section is between about 2 m and about 10 m.

5447. The method of claim 5427, wherein an average distance between heaters in the selected second section is between about 5 m and about 20 m.

5448. The method of claim 5427, wherein the selected first section comprises a planar region.

5449. The method of claim 5427, wherein at least one row of the heaters provides heat to the planar region.

5450. The method of claim 5449 wherein a length of a row is between about 75 m and about 125 m.

5451. The method of claim 5448, wherein the planar region comprises a vertical hydraulic fracture.

5452. The method of claim 5451, wherein a width of the vertical hydraulic fracture is between about 0.3 cm and about 2.5 cm.

5453. The method of claim 5451, wherein a length of the vertical hydraulic fracture is between about 75 m and about 125 m.

5454. The method of claim 5427, wherein at least one ring comprising the heaters provides heat to the selected first section.

5455. The method of claim 5454, wherein at least one ring comprising the heaters provides heat to the selected second section.

5456. The method of claim 5454, wherein the ring comprises a polygon.

5457. The method of claim 5454, wherein the ring comprises a regular polygon.

5458. The method of claim 5454, wherein the ring comprises a hexagon.

5459. The method of claim 5454, wherein the ring comprises a triangle.

5460. A method for treating hydrocarbons in at least a portion of a hydrocarbon containing formation, wherein the portion has an average permeability of less than about 10 millidarcy, comprising:

providing heat from three or more heaters to the formation;

allowing the heat to transfer from three or more of the heaters to a selected section of the formation such that heat from the heaters pyrolyzes at least some hydrocarbons within the selected section, and at least three of the heaters are arranged in a substantially triangular pattern; and

producing a mixture comprising hydrocarbons from the formation.

5461. The method of claim 5460, wherein superposition of heat from at least the three heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

5462. The method of claim 5460, wherein the mixture is produced from a production well located in a triangular region created by at least three heaters.

5463. The method of claim 5460, further comprising allowing heat to transfer from at least one of the heaters to the selected section to create thermal fractures in the formation, wherein the thermal fractures substantially increase the permeability of the selected section.

5464. The method of claim 5460, wherein the heat is provided such that an average temperature in the selected section ranges from approximately about 270°

C. to about 375°

C.

5465. The method of claim 5460, wherein at least one of the heaters comprises a electrical heater located in the formation.

5466. The method of claim 5460, wherein at least one of the heaters is located in a heater well, and wherein at least one of the heater wells comprises a conduit located in the formation, and further comprising heating the conduit by flowing a hot fluid through the conduit.

5467. The method of claim 5460, wherein at least some of the heaters are arranged in a triangular pattern.

5468. The method of claim 5460, further comprising:

monitoring a composition of the produced mixture; and

controlling a pressure in at least a portion of the formation to control the composition of the produced mixture.

5469. The method of claim 5468, wherein the pressure is controlled by a valve proximate to a location where the mixture is produced.

5470. The method of claim 5468, wherein the pressure is controlled such that pressure proximate to one or more of the heaters is greater than a pressure proximate to a location where the fluid is produced.

5471. The method of claim 5460, wherein an average distance between heaters is between about 2 m and about 8 m.

5472. A system configurable to heat a hydrocarbon containing formation, comprising:

a conduit configurable to be placed within an opening in the formation;

a conductor configurable to be placed within the conduit, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use;

at least one centralizer configurable to be coupled to the conductor, wherein at least one centralizer inhibits movement of the conductor within the conduit during use; and

wherein the system is configurable to allow heat to transfer from the conductor to a section of the formation during use.

5473. The system of claim 5472, wherein at least one centralizer comprises electrically-insulating material.

5474. The system of claim 5472, wherein at least one centralizer is configurable to inhibit arcing between the conductor and the conduit.

5475. The system of claim 5472, wherein at least one centralizer comprises ceramic material.

5476. The system of claim 5472, wherein at least one centralizer comprises at least one recess, wherein at least one recess is placed at a junction of at least one centralizer and the first conductor, wherein at least one protrusion is formed on the first conductor at the junction to maintain a location of at least one centralizer on the first conductor, and wherein at least one protrusion resides substantially within at least one recess.

5477. The system of claim 5476, wherein at least one protrusion comprises a weld.

5478. The system of claim 5476, wherein an electrically-insulating material substantially covers at least one recess.

5479. The system of claim 5476, wherein a thermal plasma applied coating substantially covers at least one recess.

5480. The system of claim 5476, wherein a thermal plasma applied coating comprises alumina.

5481. The system of claim 5472, wherein the system is further configurable to allow at least some hydrocarbons to pyrolyze in the heated section of the formation during use.

5482. The system of claim 5472, further comprising an insulation layer configurable to be coupled to at least a portion of the conductor or at least one centralizer.

5483. The system of claim 5472, wherein at least one centralizer comprises a neck portion.

5484. The system of claim 5472, wherein at least one centralizer comprises one or more grooves.

5485. The system of claim 5472, wherein at least one centralizer comprises at least two portions, and wherein the portions are configurable to be coupled to the conductor to form at least one centralizer placed on the conductor.

5486. The system of claim 5472, wherein a thickness of the conductor is greater adjacent to a lean zone in the formation than a thickness of the conductor adjacent to a rich zone in the formation such that more heat is provided to the rich zone.

5487. The system of claim 5472, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

a conduit configured to be placed within an opening in the formation;

a conductor configured to be placed within the conduit, wherein the conductor is further configured to provide heat to at least a portion of the formation during use;

at least one centralizer configured to be coupled to the conductor, wherein at least one centralizer inhibits movement of the conductor within the conduit during use; and

wherein the system is configured to allow heat to transfer from the conductor to a section of the formation during use.

5488. The system of claim 5472, wherein the system heats a hydrocarbon containing formation, and wherein the system comprises:

a conduit placed within an opening in the formation;

a conductor placed within the conduit, wherein the conductor provides heat to at least a portion of the formation;

at least one centralizer coupled to the conductor, wherein at least one centralizer inhibits movement of the conductor within the conduit; and

wherein the system allows heat to transfer from the conductor to a section of the formation.

5489. The system of claim 5472, wherein the system is configurable to be removed from the opening in the formation.

5490. The system of claim 5472, further comprising a moveable thermocouple.

5491. The system of claim 5472, further comprising an isolation block.

5492. A system configurable to heat a hydrocarbon containing formation, comprising:

a conduit configurable to be placed within an opening in the formation;

a conductor configurable to be placed within the conduit, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use;

at least one centralizer configurable to be coupled to the conductor, wherein at least one centralizer inhibits movement of the conductor within the conduit during use

wherein the system is configurable to allow heat to transfer from the conductor to a section of the formation during use; and

wherein the system is configurable to be removed from the opening in the formation.

5493. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to a conductor to provide heat to at least a portion of the formation, wherein the conductor is placed within a conduit, wherein at least one centralizer is coupled to the conductor to inhibit movement of the conductor within the conduit, and wherein the conduit is placed within an opening in the formation; and

allowing the heat to transfer from the first conductor to a section of the formation.

5494. The method of claim 5493, further comprising pyrolyzing at least some hydrocarbons in the section of the formation.

5495. The method of claim 5493, further comprising inhibiting arcing between the conductor and the conduit.

5496. A system configurable to heat a hydrocarbon containing formation, comprising:

a conduit configurable to be placed within an opening in the formation;

a conductor configurable to be placed within a conduit, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use;

an insulation layer coupled to at least a portion of the conductor, wherein the insulation layer electrically insulates at least a portion of the conductor from the conduit during use; and

wherein the system is configurable to allow heat to transfer from the conductor to a section of the formation during use

5497. The system of claim 5496, wherein the insulation layer comprises a spiral insulation layer.

5498. The system of claim 5496, wherein the insulation layer comprises at least one metal oxide.

5499. The system of claim 5496, wherein the insulation layer comprises at least one alumina oxide.

5500. The system of claim 5496, wherein the insulation layer is configurable to be fastened to the conductor with a high temperature glue.

5501. The system of claim 5496, wherein the system is further configurable to allow at least some hydrocarbons to pyrolyze in the heated section of the formation during use.

5502. The system of claim 5496, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

a conduit configured to be placed within an opening in the formation;

a conductor configured to be placed within a conduit, wherein the conductor is further configured to provide heat to at least a portion of the formation during use;

an insulation layer coupled to at least a portion of the conductor, wherein the insulation layer electrically insulates at least a portion of the conductor from the conduit during use; and

wherein the system is configured to allow heat to transfer from the conductor to a section of the formation during use.

5503. The system of claim 5496, wherein the system heats a hydrocarbon containing formation, and wherein the system comprises:

a conduit placed within an opening in the formation;

a conductor placed within a conduit, wherein the conductor provides heat to at least a portion of the formation;

an insulation layer coupled to at least a portion of the conductor, wherein the insulation layer electrically insulates at least a portion of the conductor from the conduit; and

wherein the system allows heat to transfer from the conductor to a section of the formation.

5504. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to a conductor to provide heat to at least a portion of the formation, wherein the conductor is placed within a conduit, wherein an insulation layer is coupled to at least a portion of the conductor to electrically insulate at least a portion of the conductor from the conduit, and wherein the conduit is placed within an opening in the formation; and

allowing the heat to transfer from the first conductor to a section of the formation.

5505. The method of claim 5504, further comprising pyrolyzing at least some hydrocarbons in the section of the formation.

5506. The method of claim 5504, further comprising inhibiting arcing between the conductor and the conduit.

5507. A method for making a conductor-in-conduit heater for a hydrocarbon containing formation, comprising:

placing at least one protrusion on a conductor;

placing at least one centralizer on the conductor; and

placing the conductor within a conduit to form a conductor-in-conduit heater, wherein at least one centralizer maintains a location of the conductor within the conduit.

5508. The method of claim 5507, wherein at least one centralizer comprises at least two portions, and wherein the portions are coupled to the conductor to form at least one centralizer placed on the conductor.

5509. The method of claim 5507, further comprising placing the conductor-in-conduit heater in an opening in a hydrocarbon containing formation.

5510. The method of claim 5507, further comprising coupling an insulation layer on the conductor, wherein the insulation layer is configured to electrically insulate at least a portion of the conductor from the conduit.

5511. The method of claim 5507, further comprising providing heat from the conductor-in-conduit heater to at least a portion of the formation.

5512. The method of claim 5507, further comprising pyrolyzing at least some hydrocarbons in a selected section of the formation.

5513. The method of claim 5507, further comprising producing a mixture from a selected section of the formation.

5514. The method of claim 5507, wherein the conductor-in-conduit heater is configurable to provide heat to the hydrocarbon containing formation.

5515. The method of claim 5507, wherein at least one centralizer comprises at least one recess placed at a junction of at least one centralizer on the conductor, and wherein at least one protrusion resides substantially within at least one recess.

5516. The method of claim 5515, further comprising at least partially covering at least one recess with an electrically-insulating material.

5517. The method of claim 5515, further comprising spraying an electrically-insulating material to at least partially cover at least one recess.

5518. The method of claim 5507, wherein placing at least one protrusion on the conductor comprises welding at least one protrusion on the conductor.

5519. The method of claim 5507, further comprising coiling the conductor-in-conduit heater on a spool after forming the heater.

5520. The method of claim 5507, further comprising uncoiling the heater from the spool while placing the heater in an opening in the formation.

5521. The method of claim 5507, wherein placing the conductor within a conduit comprises placing the conductor within a conduit that has been placed in an opening in the formation.

5522. The method of claim 5507, further comprising coupling the conductor-in-conduit heater to at least one additional conductor-in-conduit heater.

5523. The method of claim 5507, wherein the conductor-in-conduit heater is configurable to be installed into an opening in a hydrocarbon containing formation.

5524. The method of claim 5507, wherein the conductor-in-conduit heater is configurable to be removed from an opening in a hydrocarbon containing formation.

5525. The method of claim 5507, wherein the conductor-in-conduit heater is configurable to heat to a section of the hydrocarbon containing formation, and wherein the heat pyrolyzes at least some hydrocarbons in the section of the formation during use.

5526. The method of claim 5507, wherein a thickness of the conductor configurable to be placed adjacent to a lean zone in the formation is greater than a thickness of the conductor configurable to be placed adjacent to a rich zone in the formation such that more heat is provided to the rich zone during use.

5527. A method of installing a conductor-in-conduit heater of a desired length in a hydrocarbon containing formation, comprising:

assembling a conductor-in-conduit heater of a desired length, comprising;

placing a conductor within a conduit to form a conductor-in-conduit heater; and

coupling the conductor-in-conduit heater to at least one additional conductor-in-conduit heater to form a conductor-in-conduit heater of the desired length, wherein the conductor is electrically coupled to the conductor of at least one additional conductor-in-conduit heater and the conduit is electrically coupled to the conduit of at least one additional conductor-in-conduit heater;

coiling the conductor-in-conduit heater of the desired length after forming the heater; and

placing the conductor-in-conduit heater of the desired length in an opening in a hydrocarbon containing formation.

5528. The method of claim 5527, wherein the conductor-in-conduit heater is configurable to provide heat to the hydrocarbon containing formation.

5529. The method of claim 5527, wherein the conductor-in-conduit heater of the desired length is removable from the opening in the hydrocarbon containing formation.

5530. The method of claim 5527, further comprising uncoiling the conductor-in-conduit heater of the desired length while placing the heater in the opening.

5531. The method of claim 5527, further comprising placing at least one centralizer on the conductor.

5532. The method of claim 5527, further comprising placing at least one centralizer on the conductor, wherein at least one centralizer inhibits movement of the conductor within the conduit.

5533. The method of claim 5527, further comprising placing an insulation layer on at least a portion of the conductor.

5534. The method of claim 5527, further comprising coiling the conductor-in-conduit heater.

5535. The method of claim 5527, further comprising testing the conductor-in-conduit heater and coiling the heater.

5536. The method of claim 5527, wherein coupling the conductor-in-conduit heater to at least one additional conductor-in-conduit heater comprises welding the conductor-in-conduit heater to at least one additional conductor-in-conduit heater.

5537. The method of claim 5527, wherein coupling the conductor-in-conduit heater to at least one additional conductor-in-conduit heater comprises shielded active gas welding the conductor-in-conduit heater to at least one additional conductor-in-conduit heater.

5538. The method of claim 5527, wherein coupling the conductor-in-conduit heater to at least one additional conductor-in-conduit heater comprises shielded active gas welding the conductor-in-conduit heater to at least one additional conductor-in-conduit heater, and wherein using shielded active gas welding inhibits changes in the grain structure of the conductor or conduit during coupling.

5539. The method of claim 5527, wherein the assembling of the conductor-in-conduit heater of the desired length is performed at a location proximate the hydrocarbon containing formation.

5540. The method of claim 5527, wherein the assembling of the conductor-in-conduit heater of the desired length takes place sufficiently proximate the hydrocarbon containing formation such that the conductor-in-conduit heater can be placed directly in an opening of the formation after the heater is assembled.

5541. The method of claim 5527, further comprising coupling at least one substantially low resistance conductor to the conductor-in-conduit heater of the desired length, wherein at least one substantially low resistance conductor is configured to be placed in an overburden of the formation.

5542. The method of claim 5541, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor.

5543. The method of claim 5541, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor, wherein coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor comprises coupling a threaded end of at least one additional substantially low resistance conductor to a threaded end of at least one substantially low resistance conductor.

5544. The method of claim 5541, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor, wherein coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor comprises welding at least one additional substantially low resistance conductor to at least one substantially low resistance conductor.

5545. The method of claim 5541, wherein at least one substantially low resistance conductor is coupled to the conductor-in-conduit heater of the desired length during assembling of the heater of the desired length.

5546. The method of claim 5541, wherein at least one substantially low resistance conductor is coupled to the conductor-in-conduit heater of the desired length after assembling of the heater of the desired length.

5547. The method of claim 5527, further comprising transporting the coiled conductor-in-conduit heater of the desired length on a cart or train from an assembly location to the opening in the hydrocarbon containing formation.

5548. The method of claim 5547, wherein the cart or train can be further used to transport more than one conductor-in-conduit heater of the desired length to more than one opening in the hydrocarbon containing formation.

5549. The method of claim 5527, wherein the desired length comprises a length determined for using the conductor-in-conduit heater in a selected opening in the hydrocarbon containing formation.

5550. The method of claim 5527, further comprising treating the conductor to increase an emissivity of the conductor.

5551. The method of claim 5550, wherein treating the conductor comprises roughening the surface of the conductor.

5552. The method of claim 5550, wherein treating the conductor comprises heating the conductor to a temperature above about 750°

C. in an oxidizing fluid atmosphere.

5553. The method of claim 5527, further comprising treating the conduit to increase an emissivity of the conduit.

5554. The method of claim 5527, further comprising coating at least a portion of the conductor or at least a portion of the conduit during assembly of the conductor-in-conduit heater.

5555. The method of claim 5527, further comprising placing an insulation layer on at least a portion of the conductor-in-conduit heater prior to placing the heater in the opening in the hydrocarbon containing formation.

5556. The method of claim 5555, wherein the insulation layer comprises a spiral insulation layer.

5557. The method of claim 5555, wherein the insulation layer comprises at least one metal oxide.

5558. The method of claim 5555, further comprising fastening at least a portion of the insulation layer to at least a portion of the conductor-in-conduit heater with a high temperature glue.

5559. The method of claim 5527, further comprising providing heat from the conductor-in-conduit heater of the desired length to at least a portion of the formation.

5560. The method of claim 5527, wherein a thickness of the conductor configurable to be placed adjacent to a lean zone in the formation is greater than a thickness of the conductor configurable to be placed adjacent to a rich zone in the formation such that more heat is provided to the rich zone during use

5561. The method of claim 5527, further comprising pyrolyzing at least some hydrocarbons in a selected section of the formation.

5562. The method of claim 5527, further comprising producing a mixture from a selected section of the formation.

5563. A method for making a conductor-in-conduit heater configurable to be used to heat a hydrocarbon containing formation, comprising:

placing a conductor within a conduit to form a conductor-in-conduit heater; and

shielded active gas welding the conductor-in-conduit heater to at least one additional conductor-in-conduit heater to form a conductor-in-conduit heater of a desired length, wherein the conductor is electrically coupled to the conductor of at least one additional conductor-in-conduit heater and the conduit is electrically coupled to the conduit of at least one additional conductor-in-conduit heater; and

wherein the conductor-in-conduit heater is configurable to be placed in an opening in the hydrocarbon containing formation, and wherein the conductor-in-conduit heater is further configurable to heat a section of the hydrocarbon containing formation during use.

5564. The method of claim 5563, further comprising providing heat from the conductor-in-conduit heater of the desired length to at least a portion of the formation.

5565. The method of claim 5563, further comprising pyrolyzing at least some hydrocarbons in a selected section of the formation.

5566. The method of claim 5563, further comprising producing a mixture from a selected section of the formation.

5567. The method of claim 5563, wherein the conductor and the conduit comprise stainless steel.

5568. The method of claim 5563, wherein the conduit comprises stainless steel.

5569. The method of claim 5563, wherein the heater is configurable to be removed from the formation.

5570. The method of claim 5563, further comprising providing a reducing gas during welding.

5571. The method of claim 5563, wherein the reducing gas comprises molecular hydrogen.

5572. The method of claim 5563, further comprising providing a reducing gas during welding such that welding occurs in an environment comprising less than about 25% reducing gas by volume.

5573. The method of claim 5563, further comprising providing a reducing gas during welding such that welding occurs in an environment comprising about 10% reducing gas by volume.

5574. A system configurable to heat a hydrocarbon containing formation, comprising:

a conduit configurable to be placed within an opening in the formation;

a conductor configurable to be placed within the conduit, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use, and wherein the conductor comprises at least two conductor sections coupled by shielded active gas welding; and

wherein the system is configurable to allow heat to transfer from the conductor to a section of the formation during use.

5575. The system of claim 5574, wherein the conduit comprises at least two conduit sections coupled by shielded active gas welding.

5576. The system of claim 5574, wherein the system is further configurable to allow at least some hydrocarbons to pyrolyze in the heated section of the formation during use.

5577. The system of claim 5574, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

a conduit configured to be placed within an opening in the formation;

a conductor configured to be placed within the conduit, wherein the conductor is further configured to provide heat to at least a portion of the formation during use, and wherein the conductor comprises at least two conductor sections coupled by shielded active gas welding; and

wherein the system is configured to allow heat to transfer from the conductor to a section of the formation during use.

5578. The system of claim 5574, wherein the system heats a hydrocarbon containing formation, and wherein the system comprises:

a conduit placed within an opening in the formation;

a conductor placed within the conduit, wherein the conductor provides heat to at least a portion of the formation during use, and wherein the conductor comprises at least two conductor sections coupled by shielded active gas welding; and

wherein the system allows heat to transfer from the conductor to a section of the formation during use.

5579. The system of claim 5574, wherein the conductor-in-conduit heater is configurable to be removed from the formation.

5580. A method for installing a heater of a desired length in a hydrocarbon containing formation, comprising:

assembling a heater of a desired length, wherein the assembling of the heater of the desired length is performed at a location proximate the hydrocarbon containing formation;

coiling the heater of the desired length after forming the heater; and

placing the heater of the desired length in an opening in a hydrocarbon containing formation, wherein placing the heater in the opening comprises uncoiling the heater while placing the heater in the opening.

5581. The method of claim 5580, wherein the heater is configurable to heat a section of the hydrocarbon containing formation.

5582. The method of claim 5581, wherein the heat pyrolyzes at least some hydrocarbons in the section of the formation during use.

5583. The method of claim 5580, further comprising coupling at least one substantially low resistance conductor to the heater of the desired length, wherein at least one substantially low resistance conductor is configured to be placed in an overburden of the formation.

5584. The method of claim 5583, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor.

5585. The method of claim 5583, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor, wherein coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor comprises coupling a threaded end of at least one additional substantially low resistance conductor to a threaded end of at least one substantially low resistance conductor.

5586. The method of claim 5583, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor, wherein coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor comprises welding at least one additional substantially low resistance conductor to at least one substantially low resistance conductor.

5587. The method of claim 5580, further comprising transporting the heater of the desired length on a cart or train from an assembly location to the opening in the hydrocarbon containing formation.

5588. The method of claim 5587, wherein the cart or train can be further used to transport more than one heater to more than one opening in the hydrocarbon containing formation.

5589. The method of claim 5587, wherein the heater is configurable to removable from the opening.

5590. A method for installing a heater of a desired length in a hydrocarbon containing formation, comprising:

assembling a heater of a desired length, wherein the assembling of the heater of the desired length is performed at a location proximate the hydrocarbon containing formation;

coiling the heater of the desired length after forming the heater;

placing the heater of the desired length in an opening in a hydrocarbon containing formation, wherein placing the heater in the opening comprises uncoiling the heater while placing the heater in the opening; and

wherein the heater is configurable to be removed from the opening.

5591. The method of claim 5590, wherein the heater is configurable to heat a section of the hydrocarbon containing formation.

5592. The method of claim 5591, wherein the heat pyrolyzes at least some hydrocarbons in the section of the formation during use.

5593. The method of claim 5590, further comprising coupling at least one substantially low resistance conductor to the heater of the desired length, wherein at least one substantially low resistance conductor is configured to be placed in an overburden of the formation.

5594. The method of claim 5593, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor.

5595. The method of claim 5593, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor, wherein coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor comprises coupling a threaded end of at least one additional substantially low resistance conductor to a threaded end of at least one substantially low resistance conductor.

5596. The method of claim 5593, further comprising coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor, wherein coupling at least one additional substantially low resistance conductor to at least one substantially low resistance conductor comprises welding at least one additional substantially low resistance conductor to at least one substantially low resistance conductor.

5597. The method of claim 5590, further comprising transporting the heater of the desired length on a cart or train from an assembly location to the opening in the hydrocarbon containing formation.

5598. The method of claim 5590, wherein removing the heater comprises recoiling the heater.

5599. The method of claim 5590, wherein the heater can be removed from the opening and installed in an alternate opening in the formation.

5600. A system configurable to heat a hydrocarbon containing formation, comprising:

a conduit configurable to be placed within an opening in the formation;

a conductor configurable to be placed within a conduit, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use;

an electrically conductive material configurable to be coupled to at least a portion of the conductor, wherein the electrically conductive material is configurable to lower an electrical resistance of the conductor in the overburden during use; and

wherein the system is configurable to allow heat to transfer from the conductor to a section of the formation during use.

5601. The system of claim 5600, further comprising an electrically conductive material configurable to be coupled to at least a portion of an inside surface of the conduit.

5602. The system of claim 5600, further comprising a substantially low resistance conductor configurable to be electrically coupled to the conductor and the electrically conductive material during use, wherein the substantially low resistance conductor is further configurable to be placed within an overburden of the formation.

5603. The system of claim 5602, wherein the low resistance conductor comprises carbon steel.

5604. The system of claim 5600, wherein the electrically conductive material comprises metal tubing configurable to be clad to the conductor.

5605. The system of claim 5600, wherein the electrically conductive material comprises an electrically conductive coating configurable to be applied to the conductor.

5606. The system of claim 5600, wherein the electrically conductive material comprises a thermal plasma applied coating.

5607. The system of claim 5600, wherein the electrically conductive material is configurable to be sprayed on the conductor.

5608. The system of claim 5600, wherein the electrically conductive material comprises aluminum.

5609. The system of claim 5600, wherein the electrically conductive material comprises copper.

5610. The system of claim 5600, wherein the electrically conductive material is configurable to reduce the electrical resistance of the conductor in the overburden by a factor of greater than about 3.

5611. The system of claim 5600, wherein the electrically conductive material is configurable to reduce the electrical resistance of the conductor in the overburden by a factor of greater than about 15.

5612. The system of claim 5600, wherein the system is further configurable to allow at least some hydrocarbons to pyrolyze in the heated section of the formation during use.

5613. The system of claim 5600, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

a conduit configured to be placed within an opening in the formation;

a conductor configured to be placed within a conduit, wherein the conductor is further configured to provide heat to at least a portion of the formation during use;

an electrically conductive material configured to be coupled to the conductor, wherein the electrically conductive material is further configured to lower an electrical resistance of the conductor in the overburden during use; and

wherein the system is configured to allow heat to transfer from the conductor to a section of the formation during use.

5614. The system of claim 5600, wherein the system heats a hydrocarbon containing formation, and wherein the system comprises:

a conduit placed within an opening in the formation;

a conductor placed within a conduit, wherein the conductor is provides heat to at least a portion of the formation during use;

an electrically conductive material coupled to the conductor, wherein the electrically conductive material lowers an electrical resistance of the conductor in the overburden during use; and

wherein the system allows heat to transfer from the conductor to a section of the formation during use.

5615. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to a conductor to provide heat to at least a portion of the formation, wherein the conductor is placed in a conduit, and wherein the conduit is placed in an opening in the formation, and wherein the conductor is coupled to an electrically conductive material; and

allowing the heat to transfer from the conductor to a section of the formation.

5616. The method of claim 5615, wherein the electrically conductive material comprises copper.

5617. The method of claim 5615, further comprising coupling an electrically conductive material to an inside surface of the conduit.

5618. The method of claim 5615, wherein the electrically conductive material comprises metal tubing clad to the substantially low resistance conductor.

5619. The method of claim 5615, wherein the electrically conductive material reduces an electrical resistance of the substantially low resistance conductor in the overburden.

5620. The method of claim 5615, further comprising pyrolyzing at least some hydrocarbons within the formation.

5621. A system configurable to heat a hydrocarbon containing formation, comprising:

a conduit configurable to be placed within an opening in the formation;

a conductor configurable to be placed within a conduit, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use, and wherein the conductor has been treated to increase an emissivity of at least a portion of a surface of the conductor; and

wherein the system is configurable to allow heat to transfer from the conductor to a section of the formation during use.

5622. The system of claim 5621, wherein at least a portion of the surface of the conductor has been roughened to increase the emissivity of the conductor.

5623. The system of claim 5621, wherein the conductor has been heated to a temperature above about 750°

C. in an oxidizing fluid atmosphere to increase the emissivity of at least a portion of the surface of the conductor.

5624. The system of claim 5621, wherein the conduit has been treated to increase an emissivity of at least a portion of the surface of the conduit.

5625. The system of claim 5621, further comprising an electrically insulative, thermally conductive coating coupled to the conductor.

5626. The system of claim 5625, wherein the electrically insulative, thermally conductive coating is configurable to electrically insulate the conductor from the conduit.

5627. The system of claim 5625, wherein the electrically insulative, thermally conductive coating inhibits emissivity of the conductor from decreasing.

5628. The system of claim 5625, wherein the electrically insulative, thermally conductive coating substantially increases an emissivity of the conductor.

5629. The system of claim 5625, wherein the electrically insulative, thermally conductive coating comprises silicon oxide.

5630. The system of claim 5625, wherein the electrically insulative, thermally conductive coating comprises aluminum oxide.

5631. The system of claim 5625, wherein the electrically insulative, thermally conductive coating comprises refractive cement.

5632. The system of claim 5625, wherein the electrically insulative, thermally conductive coating is sprayed on the conductor.

5633. The system of claim 5621, wherein the system is further configurable to allow at least some hydrocarbons to pyrolyze in the heated section of the formation during use.

5634. The system of claim 5621, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

a conduit configured to be placed within an opening in the formation;

a conductor configured to be placed within a conduit, wherein the conductor is further configured to provide heat to at least a portion of the formation during use, and wherein the conductor has been treated to increase an emissivity of at least a portion of a surface of the conductor; and

wherein the system is configured to allow heat to transfer from the conductor to a section of the formation during use.

5635. The system of claim 5621, wherein the system heats a hydrocarbon containing formation, and wherein the system comprises:

a conduit placed within an opening in the formation;

a conductor placed within a conduit, wherein the conductor provides heat to at least a portion of the formation during use, and wherein the conductor has been treated to increase an emissivity of at least a portion of a surface of the conductor; and

wherein the system allows heat to transfer from the conductor to a section of the formation during use.

5636. A heater configurable to heat a hydrocarbon containing formation, comprising:

a conduit configurable to be placed within an opening in the formation; and

a conductor configurable to be placed within a conduit, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use, and wherein the conductor has been treated to increase an emissivity of at least a portion of a surface of the conductor.

5637. The heater of claim 5636, wherein at least a portion of the surface of the conductor has been roughened to increase the emissivity the conductor.

5638. The heater of claim 5636, wherein the conductor has been heated to a temperature above about 750°

C. in an oxidizing fluid atmosphere to increase the emissivity of at least at least a portion of the surface of the conductor.

5639. The heater of claim 5636, wherein the conduit has been treated to increase an emissivity of at least a portion of the surface of the conduit.

5640. The heater of claim 5636, further comprising an electrically insulative, thermally conductive coating placed on the conductor.

5641. The heater of claim 5640, wherein the electrically insulative, thermally conductive coating is configurable to electrically insulate the conductor from the conduit.

5642. The heater of claim 5640, wherein the electrically insulative, thermally conductive coating substantially maintains an emissivity of the conductor.

5643. The heater of claim 5640, wherein the electrically insulative, thermally conductive coating substantially increases an emissivity of the conductor.

5644. The heater of claim 5640, wherein the electrically insulative, thermally conductive coating comprises silicon oxide.

5645. The heater of claim 5640, wherein the electrically insulative, thermally conductive coating comprises aluminum oxide.

5646. The heater of claim 5640, wherein the electrically insulative, thermally conductive coating comprises refractive cement.

5647. The heater of claim 5640, wherein the electrically insulative, thermally conductive coating is sprayed on the conductor.

5648. The heater of claim 5636, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use such that at least some hydrocarbons pyrolyze in the heated section of the formation during use.

5649. The heater of claim 5636, wherein the heater is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

a conduit configured to be placed within an opening in the formation;

a conductor configured to be placed within a conduit, wherein the conductor is further configured to provide heat to at least a portion of the formation during use, and wherein the conductor has been treated to increase an emissivity of at least a portion of a surface of the conductor.

5650. The heater of claim 5636, wherein the heater heats a hydrocarbon containing formation, and wherein the system comprises:

a conduit placed within an opening in the formation;

a conductor placed within a conduit, wherein the conductor provides heat to at least a portion of the formation, and wherein the conductor has been treated to increase an emissivity of at least a portion of a surface of the conductor.

5651. A method for forming an increased emissivity conductor-in-conduit heater, comprising:

treating a surface of a conductor to increase an emissivity of at least the surface of the conductor;

placing the conductor within a conduit to form a conductor-in-conduit heater; and

wherein the conductor-in-conduit heater is configurable to heat a hydrocarbon containing formation.

5652. The method of claim 5651, wherein treating the surface of the conductor comprises roughening at least a portion of the surface of the conductor.

5653. The method of claim 5651, wherein treating the surface of the conductor comprises heating the conductor to a temperature above about 750°

C. in an oxidizing fluid atmosphere.

5654. The method of claim 5651, further comprising treating a surface of the conduit to increase an emissivity of at least a portion of the surface of the conduit.

5655. The method of claim 5651, further comprising placing the conductor-in-conduit heater of the desired length in an opening in a hydrocarbon containing formation.

5656. The method of claim 5651, further comprising assembling a conductor-in-conduit heater of a desired length, the assembling comprising:

coupling the conductor-in-conduit heater to at least one additional conductor-in-conduit heater to form a conductor-in-conduit heater of a desired length, wherein the conductor is electrically coupled to the conductor of at least one additional conductor-in-conduit heater and the conduit is electrically coupled to the conduit of at least one additional conductor-in-conduit heater;

coiling the conductor-in-conduit heater of the desired length after forming the heater; and

placing the conductor-in-conduit heater of the desired length in an opening in a hydrocarbon containing formation.

5657. The method of claim 5651, wherein the conductor-in-conduit heater is configurable to heat to a section of the hydrocarbon containing formation, and wherein the heat pyrolyzes at least some hydrocarbons in the section of the formation during use.

5658. A system configurable to heat a hydrocarbon containing formation, comprising:

a heater configurable to be placed in an opening in the formation, wherein the heater is further configurable to provide heat to at least a portion of the formation during use;

an expansion mechanism configurable to be coupled to the heater, wherein the

expansion mechanism is configurable to allow for movement of the heater during

use; and

wherein the system is configurable to allow heat to transfer to a section of the formation during use.

5659. The system of claim 5658, wherein the expansion mechanism is configurable to allow for expansion of the heater during use.

5660. The system of claim 5658, wherein the expansion mechanism is configurable to allow for contraction of the heater during use.

5661. The system of claim 5658, wherein the expansion mechanism is configurable to allow for expansion of at least one component of the heater during use.

5662. The system of claim 5658, wherein the expansion mechanism is configurable to allow for expansion and contraction of the heater within a wellbore during use.

5663. The system of claim 5658, wherein the expansion mechanism comprises spring loading.

5664. The system of claim 5658, wherein the expansion mechanism comprises an accordion mechanism.

5665. The system of claim 5658, wherein the expansion mechanism is configurable to be coupled to a bottom of the heater.

5666. The system of claim 5658, wherein the heater is configurable to allow at least some hydrocarbons to pyrolyze in the heated section of the formation during use.

5667. The system of claim 5658, wherein the system is configured to heat a hydrocarbon containing formation, and wherein the system comprises:

a heater configured to be placed in an opening in the formation, wherein the heater is further configured to provide heat to at least a portion of the formation during use;

an expansion mechanism configured to be coupled to the heater, wherein the expansion mechanism is configured to allow for movement of the heater during use; and

wherein the system is configured to allow heat to transfer to a section of the formation during use.

5668. The system of claim 5658, wherein the system heats a hydrocarbon containing formation, and wherein the system comprises:

a heater placed in an opening in the formation, wherein the heater provides heat to at least a portion of the formation during use;

an expansion mechanism coupled to the heater, wherein the expansion mechanism allows for movement of the heater during use; and

wherein the system allows heat to transfer to a section of the formation during use.

5669. The system of claim 5658, wherein the heater is removable.

5670. A system configurable to provide heat to a hydrocarbon containing formation, comprising:

a conduit positionable in at least a portion of an opening in the formation, wherein a first end of the opening contacts an earth surface at a first location, and wherein a second end of the opening contacts the earth surface at a second location; and

an oxidizer configurable to provide heat to a selected section of the formation by transferring heat through the conduit.

5671. The system of claim 5670, wherein heat from the oxidizer pyrolyzes at least some hydrocarbons in the selected section.

5672. The system of claim 5670, wherein the conduit is positioned in the opening.

5673. The system of claim 5670, wherein the oxidizer is positionable in the conduit.

5674. The system of claim 5670, wherein the oxidizer is positioned in the conduit, and wherein the oxidizer is configured to heat the selected section.

5675. The system of claim 5670, wherein the oxidizer comprises a ring burner.

5676. The system of claim 5670, wherein the oxidizer comprises an inline burner.

5677. The system of claim 5670, wherein the oxidizer is configurable to provide heat in the conduit.

5678. The system of claim 5670, further comprising an annulus formed between a wall of the conduit and a wall of the opening.

5679. The system of claim 5670, wherein the oxidizer comprises a first oxidizer and a second oxidizer, and further comprising an annulus formed between a wall of the conduit and a wall of the opening, wherein the second oxidizer is positionable in the annulus.

5680. The system of claim 5679, wherein the first oxidizer is configurable to provide heat in the conduit, and wherein the second oxidizer is configurable to provide heat outside of the conduit.

5681. The system of claim 5679, wherein heat provided by the first oxidizer transfers in the first conduit in a direction opposite of heat provided by the second oxidizer.

5682. The system of claim 5679, wherein heat provided by the first oxidizer transfers in the first conduit in a same direction as heat provided by the second oxidizer.

5683. The system of claim 5670, wherein the oxidizer is configurable to oxidize fuel to generate hear, and further comprising a recycle conduit configurable to recycle at least some of the fuel in the conduit to a fuel source.

5684. The system of claim 5670, wherein the oxidizer comprises a first oxidizer positioned in the conduit and a second oxidizer positioned in an annulus formed between a wall of the conduit and a wall of the opening, wherein the oxidizers are configurable to oxidize fuel to generate heat, and further comprising:

a first recycle conduit configurable to recycle at least some of the fuel in the conduit to the second oxidizer; and

a second recycle conduit configurable to recycle at least some of the fuel in the annulus to the first oxidizer.

5685. The system of claim 5670, further comprising insulation positionable proximate the oxidizer.

5686. An in situ method for heating a hydrocarbon containing formation, comprising:

providing heat to a conduit positioned in an opening in the formation, wherein a first end of the opening contacts an earth surface at a first location, and wherein a second end of the opening contacts the earth surface at a second location; and

allowing the heat in the conduit to transfer through the opening and to a surrounding portion of the formation.

5687. The method of claim 5686, further comprising:

providing fuel to an oxidizer;

oxidizing at least some of the fuel; and

allowing oxidation products to migrate through the opening, wherein the oxidation products comprise heat.

5688. The method of claim 5687, wherein the fuel is provided to the oxidizer proximate the first location, and wherein the oxidation products migrate towards the second location.

5689. The method of claim 5686, wherein the oxidizer comprises a ring burner.

5690. The method of claim 5686, wherein the oxidizer comprises an inline burner.

5691. The method of claim 5686, further comprising recycling at least some fuel in the conduit.

5692. A system configurable to provide heat to a hydrocarbon containing formation, comprising:

a conduit positionable in an opening in the formation, wherein a first end of the opening contacts an earth surface at a first location, wherein a second end of the opening contacts the earth surface at a second location;

an annulus formed between a wall of the conduit and a wall of the opening; and

a oxidizer configurable to provide heat to a selected section of the formation by transferring heat through the annulus.

5693. The system of claim 5692, wherein heat from the oxidizer pyrolyzes at least some hydrocarbons in the selected section.

5694. The system of claim 5692, wherein the conduit is positioned in the opening.

5695. The system of claim 5692, wherein the oxidizer comprises a first oxidizer and a second oxidizer, wherein the second oxidizer is positioned in the conduit, and wherein the second oxidizer is configured to heat the selected section.

5696. The system of claim 5692, wherein the oxidizer comprises a ring burner.

5697. The system of claim 5692, wherein the oxidizer comprises an inline burner.

5698. The system of claim 5695, wherein heat provided by the first oxidizer transfers in the first conduit in a direction opposite of heat provided by the second oxidizer.

5699. The system of claim 5692, wherein the oxidizer is configurable to oxidize fuel to generate heat, and further comprising a recycle conduit configurable to recycle at least some of the fuel in the conduit to a fuel source.

5700. The system of claim 5692, further comprising insulation positionable proximate the oxidizer.

5701. The system of claim 5692, wherein the conduit is positioned in the opening.

5702. The system of claim 5692, wherein the oxidizer is positioned in the annulus, and wherein the oxidizer is configured to heat the selected section.

5703. The system of claim 5692, wherein the oxidizer comprises a first oxidizer and a second oxidizer.

5704. The system of claim 5703, wherein heat provided by the first oxidizer transfers through the opening in a direction opposite of heat provided by the second oxidizer.

5705. The system of claim 5692, wherein the oxidizer is configurable to oxidize fuel to generate heat, and further comprising a recycle conduit configurable to recycle at least some of the fuel in the annulus to a fuel source.

5706. The system of claim 5692, further comprising insulation positionable proximate the oxidizer.

5707. The system of claim 5703, wherein the first oxidizer and the second oxidizer comprise oxidizers, and wherein a first mixture of oxidation products generated by the first oxidizer flows countercurrent to a second mixture of oxidation products generated by the second heater.

5708. The system of claim 5703, wherein the first heater and the second heater comprise oxidizers, wherein fuel is oxidized by the oxidizers to generate heat, and further comprising a first recycle conduit to recycle fuel in the first conduit proximate the second location to the second conduit.

5709. The system of claim 5703, wherein the first oxidizer and the second oxidizer comprise oxidizers, wherein fuel is oxidized by the oxidizers to generate heat, and further comprising a second recycle conduit to recycle fuel in the second conduit proximate the first location to the first conduit.

5710. The system of claim 5692, further comprising a casing, wherein the conduit is positionable in the casing.

5711. The system of claim 5692, wherein the oxidizer comprises a first oxidizer positioned in the annulus and a second oxidizer positioned in the conduit, wherein the oxidizers are configurable to oxidize fuel to generate heat, and further comprising:

a first recycle conduit configurable to recycle at least some of the fuel in the annulus to the second oxidizer; and

a second recycle conduit configurable to recycle at least some of the fuel in the conduit to the first oxidizer.

5712. An in situ method for heating a hydrocarbon containing formation, comprising:

providing heat to an annulus formed between a wall of an opening in the formation and a wall of a conduit in the opening, wherein a first end of the opening contacts an earth surface at a first location, and wherein a second end of the opening contacts the earth surface at a second location; and

allowing the heat in the annulus to transfer through the opening and to a surrounding portion of the formation.

5713. The method of claim 5712, further comprising:

providing fuel to an oxidizer;

oxidizing at least some of the fuel; and

allowing oxidation products to migrate through the opening, wherein the oxidation products comprise heat.

5714. The method of claim 5713, wherein the fuel is provided the oxidizer proximate the first location, and wherein the oxidation products migrate towards the second location.

5715. The method of claim 5712, wherein the oxidizer comprises a ring burner.

5716. The method of claim 5712, wherein the oxidizer comprises an inline burner.

5717. The method of claim 5712, further comprising recycling at least some fuel in the conduit.

5718. A system configurable to provide heat to a hydrocarbon containing formation, comprising:

a first conduit positionable in an opening in the formation, wherein a first end of the opening contacts an earth surface at a first location, wherein a second end of the opening contacts the earth surface at a second location;

a second conduit positionable in the opening;

a first oxidizer configurable to provide heat to a selected section of the formation by transferring heat through the first conduit; and

a second oxidizer configurable to provide heat to the selected section of the formation by transferring heat through the second conduit.

5719. The system of claim 5718, wherein the first oxidizer is positionable in the first conduit.

5720. The system of claim 5718, wherein the second oxidizer is positionable in the second conduit.

5721. The system of claim 5718, further comprising a casing positionable in the opening.

5722. The system of claim 5718, wherein at least a portion of the second conduit is positionable in the first conduit, and further comprising an annulus formed between a wall of the first conduit and a wall of the second conduit.

5723. The system of claim 5718, wherein a portion of the second conduit is positionable proximate a portion of the first conduit.

5724. The system of claim 5718, wherein the first oxidizer or the second oxidizer provide heat to at least a portion of the formation.

5725. The system of claim 5718, wherein the first oxidizer and the second oxidizer provide heat to at least a portion of the formation concurrently.

5726. The system of claim 5718, wherein the first oxidizer is positioned in the first conduit, wherein the second oxidizer is positioned in the second conduit, wherein the first oxidizer and the second oxidizer comprise oxidizers, and wherein a first flow of oxidation products from the first oxidizer flows in a direction opposite of a second flow of oxidation products from the second oxidizer.

5727. The system of claim 5718, further comprising:

a first recycle conduit configurable to recycle at least some of the fuel in the first conduit to the second oxidizer; and

a second recycle conduit configurable to recycle at least some of the fuel in the second conduit to the first oxidizer.

5728. An in situ method for heating a hydrocarbon containing formation, comprising:

providing heat to a first conduit positioned in an opening in the formation, wherein a first end of the opening contacts an earth surface at a first location, and wherein a second end of the opening contacts the earth surface at a second location;

providing heat to a second conduit positioned in the opening in the formation;

allowing the heat in the first conduit to transfer through the opening and to a surrounding portion of the formation; and

allowing the heat in the second conduit to transfer through the opening and to a surrounding portion of the formation;

5729. The method of claim 5728, wherein providing heat to the first conduit comprises providing fuel to an oxidizer.

5730. The method of claim 5728, wherein providing heat to the second conduit comprises providing fuel to an oxidizer.

5731. The method of claim 5728, wherein the first fuel is provided to the first conduit proximate the first location, and wherein the second fuel is provided to the second conduit proximate the second location.

5732. The method of claim 5728, wherein the first oxidizer or the second oxidizer comprises a ring burner.

5733. The method of claim 5728, wherein the first oxidizer or the second oxidizer an inline burner.

5734. The method of claim 5728, further comprising:

transferring heat through the first conduit in a first direction; and

transferring heat in the second conduit in a second direction.

5735. The method of claim 5728, further comprising recycling at least some fuel in the first conduit to the second conduit;

and recycling at least some fuel in the second conduit to the first conduit.

5736. A system configurable to provide heat to a hydrocarbon containing formation, comprising:

a first conduit positionable in an opening in the formation, wherein a first end of the opening contacts an earth surface at a first location, wherein a second end of the opening contacts the earth surface at a second location;

a second conduit positionable in the first conduit; and

at least one surface unit configurable to provide heat to the first conduit.

5737. The system of claim 5736, wherein the surface unit comprises a furnace.

5738. The system of claim 5736, wherein the surface unit comprises a burner.

5739. The system of claim 5736, wherein at least one surface unit is configurable to provide heat to the second conduit.

5740. The system of claim 5739, wherein the first conduit and the second conduit provide heat to at least a portion of the formation.

5741. The system of claim 5739, wherein the first conduit provides heat to at least a portion of the formation.

5742. The system of claim 5739, wherein the second conduit provides heat to at least a portion of the formation.

5743. The system of claim 5736, further comprising a casing positionable in the opening.

5744. The system of claim 5736, wherein the first conduit and the second conduit are concentric.

5745. An in situ method for heating a hydrocarbon containing formation, comprising:

heating a fluid using at least one surface unit;

providing the heated fluid to a first conduit wherein a portion of the first conduit is positioned in an opening in the formation, wherein a first end of the opening contacts an earth surface at a first location, and wherein a second end of the opening contacts the earth surface at a second location;

allowing the heated fluid to flow into a second conduit, wherein the first conduit is positioned within the second conduit; and

allowing heat from the first and second conduit to transfer to a portion of the formation.

5746. The method of claim 5745, further comprising providing additional heat to the heated fluid using at least one surface unit proximate the second location.

5747. The method of claim 5745, wherein the fluid comprises an oxidizing fluid.

5748. The method of claim 5745, wherein the fluid comprises air.

5749. The method of claim 5745, wherein the fluid comprises flue gas.

5750. The method of claim 5745, wherein the fluid comprises steam.

5751. The method of claim 5745, wherein the fluid comprises fuel.

5752. The method of claim 5745, further comprising compressing the fluid prior to heating.

5753. The method of claim 5745, wherein the surface unit comprises a furnace.

5754. The method of claim 5745, wherein the surface unit comprises an indirect furnace.

5755. The method of claim 5745, wherein the surface unit comprises a burner.

5756. The method of claim 5745, wherein the first conduit and the second conduit are concentric.

5757. A system configurable to provide heat to a hydrocarbon containing formation, comprising:

a conduit positionable in at least a portion of an opening in the formation, wherein a first end of the opening contacts an earth surface at a first location, and wherein a second end of the opening contacts the earth surface at a second location; and

at least two oxidizers configurable to provide heat to a portion of the formation.

5758. The system of claim 5757, wherein heat from the oxidizers pyrolyzes at least some hydrocarbons in the selected section.

5759. The system of claim 5757, wherein the conduit comprises a fuel conduit.

5760. The system of claim 5757, wherein at least one oxidizer is positionable proximate the conduit.

5761. The system of claim 5757, wherein at least one oxidizer comprises a ring burner.

5762. The system of claim 5757, wherein at least one oxidizer comprises an inline burner.

5763. The system of claim 5757, further comprising insulation positionable proximate at least one oxidizer.

5764. The system of claim 5757, further comprising a casing comprising insulation proximate at least one oxidizer.

5765. An in situ method for heating a hydrocarbon containing formation, comprising:

providing fuel to a conduit positioned in an opening in the formation, wherein a first end of the opening contacts an earth surface at a first location, and wherein a second end of the opening contacts the earth surface at a second location;

providing an oxidizing fluid to the opening;

oxidizing fuel in at least one oxidizer positioned proximate the conduit; and

allowing heat to transfer to a portion of the formation.

5766. The method of claim 5765, further comprising providing steam to the conduit.

5767. The method of claim 5765, further comprising inhibiting coking within the conduit.

5768. The method of claim 5765, wherein the oxidizing fluid comprises air.

5769. The method of claim 5765, wherein the oxidizing fluid comprises oxygen.

5770. The method of claim 5765, further comprising allowing oxidation products to exit the opening proximate the second location.

5771. The method of claim 5765, wherein the fuel is provided to proximate the first location, and wherein the oxidation products migrate towards the second location.

5772. The method of claim 5765, wherein the oxidizer comprises a ring burner.

5773. The method of claim 5765, wherein the oxidizer comprises an inline burner.

5774. The method of claim 5765, further comprising recycling at least some fuel in the conduit.

5775. The system of claim 5765, wherein the opening comprises a casing and further comprising insulating a portion of the casing proximate at least one oxidizer.

5776. The system of claim 5765, further comprising at least two oxidizers, wherein the oxidizers are positioned about 30 m apart.

5777. A system configurable to provide heat to a hydrocarbon containing formation, comprising:

a conduit positionable in at least a portion of an opening in the formation, wherein a first end of the opening contacts an earth surface at a first location, and wherein a second end of the opening contacts the earth surface at a second location; and

an oxidizing fluid source configurable to provide an oxidizing fluid to a reaction zone of the formation.

5778. The system of claim 5777, wherein the conduit comprises a conductor and wherein the conductor is configured to generate heat during application of an electrical current to the conduit.

5779. The system of claim 5777, wherein the conduit comprises a low resistance conductor and wherein at least some of the low resistance conductor is positionable in an overburden.

5780. The system of claim 5777, wherein the oxidizing fluid source is configurable to provide at least some oxidizing fluid to the conduit at the first location and at the second location.

5781. The system of claim 5777, wherein the opening is configurable to allow products of oxidation to be produced from the formation.

5782. The system of claim 5777, wherein the oxidizing fluid reacts with at least some hydrocarbons and wherein the oxidizing fluid source is configurable to provide at least some oxidizing fluid to the first location and to the second location.

5783. The system of claim 5777, wherein the heater is configurable to heat a reaction zone of the selected section to a temperature sufficient to support reaction of hydrocarbons in the selected section with an oxidizing fluid.

5784. The system of claim 5783, wherein the heater is configurable to provide an oxidizing fluid to the selected section of the formation to generate heat during use.

5785. The system of claim 5783, wherein the generated heat transfers to a pyrolysis zone of the formation.

5786. The system of claim 5777, further comprising an oxidizing fluid source configurable to provide an oxidizing fluid to the heater, and wherein the conduit is configurable to provide the oxidizing fluid to the selected section of the formation during use.

5787. The system of claim 5777, wherein the conduit comprises a low resistance conductor and a conductor, and wherein the conductor is further configured to generate heat during application of an electrical current to the conduit.

5788. An in situ method for heating a hydrocarbon containing formation, comprising:

providing an electrical current to a conduit positioned in an opening in the formation;

allowing heat to transfer from the conduit to a reaction zone of the formation;

providing at least some oxidizing fluid to the conduit;

allowing the oxidizing fluid to transfer from the conduit to the reaction zone in the formation;

allowing the oxidizing fluid to oxidize at least some hydrocarbons in the reaction zone to generate heat; and

allowing at least some of the generated heat to transfer to a pyrolysis zone in the formation.

5789. The method of claim 5788, wherein at least a portion of the conduit is configured to generate heat during application of the electrical current to the conduit.

5790. The method of claim 5788, further comprising:

providing at least some oxidizing fluid to the conduit proximate a first end of the conduit;

providing at least some oxidizing fluid to the conduit proximate a second end of the conduit; and

wherein the first end of the conduit is positioned at a first location on a surface of the formation and wherein the second end of the conduit is positioned at a second location on the surface.

5791. The method of claim 5788, further comprising allowing the oxidizing fluid to move out of the conduit through orifices positioned on the conduit.

5792. The method of claim 5788, further comprising removing products of oxidation through the opening during use.

5793. The method of claim 5788, wherein a first end of the opening is positioned at a first location on a surface of the formation and wherein a second end of the opening is positioned at a second location on the surface.

5794. The method of claim 5788, further comprising heating the reaction zone to a temperature sufficient to support reaction of hydrocarbons with an oxidizing fluid.

5795. The method of claim 5788, further comprising controlling a flow rate of the oxidizing fluid into the formation.

5796. The method of claim 5788, further comprising controlling a temperature in the pyrolysis zone.

5797. The method of claim 5788, further comprising removing products from oxidation through an opening in the formation during use.

5798. A method for treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a first section of the formation such that the heat from the one or more heaters pyrolyzes at least some hydrocarbons within the first section; and

producing a mixture through a second section of the formation, wherein the produced mixture comprises at least some pyrolyzed hydrocarbons from the first section, and wherein the second section comprises a higher permeability than the first section.

5799. The method of claim 5798, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

5800. The method of claim 5798, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

5801. The method of claim 5798, further comprising increasing permeability within the second section by allowing heat to transfer from the one or more heaters to the second section.

5802. The method of claim 5798, wherein the second section has a higher permeability than the first section before providing heat to the formation.

5803. The method of claim 5798, wherein the second section comprises an average permeability thickness product of greater than about 100 millidarcy feet.

5804. The method of claim 5798, wherein the first section comprises an initial average permeability thickness product of less than about 10 millidarcy feet.

5805. The method of claim 5798, wherein the second section comprises an average permeability thickness product that is at least twice an initial average permeability thickness product of the first section.

5806. The method of claim 5798, wherein the second section comprises an average permeability thickness product that is at least ten times an initial average permeability thickness product of the first section.

5807. The method of claim 5798, wherein the one or more heaters are placed within at least one uncased wellbore in the formation.

5808. The method of claim 5807, further comprising allowing at least some hydrocarbons from the first section to propagate through at least one uncased wellbore into the second section.

5809. The method of claim 5807, further comprising producing at least some hydrocarbons through at least one uncased wellbore.

5810. The method of claim 5798, further comprising forming one or more fractures that propagate between the first section and the second section.

5811. The method of claim 5810, further comprising allowing at least some hydrocarbons from the first section to propagate through the one or more fractures into the second section.

5812. The method of claim 5798, further comprising producing the mixture from the formation through a production well placed in the second section.

5813. The method of claim 5798, further comprising producing the mixture from the formation through a production well placed in the first section and the second section.

5814. The method of claim 5798, further comprising inhibiting fracturing of a section of the formation that is substantially adjacent to an environmentally sensitive area.

5815. The method of claim 5798, further comprising producing at least some hydrocarbons through the second section to maintain a pressure in the formation below a lithostatic pressure of the formation.

5816. The method of claim 5798, further comprising producing at least some hydrocarbons through a production well placed in the first section.

5817. The method of claim 5798, further comprising pyrolyzing at least some hydrocarbons within the second section.

5818. The method of claim 5798, wherein the first section and the second section are substantially adjacent.

5819. The method of claim 5798, further comprising allowing migration of fluids between the first second and the second section.

5820. The method of claim 5798, wherein at least one heater has a thickness of a conductor that is adjusted to provide more heat to the first section than the second section.

5821. A method for treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation, wherein one or more of such heaters is placed within at least one uncased wellbore in the formation;

allowing the heat to transfer from the one or more heaters to a first section of the formation such that the heat from the one or more heaters pyrolyzes at least some hydrocarbons within the first section; and

producing a mixture through a second section of the formation, wherein the produced mixture comprises at least some pyrolyzed hydrocarbons from the first section, and wherein the second section comprises a higher permeability than the first section.

5822. The method of claim 5821, further comprising allowing at least some hydrocarbons from the first section to propagate through at least one uncased wellbore into the second section.

5823. The method of claim 5821, further comprising producing at least some hydrocarbons through at least one uncased wellbore.

5824. A method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, comprising:

providing at least one property of the formation to the computer system;

providing at least one operating condition of the process to the computer system, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

assessing at least one process characteristic of the in situ process using a simulation method on the computer system, and using at least one property of the formation and at least one operating condition.

5825. The method of claim 5824, wherein at least one process characteristic is assessed as function of time.

5826. The method of claim 5824, wherein the simulation method is a body-fitted finite difference simulation method.

5827. The method of claim 5824, wherein the simulation method is a space-fitted finite difference simulation method.

5828. The method of claim 5824, wherein the simulation method is a reservoir simulation method.

5829. The method of claim 5824, wherein the simulation method simulates heat transfer by conduction.

5830. The method of claim 5824, wherein the simulation method simulates heat transfer by convection.

5831. The method of claim 5824, wherein the simulation method simulates heat transfer by radiation.

5832. The method of claim 5824, wherein the simulation method simulates heat transfer in a near wellbore region.

5833. The method of claim 5824, wherein the simulation method assesses a temperature distribution in the formation.

5834. The method of claim 5824, wherein at least one property of the formation comprises one or more materials from the formation.

5835. The method of claim 5834, wherein one material comprises mineral matter.

5836. The method of claim 5834, wherein one material comprises organic matter.

5837. The method of claim 5824, wherein at least one property of the formation comprises one or more phases.

5838. The method of claim 5837, wherein one phase comprises a water phase.

5839. The method of claim 5837, wherein one phase comprises an oil phase.

5840. The method of claim 5839, wherein the oil phase comprises one or more components.

5841. The method of claim 5837, wherein one phase comprises a gas phase.

5842. The method of claim 5841, wherein the gas phase comprises one or more components.

5843. The method of claim 5824, wherein at least one property of the formation comprises a porosity of the formation.

5844. The method of claim 5824, wherein at least one property of the formation comprises a permeability of the formation.

5845. The method of claim 5844, wherein the permeability depends on the composition of the formation.

5846. The method of claim 5824, wherein at least one property of the formation comprises a saturation of the formation.

5847. The method of claim 5824, wherein at least one property of the formation comprises a density of the formation.

5848. The method of claim 5824, wherein at least one property of the formation comprises a thermal conductivity of the formation.

5849. The method of claim 5824, wherein at least one property of the formation comprises a volumetric heat capacity of the formation.

5850. The method of claim 5824, wherein at least one property of the formation comprises a compressibility of the formation.

5851. The method of claim 5824, wherein at least one property of the formation comprises a composition of the formation.

5852. The method of claim 5824, wherein at least one property of the formation comprises a thickness of the formation.

5853. The method of claim 5824, wherein at least one property of the formation comprises a depth of the formation.

5854. The method of claim 5824, wherein at least one property comprises one or more chemical components.

5855. The method of claim 5854, wherein one component comprises a pseudo-component.

5856. The method of claim 5824, wherein at least property comprises one or more kinetic parameters.

5857. The method of claim 5824, wherein at least one property comprises one or more chemical reactions.

5858. The method of claim 5857, wherein a rate of at least one chemical reaction depends on a pressure of the formation.

5859. The method of claim 5857, wherein a rate of at least one chemical reaction depends on a temperature of the formation.

5860. The method of claim 5857, wherein at least one chemical reaction comprises a pre-pyrolysis water generation reaction.

5861. The method of claim 5857, wherein at least one chemical reaction comprises a hydrocarbon generating reaction.

5862. The method of claim 5857, wherein at least one chemical reaction comprises a coking reaction.

5863. The method of claim 5857, wherein at least one chemical reaction comprise a cracking reaction.

5864. The method of claim 5857, wherein at least one chemical reaction comprises a synthesis gas reaction.

5865. The method of claim 5824, wherein at least one process characteristic comprises an API gravity of produced fluids.

5866. The method of claim 5824, wherein at least one process characteristic comprises an olefin content of produced fluids.

5867. The method of claim 5824, wherein at least one process characteristic comprises a carbon number distribution of produced fluids.

5868. The method of claim 5824, wherein at least one process characteristic comprises an ethene to ethane ratio of produced fluids.

5869. The method of claim 5824, wherein at least one process characteristic comprises an atomic carbon to hydrogen ratio of produced fluids.

5870. The method of claim 5824, wherein at least one process characteristic comprises a ratio of non-condensable hydrocarbons to condensable hydrocarbons of produced fluids.

5871. The method of claim 5824, wherein at least one process characteristic comprises a pressure in the formation.

5872. The method of claim 5824, wherein at least one process characteristic comprises total mass recovery from the formation.

5873. The method of claim 5824, wherein at least one process characteristic comprises a production rate of fluid produced from the formation.

5874. The method of claim 5824, wherein at least one operating condition comprises a pressure.

5875. The method of claim 5824, wherein at least one operating condition comprises a temperature.

5876. The method of claim 5824, wherein at least one operating condition comprises a heating rate.

5877. The method of claim 5824, wherein at least one operating condition comprises a process time.

5878. The method of claim 5824, wherein at least one operating condition comprises a location of producer wells.

5879. The method of claim 5824, wherein at least one operating condition comprises an orientation of producer wells.

5880. The method of claim 5824, wherein at least one operating condition comprises a ratio of producer wells to heater wells.

5881. The method of claim 5824, wherein at least one operating condition comprises a spacing between heater wells.

5882. The method of claim 5824, wherein at least one operating condition comprises a distance between an overburden and horizontal heater wells.

5883. The method of claim 5824, wherein at least one operating condition comprises a pattern of heater wells.

5884. The method of claim 5824, wherein at least one operating condition comprises an orientation of heater wells.

5885. A method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, comprising:

simulating a heat input rate to the formation from two or more heaters on the computer system, wherein heat is allowed to transfer from the heaters to a selected section of the formation;

providing at least one desired parameter of the in situ process to the computer system; and

controlling the heat input rate from the heaters to achieve at least one desired parameter.

5886. The method of claim 5885, wherein the heat is allowed to transfer from the heaters substantially by conduction.

5887. The method of claim 5885, wherein the heat input rate is simulated with a body-fitted finite difference simulation method.

5888. The method of claim 5885, wherein simulating the heat input rate from two or more heaters comprises simulating a model of one or more heaters with symmetry boundary conditions.

5889. The method of claim 5885, wherein superposition of heat from the two or more heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

5890. The method of claim 5885, wherein at least one desired parameter comprises a selected process characteristic.

5891. The method of claim 5885, wherein at least one desired parameter comprises a selected temperature.

5892. The method of claim 5885, wherein at least one desired parameter comprises a selected heating rate.

5893. The method of claim 5885, wherein at least one desired parameter comprises a desired product mixture produced from the formation.

5894. The method of claim 5885, wherein at least one desired parameter comprises a desired product mixture produced from the formation, and wherein the desired product mixture comprises a selected composition.

5895. The method of claim 5885, wherein at least one desired parameter comprises a selected pressure.

5896. The method of claim 5885, wherein at least one desired parameter comprises a selected heating time.

5897. The method of claim 5885, wherein at least one desired parameter comprises a market parameter.

5898. The method of claim 5885, wherein at least one desired parameter comprises a price of crude oil.

5899. The method of claim 5885, wherein at least one desired parameter comprises an energy cost.

5900. The method of claim 5885, wherein at least one desired parameter comprises a selected molecular hydrogen to carbon monoxide volume ratio.

5901. A method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, comprising:

providing at least one heat input property to the computer system;

assessing heat injection rate data for the formation using a first simulation method on the computer system;

providing at least one property of the formation to the computer system;

assessing at least one process characteristic of the in situ process from the heat injection rate data and at least one property of the formation using a second simulation method; and

wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation.

5902. The method of claim 5901, wherein at least one process characteristic is assessed as a function of time.

5903. The method of claim 5901, wherein assessing heat injection rate data comprises simulating heating of the formation.

5904. The method of claim 5901, wherein the heating is controlled to obtain a desired parameter.

5905. The method of claim 5901, wherein determining at least one process characteristic comprises simulating heating of the formation.

5906. The method of claim 5905, wherein the heating is controlled to obtain a desired parameter.

5907. The method of claim 5901, wherein the first simulation method is a body-fitted finite difference simulation method.

5908. The method of claim 5901, wherein the second simulation method is a space-fitted finite difference simulation method.

5909. The method of claim 5901, wherein the second simulation method is a reservoir simulation method.

5910. The method of claim 5901, wherein the first simulation method simulates heat transfer by conduction.

5911. The method of claim 5901, wherein the first simulation method simulates heat transfer by convection.

5912. The method of claim 5901, wherein the first simulation method simulates heat transfer by radiation.

5913. The method of claim 5901, wherein the second simulation method simulates heat transfer by conduction.

5914. The method of claim 5901, wherein the second simulation method simulates heat transfer by convection.

5915. The method of claim 5901, wherein the first simulation method simulates heat transfer in a near wellbore region.

5916. The method of claim 5901, wherein the first simulation method determines a temperature distribution in the formation.

5917. The method of claim 5901, wherein at least one heat input property comprises a property of the formation.

5918. The method of claim 5901, wherein at least one heat input property comprises a heat transfer property.

5919. The method of claim 5901, wherein at least one heat input property comprises an initial property of the formation.

5920. The method of claim 5901, wherein at least one heat input property comprises a heat capacity.

5921. The method of claim 5901, wherein at least one heat input property comprises a thermal conductivity.

5922. The method of claim 5901, wherein the heat injection rate data comprises a temperature distribution within the formation.

5923. The method of claim 5901, wherein the heat injection rate data comprises a heat input rate.

5924. The method of claim 5923, wherein the heat input rate is controlled to maintain a specified maximum temperature at a point in the formation.

5925. The method of claim 5901, wherein the heat injection rate data comprises heat flux data.

5926. The method of claim 5901, wherein at least one property of the formation comprises one or more materials in the formation.

5927. The method of claim 5926, wherein one material comprises mineral matter.

5928. The method of claim 5926, wherein one material comprises organic matter.

5929. The method of claim 5901, wherein at least one property of the formation comprises one or more phases.

5930. The method of claim 5929, wherein one phase comprises a water phase.

5931. The method of claim 5929, wherein one phase comprises an oil phase.

5932. The method of claim 5931, wherein the oil phase comprises one or more components.

5933. The method of claim 5929, wherein one phase comprises a gas phase.

5934. The method of claim 5933, wherein the gas phase comprises one or more components.

5935. The method of claim 5901, wherein at least one property of the formation comprises a porosity of the formation.

5936. The method of claim 5901, wherein at least one property of the formation comprises a permeability of the formation.

5937. The method of claim 5936, wherein the permeability depends on the composition of the formation.

5938. The method of claim 5901, wherein at least one property of the formation comprises a saturation of the formation.

5939. The method of claim 5901, wherein at least one property of the formation comprises a density of the formation.

5940. The method of claim 5901, wherein at least one property of the formation comprises a thermal conductivity of the formation.

5941. The method of claim 5901, wherein at least one property of the formation comprises a volumetric heat capacity of the formation.

5942. The method of claim 5901, wherein at least one property of the formation comprises a compressibility of the formation.

5943. The method of claim 5901, wherein at least one property of the formation comprises a composition of the formation.

5944. The method of claim 5901, wherein at least one property of the formation comprises a thickness of the formation.

5945. The method of claim 5901, wherein at least one property of the formation comprises a depth of the formation.

5946. The method of claim 5901, wherein at least one property of the formation comprises one or more chemical components.

5947. The method of claim 5946, wherein at least one chemical component comprises a pseudo-component.

5948. The method of claim 5901, wherein at least one property of the formation comprises one or more kinetic parameters.

5949. The method of claim 5901, wherein at least one property of the formation comprises one or more chemical reactions.

5950. The method of claim 5949, wherein a rate of at least one chemical reaction depends on a pressure of the formation.

5951. The method of claim 5949, wherein a rate of at least one chemical reaction depends on a temperature of the formation.

5952. The method of claim 5949, wherein at least one chemical reaction comprises a pre-pyrolysis water generation reaction.

5953. The method of claim 5949, wherein at least one chemical reaction comprises a hydrocarbon generating reaction.

5954. The method of claim 5949, wherein at least one chemical reaction comprises a coking reaction.

5955. The method of claim 5949, wherein at least one chemical reaction comprises a cracking reaction.

5956. The method of claim 5949, wherein at least one chemical reaction comprises a synthesis gas reaction.

5957. The method of claim 5901, wherein at least one process characteristic comprises an API gravity of produced fluids.

5958. The method of claim 5901, wherein at least one process characteristic comprises an olefin content of produced fluids.

5959. The method of claim 5901, wherein at least one process characteristic comprises a carbon number distribution of produced fluids.

5960. The method, of claim 5901, wherein at least one process characteristic comprises an ethene to ethane ratio of produced fluids.

5961. The method of claim 5901, wherein at least one process characteristic comprises an atomic carbon to hydrogen ratio of produced fluids.

5962. The method of claim 5901, wherein at least one process characteristic comprises a ratio of non-condensable hydrocarbons to condensable hydrocarbons of produced fluids.

5963. The method of claim 5901, wherein at least one process characteristic comprises a pressure in the formation.

5964. The method of claim 5901, wherein at least one process characteristic comprises a total mass recovery from the formation.

5965. The method of claim 5901, wherein at least one process characteristic comprises a production rate of fluid produced from the formation.

5966. The method of claim 5901, further comprising:

assessing modified heat injection rate data using the first simulation method at a specified time of the second simulation method based on at least one heat input property of the formation at the specified time;

assessing at least one process characteristic of the in situ process as a function of time from the modified heat injection rate data and at least one property of the formation at the specified time using the second simulation method.

5967. A method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, comprising:

providing one or more model parameters for the in situ process to the computer system;

assessing one or more simulated process characteristics based on one or more model parameters using a simulation method;

modifying one or more model parameters such that at least one simulated process characteristic matches or approximates at least one real process characteristic;

assessing one or more modified simulated process characteristics based on the modified model parameters; and

wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation.

5968. The method of claim 5967, further comprising using the simulation method with the modified model parameters to determine at least one operating condition of the in situ process to achieve a desired parameter.

5969. The method of claim 5967, wherein the simulation method comprises a body-fitted finite difference simulation method.

5970. The method of claim 5967, wherein the simulation method comprises a space-fitted finite difference simulation method.

5971. The method of claim 5967, wherein the simulation method comprises a reservoir simulation method.

5972. The method of claim 5967, wherein the real process characteristics comprise process characteristics obtained from laboratory experiments of the in situ process.

5973. The method of claim 5967, wherein the real process characteristics comprise process characteristics obtained from field test experiments of the in situ process.

5974. The method of claim 5967, further comprising comparing the simulated process characteristics to the real process characteristics as a function of time.

5975. The method of claim 5967, further comprising associating differences between the simulated process characteristics and the real process characteristics with one or more model parameters.

5976. The method of claim 5967, wherein at least one model parameter comprises a chemical component.

5977. The method of claim 5967, wherein at least one model parameter comprises a kinetic parameter.

5978. The method of claim 5977, wherein the kinetic parameter comprises an order of a reaction.

5979. The method of claim 5977, wherein the kinetic parameter comprises an activation energy.

5980. The method of claim 5977, wherein the kinetic parameter comprises a reaction enthalpy.

5981. The method of claim 5977, wherein the kinetic parameter comprises a frequency factor.

5982. The method of claim 5967, wherein at least one model parameter comprises a chemical reaction.

5983. The method of claim 5982, wherein at least one chemical reaction comprises a pre-pyrolysis water generation reaction.

5984. The method of claim 5982, wherein at least one chemical reaction comprises a hydrocarbon generating reaction.

5985. The method of claim 5982, wherein at least one chemical reaction comprises a coking reaction.

5986. The method of claim 5982, wherein at least one chemical reaction comprises a cracking reaction.

5987. The method of claim 5982, wherein at least one chemical reaction comprises a synthesis gas reaction.

5988. The method of claim 5967, wherein one or more model parameters comprise one or more properties.

5989. The method of claim 5967, wherein at least one model parameter comprises a relationship for the dependence of a property on a change in conditions in the formation.

5990. The method of claim 5967, wherein at least one model parameter comprises an expression for the dependence of porosity on pressure in the formation.

5991. The method of claim 5967, wherein at least one model parameter comprises an expression for the dependence of permeability on porosity.

5992. The method of claim 5967, wherein at least one model parameter comprises an expression for the dependence of thermal conductivity on composition of the formation.

5993. A method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, comprising;

assessing at least one operating condition of the in situ process using a simulation method based on one or more model parameter;

modifying at least one model parameter such that at least one simulated process characteristic of the in situ process matches or approximates at least one real process characteristic of the in situ process;

assessing one or more modified simulated process characteristics based on the modified model parameters; and

wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation.

5994. The method of claim 5993, wherein at least one operating condition is assessed to achieve at least one desired parameter.

5995. The method of claim 5993, wherein the real process characteristic comprises a process characteristic from a field test of the in situ process.

5996. The method of claim 5993, wherein the simulation method comprises a body-fitted finite difference simulation method.

5997. The method of claim 5993, wherein the simulation method comprises a space-fitted finite difference simulation method.

5998. The method of claim 5993, wherein the simulation method comprises a reservoir simulation method.

5999. A method of modeling a process of treating a hydrocarbon containing formation in situ using a computer system, comprising:

providing one or more model parameters to the computer system;

assessing one or more first process characteristics based on the one or more model parameters using a first simulation method on the computer system;

assessing one or more second process characteristics based on one or more model parameters using a second simulation method on the computer system;

modifying one or more model parameters such that at least one first process characteristic matches or approximates at least one second process characteristic; and

wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation.

6000. The method of claim 5999, further comprising assessing one or more third process characteristics based on the one or more modified model parameters using the second simulation method.

6001. The method of claim 5999, wherein modifying one or more model parameters such that at least one first process characteristic matches or approximates at least one second process characteristic further comprises:

assessing at least one set of first process characteristics based on at least one set of modified model parameters using the first simulation method; and

assessing the set of modified model parameters that results in at least one first process characteristic that matches or approximates at least one second process characteristic.

6002. The method of claim 5999, wherein the first simulation method comprises a body-fitted finite difference simulation method.

6003. The method of claim 5999, wherein the second simulation method comprises a space-fitted finite difference simulation method.

6004. The method of claim 5999, wherein at least one first process characteristic comprises a process characteristic at a sharp interface in the formation.

6005. The method of claim 5999, wherein at least one first process characteristic comprises a process characteristic at a combustion front in the formation.

6006. The method of claim 5999, wherein modifying the one or more model parameters comprises changing the order of a chemical reaction.

6007. The method of claim 5999, wherein modifying the one or more model parameters comprises adding one or more chemical reactions.

6008. The method of claim 5999, wherein modifying the one or more model parameters comprises changing an activation energy.

6009. The method of claim 5999, wherein modifying the one or more model parameters comprises changing a frequency factor.

6010. A method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, comprising:

providing to the computer system one or more values of at least one operating condition of the in situ process, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

assessing one or more values of at least one process characteristic corresponding to one or more values of at least one operating condition using a simulation method;

providing a desired value of at least one process characteristic for the in situ process to the computer system; and

assessing a desired value of at least one operating condition to achieve the desired value of at least one process characteristic from the assessed values of at least one process characteristic and the provided values of at least one operating condition.

6011. The method of claim 6010, further comprising operating the in situ system using the desired value of at least one operating condition.

6012. The method of claim 6010, wherein the process comprises providing heat from one or more heaters to at least one portion of the formation.

6013. The method of claim 6010, wherein the process comprises allowing heat to transfer from one or more heaters to a selected section of the formation.

6014. The method of claim 6010, wherein a value of at least one process characteristic comprises the process characteristic as a function of time.

6015. The method of claim 6010, further comprising determining a value of at least one process characteristic based on the desired value of at least one operating condition using the simulation method.

6016. The method of claim 6010, wherein determining the desired value of at least one operating condition comprises interpolating the desired value from the determined values of at least one process characteristic and the provided values of at least one operating condition.

6017. A method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, comprising:

providing a desired value of at least one process characteristic for the in situ process to the computer system, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

assessing a value of at least one operating condition to achieve the desired value of at least one process characteristic, wherein such assessing comprises using a relationship between at least one process characteristic and at least one operating condition for the in situ process, wherein such relationship is stored on a database accessible by the computer system.

6018. The method of claim 6017, further comprising operating the in situ system using the desired value of at least one operating condition.

6019. The method of claim 6017, wherein the process comprises providing heat from one or more heaters to at least one portion of the formation.

6020. The method of claim 6017, wherein the process comprises providing heat to transfer from one or more heaters to a selected section of the formation.

6021. The method of claim 6017, wherein the relationship is determined from one or more simulations of the in situ process using a simulation method.

6022. The method of claim 6017, wherein the relationship comprises one or more values of at least one process characteristic and corresponding values of at least one operating condition.

6023. The method of claim 6017, wherein the relationship comprises an analytical function.

6024. The method of claim 6017, wherein determining the value of at least one operating condition comprises interpolating the value of at least one operating condition from the relationship.

6025. The method of claim 6017, wherein at least one process characteristic comprises a selected composition of produced fluids.

6026. The method of claim 6017, wherein at least one operating condition comprises a pressure.

6027. The method of claim 6017, wherein at least one operating condition comprises a heat input rate.

6028. A system, comprising:

a CPU;

a data memory coupled to the CPU; and

a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, the method comprising;

providing at least one property of the formation to the computer system;

providing at least one operating condition of the process to the computer system, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

assessing at least one process characteristic of the in situ process using a simulation method on the computer system, and using at least one property of the formation and at least one operating condition.

6029. A carrier medium comprising program instructions, wherein the program instructions are computer-executable to implement a method comprising:

providing at least one property of the formation to the computer system;

providing at least one operating condition of the process to the computer system, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

assessing at least one process characteristic of the in situ process using a simulation method on the computer system, and using at least one property of the formation and at least one operating condition.

6030. A system, comprising:

a CPU;

a data memory coupled to the CPU; and

a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, the method comprising;

simulating a heat input rate to the formation from two or more heaters on the computer system, wherein heat is allowed to transfer from the heaters to a selected section of the formation;

providing at least one desired parameter of the in situ process to the computer system; and

controlling the heat input rate from the heaters to achieve at least one desired parameter.

6031. A carrier medium comprising program instructions, wherein the program instructions are computer-executable to implement a method comprising:

simulating a heat input rate to the formation from two or more heaters on the computer system, wherein heat is allowed to transfer from the heaters to a selected section of the formation;

providing at least one desired parameter of the in situ process to the computer system; and

controlling the heat input rate from the heaters to achieve at least one desired parameter.

6032. A system, comprising:

a CPU;

a data memory coupled to the CPU; and

a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, the method comprising;

providing at least one heat input property to the computer system;

assessing heat injection rate data for the formation using a first simulation method on the computer system;

providing at least one property of the formation to the computer system;

assessing at least one process characteristic of the in situ process from the heat injection rate data and at least one property of the formation using a second simulation method; and

wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation.

6033. A carrier medium comprising program instructions, wherein the program instructions are computer-executable to implement a method comprising:

providing at least one heat input property to the computer system;

assessing heat injection rate data for the formation using a first simulation method on the computer system;

providing at least one property of the formation to the computer system;

assessing at least one process characteristic of the in situ process from the heat injection rate data and at least one property of the formation using a second simulation method; and

wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation.

6034. A system, comprising:

a CPU;

a data memory coupled to the CPU; and

a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, the method comprising;

providing one or more model parameters for the in situ process to the computer system;

assessing one or more simulated process characteristics based on one or more model parameters using a simulation method;

modifying one or more model parameters such that at least one simulated process characteristic matches or approximates at least one real process characteristic;

assessing one or more modified simulated process characteristics based on the modified model parameters; and

wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation.

6035. A carrier medium comprising program instructions, wherein the program instructions are computer-executable to implement a method comprising:

providing one or more model parameters for the in situ process to the computer system;

assessing one or more simulated process characteristics based on one or more model parameters using a simulation method;

modifying one or more model parameters such that at least one simulated process characteristic matches or approximates at least one real process characteristic;

assessing one or more modified simulated process characteristics based on the modified model parameters; and

wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation.

6036. A system, comprising:

a CPU;

a data memory coupled to the CPU; and

a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, the method comprising;

assessing at least one operating condition of the in situ process using a simulation method based on one or more model parameter;

modifying at least one model parameter such that at least one simulated process characteristic of the in situ process matches or approximates at least one real process characteristic of the in situ process;

assessing one or more modified simulated process characteristics based on the modified model parameters; and

wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation simulated process characteristics based on the modified model parameters.

6037. A carrier medium comprising program instructions, wherein the program instructions are computer-executable to implement a method comprising:

assessing at least one operating condition of the in situ process using a simulation method based on one or more model parameter;

modifying at least one model parameter such that at least one simulated process characteristic of the in situ process matches or approximates at least one real process characteristic of the in situ process;

assessing one or more modified simulated process characteristics based on the modified model parameters; and

wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation.

6038. A system, comprising:

a CPU;

a data memory coupled to the CPU; and

a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, the method comprising;

providing one or more model parameters to the computer system;

assessing one or more first process characteristics based on one or more model parameters using a first simulation method on the computer system;

assessing one or more second process characteristics based on one or more model parameters using a second simulation method on the computer system;

modifying one or more model parameters such that at least one first process characteristic matches or approximates at least one second process characteristic; and

wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation.

6039. A carrier medium comprising program instructions, wherein the program instructions are computer-executable to implement a method comprising:

providing one or more model parameters to the computer system;

assessing one or more first process characteristics based on one or more model parameters using a first simulation method on the computer system;

assessing one or more second process characteristics based on one or more model parameters using a second simulation method on the computer system;

modifying one or more model parameters such that at least one first process characteristic matches at least one second process characteristic; and

wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation.

6040. A system, comprising:

a CPU;

a data memory coupled to the CPU; and

a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, the method comprising;

providing to the computer system one or more values of at least one operating condition of the in situ process, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

assessing one or more values of at least one process characteristic corresponding to one or more values of at least one operating condition using a simulation method;

providing a desired value of at least one process characteristic for the in situ process to the computer system; and

assessing a desired value of at least one operating condition to achieve the desired value of at least one process characteristic from the assessed values of at least one process characteristic and the provided values of at least one operating condition.

6041. A carrier medium comprising program instructions, wherein the program instructions are computer-executable to implement a method comprising:

providing to the computer system one or more values of at least one operating condition of the in situ process, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

assessing one or more values of at least one process characteristic corresponding to one or more values of at least one operating condition using a simulation method;

providing a desired value of at least one process characteristic for the in situ process to the computer system; and

assessing a desired value of at least one operating condition to achieve the desired value of at least one process characteristic from the assessed values of at least one process characteristic and the provided values of at least one operating condition.

6042. A system, comprising:

a CPU;

a data memory coupled to the CPU; and

a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, the method comprising;

providing a desired value of at least one process characteristic for the in situ process to the computer system, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

assessing a value of at least one operating condition to achieve the desired value of at least one process characteristic, wherein such assessing comprises using a relationship between at least one process characteristic and at least one operating condition for the in situ process, wherein such relationship is stored on a database accessible by the computer system.

6043. A carrier medium comprising program instructions, wherein the program instructions are computer-executable to implement a method comprising:

providing a desired value of at least one process characteristic for the in situ process to the computer system, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

assessing a value of at least one operating condition to achieve the desired value of at least one process characteristic, wherein such assessing comprises using a relationship between at least one process characteristic and at least one operating condition for the in situ process, wherein such relationship is stored on a database accessible by the computer system.

6044. A method of using a computer system for operating an in situ process for treating a hydrocarbon containing formation, comprising:

operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing at least one operating parameter of the in situ process to the computer system; and

using at least one parameter with a simulation method and the computer system to provide assessed information about the in situ process.

6045. The method of claim 6044, wherein one or more of the operating parameters comprise a thickness of a treated portion of the formation.

6046. The method of claim 6044, wherein one or more of the operating parameters comprise an area of a treated portion of the formation.

6047. The method of claim 6044, wherein one or more of the operating parameters comprise a volume of a treated portion of the formation.

6048. The method of claim 6044, wherein one or more of the operating parameters comprise a property of the formation.

6049. The method of claim 6044, wherein one or more of the operating parameters comprise a heat capacity of the formation.

6050. The method of claim 6044, wherein one or more of the operating parameters comprise a permeability of the formation.

6051. The method of claim 6044, wherein one or more of the operating parameters comprise a density of the formation.

6052. The method of claim 6044, wherein one or more of the operating parameters comprise a thermal conductivity of the formation.

6053. The method of claim 6044, wherein one or more of the operating parameters comprise a porosity of the formation.

6054. The method of claim 6044, wherein one or more of the operating parameters comprise a pressure.

6055. The method of claim 6044, wherein one or more of the operating parameters comprise a temperature.

6056. The method of claim 6044, wherein one or more of the operating parameters comprise a heating rate.

6057. The method of claim 6044, wherein one or more of the operating parameters comprise a process time.

6058. The method of claim 6044, wherein one or more of the operating parameters comprises a location of producer wells.

6059. The method of claim 6044, wherein one or more of the operating parameters comprise an orientation of producer wells.

6060. The method of claim 6044, wherein one or more of the operating parameters comprise a ratio of producer wells to heater wells.

6061. The method of claim 6044, wherein one or more of the operating parameters comprise a spacing between heater wells.

6062. The method of claim 6044, wherein one or more of the operating parameters comprise a distance between an overburden and horizontal heater wells.

6063. The method of claim 6044, wherein one or more of the operating parameters comprise a type of pattern of heater wells.

6064. The method of claim 6044, wherein one or more of the operating parameters comprise an orientation of heater wells.

6065. The method of claim 6044, wherein one or more of the operating parameters comprise a mechanical property.

6066. The method of claim 6044, wherein one or more of the operating parameters comprise subsidence of the formation.

6067. The method of claim 6044, wherein one or more of the operating parameters comprise fracture progression in the formation.

6068. The method of claim 6044, wherein one or more of the operating parameters comprise heave of the formation.

6069. The method of claim 6044, wherein one or more of the operating parameters comprise compaction of the formation.

6070. The method of claim 6044, wherein one or more of the operating parameters comprise shear deformation of the formation.

6071. The method of claim 6044, wherein the assessed information comprises information relating to properties of the formation.

6072. The method of claim 6044, wherein the assessed information comprises a relationship between one or more operating parameters and at least one other operating parameter.

6073. The method of claim 6044, wherein the computer system is remote from the in situ process.

6074. The method of claim 6044, wherein the computer system is located at or near the in situ process.

6075. The method of claim 6044, wherein at least one parameter is provided to the computer system using hardwire communication.

6076. The method of claim 6044, wherein at least one parameter is provided to the computer system using internet communication.

6077. The method of claim 6044, wherein at least one parameter is provided to the computer system using wireless communication.

6078. The method of claim 6044, wherein the one or more parameters are monitored using sensors in the formation.

6079. The method of claim 6044, wherein at least one parameter is provided automatically to the computer system.

6080. The method of claim 6044, wherein using at least one parameter with a simulation method comprises performing a simulation and obtaining properties of the formation.

6081. A method of using a computer system for operating an in situ process for treating a hydrocarbon containing formation, comprising:

operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing at least one operating parameter of the in situ process to the computer system;

using at least one parameter with a simulation method and the computer system to provide assessed information about the in situ process; and

using the assessed information to operate the in situ process.

6082. The method of claim 6081, further comprising providing the assessed information to a computer system used for controlling the in situ process.

6083. The method of claim 6081, wherein the computer system is remote from the in situ process.

6084. The method of claim 6081, wherein the computer system is located at or near the in situ process.

6085. The method of claim 6081, wherein using the assessed information to operate the in situ process comprises:

modifying at least one operating parameter; and

operating the in situ process with at least one modified operating parameter.

6086. A method of using a computer system for operating an in situ process for treating a hydrocarbon containing formation, comprising

operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing at least one operating parameter of the in situ process to the computer system;

using at least one parameter with a first simulation method and the computer system to provide assessed information about the in situ process; and

obtaining information from a second simulation method and the computer system using the assessed information and a desired parameter.

6087. The method of claim 6086, further comprising using the obtained information to operate the in situ process.

6088. The method of claim 6086, wherein the first simulation method is the same as the second simulation method.

6089. The method of claim 6086, further comprising providing the obtained information to a computer system used for controlling the in situ process.

6090. The method of claim 6086, wherein using the obtained information to operate the in situ process comprises:

modifying at least one operating parameter; and

operating the in situ process with at least one modified operating parameter.

6091. The method of claim 6086, wherein the obtained information comprises at least one operating parameter for use in the in situ process that achieves the desired parameter.

6092. The method of claim 6086, wherein the computer system is remote from the in situ process.

6093. The method of claim 6086, wherein the computer system is located at or near the in situ process.

6094. The method of claim 6086, wherein the desired parameter comprises a selected gas to oil ratio.

6095. The method of claim 6086, wherein the desired parameter comprises a selected production rate of fluid produced from the formation.

6096. The method of claim 6086, wherein the desired parameter comprises a selected production rate of fluid at a selected time produced from the formation.

6097. The method of claim 6086, wherein the desired parameter comprises a selected olefin content of produced fluids.

6098. The method of claim 6086, wherein the desired parameter comprises a selected carbon number distribution of produced fluids.

6099. The method of claim 6086, wherein the desired parameter comprises a selected ethene to ethane ratio of produced fluids.

6100. The method of claim 6086, wherein the desired parameter comprises a desired atomic carbon to hydrogen ratio of produced fluids.

6101. The method of claim 6086, wherein the desired parameter comprises a selected gas to oil ratio of produced fluids.

6102. The method of claim 6086, wherein the desired parameter comprises a selected pressure in the formation.

6103. The method of claim 6086, wherein the desired parameter comprises a selected total mass recovery from the formation.

6104. The method of claim 6086, wherein the desired parameter comprises a selected production rate of fluid produced from the formation.

6105. A system, comprising:

a CPU;

a data memory coupled to the CPU; and

a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for operating an in situ process for treating a hydrocarbon containing formation, comprising;

operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing at least one operating parameter of the in situ process to the computer system; and

using at least one parameter with a simulation method and the computer system to provide assessed information about the in situ process.

6106. A carrier medium comprising program instructions, wherein the program instructions are computer-executable to implement a method comprising:

operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing at least one operating parameter of the in situ process to the computer system; and

using at least one parameter with a simulation method and the computer system to provide assessed information about the in situ process.

6107. A system, comprising:

a CPU;

a data memory coupled to the CPU; and

a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for operating an in situ process for treating a hydrocarbon containing formation, comprising;

operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing at least one operating parameter of the in situ process to the computer system;

using at least one parameter with a simulation method and the computer system to provide assessed information about the in situ process; and

using the assessed information to operate the in situ process.

6108. A carrier medium comprising program instructions, wherein the program instructions are computer-executable to implement a method comprising:

operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing at least one operating parameter of the in situ process to the computer system;

using at least one parameter with a simulation method and the computer system to provide assessed information about the in situ process; and

using the assessed information to operate the in situ process.

6109. A system, comprising:

a CPU;

a data memory coupled to the CPU; and

a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for operating an in situ process for treating a hydrocarbon containing formation, comprising;

operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing at least one operating parameter of the in situ process to the computer system;

using at least one parameter with a first simulation method and the computer system to provide assessed information about the in situ process; and

obtaining information from a second simulation method and the computer system using the assessed information and a desired parameter.

6110. A carrier medium comprising program instructions, wherein the program instructions are computer-executable to implement a method comprising:

operating the in situ process using one or more operating parameters, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing at least one operating parameter of the in situ process to the computer system;

using at least one parameter with a first simulation method and the computer system to provide assessed information about the in situ process; and

obtaining information from a second simulation method and the computer system using the assessed information and a desired parameter.

6111. A method of modeling one or more stages of a process for treating a hydrocarbon containing formation in situ with a simulation method using a computer system, comprising:

providing at least one property of the formation to the computer system;

providing at least one operating condition for the one or more stages of the in situ process to the computer system, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

assessing at least one process characteristic of the one or more stages using the simulation method.

6112. The method of claim 6111, wherein the simulation method is a body-fitted finite difference simulation method.

6113. The method of claim 6111, wherein the simulation method is a reservoir simulation method.

6114. The method of claim 6111, wherein the simulation method is a space-fitted finite difference simulation method.

6115. The method of claim 6111, wherein the simulation method simulates heating of the formation.

6116. The method of claim 6111, wherein the simulation method simulates fluid flow in the formation.

6117. The method of claim 6111, wherein the simulation method simulates mass transfer in the formation.

6118. The method of claim 6111, wherein the simulation method simulates heat transfer in the formation.

6119. The method of claim 6111, wherein the simulation method simulates chemical reactions in the one or more stages of the process in the formation.

6120. The method of claim 6111, wherein the simulation method simulates removal of contaminants from the formation.

6121. The method of claim 6111, wherein the simulation method simulates recovery of heat from the formation.

6122. The method of claim 6111, wherein the simulation method simulates injection of fluids into the formation.

6123. The method of claim 6111, wherein the one or more stages comprise heating of the formation.

6124. The method of claim 6111, wherein the one or more stages comprise generation of pyrolyzation fluids.

6125. The method of claim 6111, wherein the one or more stages comprise remediation of the formation.

6126. The method of claim 6111, wherein the one or more stages comprise shut-in of the formation.

6127. The method of claim 6111, wherein at least one operating condition of a remediation stage is the flow rate of ground water into the formation.

6128. The method of claim 6111, wherein at least one operating condition of a remediation stage is the flow rate of injected fluids into the formation.

6129. The method of claim 6111, wherein at least one process characteristic of a remediation stage is the concentration of contaminants in the formation.

6130. The method of claim 6111, further comprising:

providing to the computer system at least one set of operating conditions for at least one of the stages of the in situ process, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing to the computer system at least one desired process characteristic for at least one of the stages of the in situ process; and

assessing at least one additional operating condition for at least one of the stages that achieves at least one desired process characteristic for at least one of the stages.

6131. A method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, comprising:

providing at least one property of the formation to a computer system;

providing at least one operating condition to the computer system;

assessing at least one process characteristic of the in situ process, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

assessing at least one deformation characteristic of the formation using a simulation method from at least one property, at least one operating condition, and at least one process characteristic.

6132. The method of claim 6131, wherein the in situ process comprises two or more heaters.

6133. The method of claim 6131, wherein the in situ process provides heat from one or more heaters to at least one portion of the formation.

6134. The method of claim 6131, wherein the simulation method comprises a finite element simulation method.

6135. The method of claim 6131, wherein the formation comprises a treated portion and an untreated portion.

6136. The method of claim 6131, wherein at least one deformation characteristic comprises subsidence.

6137. The method of claim 6131, wherein at least one deformation characteristic comprises heave.

6138. The method of claim 6131, wherein at least one deformation characteristic comprises compaction.

6139. The method of claim 6131, wherein at least one deformation characteristic comprises shear deformation.

6140. The method of claim 6131, wherein at least one operating condition comprises a pressure.

6141. The method of claim 6131, wherein at least one operating condition comprises a temperature.

6142. The method of claim 6131, wherein at least one operating condition comprises a process time.

6143. The method of claim 6131, wherein at least one operating condition comprises a rate of pressure increase.

6144. The method of claim 6131, wherein at least one operating condition comprises a heating rate.

6145. The method of claim 6131, wherein at least one operating condition comprises a width of a treated portion of the formation.

6146. The method of claim 6131, wherein at least one operating condition comprises a thickness of a treated portion of the formation.

6147. The method of claim 6131, wherein at least one operating condition comprises a thickness of an overburden of the formation.

6148. The method of claim 6131, wherein at least one process characteristic comprises a pore pressure distribution in the formation.

6149. The method of claim 6131, wherein at least one process characteristic comprises a temperature distribution in the formation.

6150. The method of claim 6131, wherein at least one process characteristic comprises a heat input rate.

6151. The method of claim 6131, wherein at least one property comprises a physical property of the formation.

6152. The method of claim 6131, wherein at least one property comprises richness of the formation.

6153. The method of claim 6131, wherein at least one property comprises a heat capacity.

6154. The method of claim 6131, wherein at least one property comprises a thermal conductivity.

6155. The method of claim 6131, wherein at least one property comprises a coefficient of thermal expansion.

6156. The method of claim 6131, wherein at least one property comprises a mechanical property.

6157. The method of claim 6131, wherein at least one property comprises an elastic modulus.

6158. The method of claim 6131, wherein at least one property comprises a Poisson'"'"'s ratio.

6159. The method of claim 6131, wherein at least one property comprises cohesion stress.

6160. The method of claim 6131, wherein at least one property comprises a friction angle.

6161. The method of claim 6131, wherein at least one property comprises a cap eccentricity.

6162. The method of claim 6131, wherein at least one property comprises a cap yield stress.

6163. The method of claim 6131, wherein at least one property comprises a cohesion creep multiplier.

6164. The method of claim 6131, wherein at least one property comprises a thermal expansion coefficient.

6165. A method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, comprising:

providing to the computer system at least one set of operating conditions for the in situ process, wherein the process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing to the computer system at least one desired deformation characteristic for the in situ process; and

assessing at least one additional operating condition of the formation that achieves at least one desired deformation characteristic.

6166. The method of claim 6165, further comprising operating the in situ system using at least one additional operating condition.

6167. The method of claim 6165, wherein the in situ process comprises two or more heaters.

6168. The method of claim 6165, wherein the in situ process provides heat from one or more heaters to at least one portion of the formation.

6169. The method of claim 6165, wherein the in situ process allows heat to transfer from one or more heaters to a selected section of the formation.

6170. The method of claim 6165, wherein at least one set of operating conditions comprises at least one set of pressures.

6171. The method of claim 6165, wherein at least one set of operating conditions comprises at least one set of temperatures.

6172. The method of claim 6165, wherein at least one set of operating conditions comprises at least one set of heating rates.

6173. The method of claim 6165, wherein at least one set of operating conditions comprises at least one set of overburden thicknesses.

6174. The method of claim 6165, wherein at least one set of operating conditions comprises at least one set of thicknesses of a treated portion of the formation.

6175. The method of claim 6165, wherein at least one set of operating conditions comprises at least one set of widths of a treated portion of the formation.

6176. The method of claim 6165, wherein at least one set of operating conditions comprises at least one set of radii of a treated portion of the formation.

6177. The method of claim 6165, wherein at least one desired deformation characteristic comprises a selected subsidence.

6178. The method of claim 6165, wherein at least one desired deformation characteristic comprises a selected heave.

6179. The method of claim 6165, wherein at least one desired deformation characteristic comprises a selected compaction.

6180. The method of claim 6165, wherein at least one desired deformation characteristic comprises a selected shear deformation.

6181. A method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, comprising:

providing one or more values of at least one operating condition;

assessing one or more values of at least one deformation characteristic using a simulation method based on the one or more values of at least one operating condition;

providing a desired value of at least one deformation characteristic for the in situ process to the computer system, wherein the process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

assessing a desired value of at least one operating condition that achieves the desired value of at least one deformation characteristic from the determined values of at least one deformation characteristic and the provided values of at least one operating condition.

6182. The method of claim 6181, further comprising operating the in situ process using the desired value of at least one operating condition.

6183. The method of claim 6181, wherein the in situ process comprises two or more heaters.

6184. The method of claim 6181, wherein at least one operating condition comprises a pressure.

6185. The method of claim 6181, wherein at least one operating condition comprises a heat input rate.

6186. The method of claim 6181, wherein at least one operating condition comprises a temperature.

6187. The method of claim 6181, wherein at least one operating condition comprises a heating rate.

6188. The method of claim 6181, wherein at least one operating condition comprises an overburden thickness.

6189. The method of claim 6181, wherein at least one operating condition comprises a thickness of a treated portion of the formation.

6190. The method of claim 6181, wherein at least one operating condition comprises a width of a treated portion of the formation.

6191. The method of claim 6181, wherein at least one operating condition comprises a radius of a treated portion of the formation.

6192. The method of claim 6181, wherein at least one deformation characteristic comprises subsidence.

6193. The method of claim 6181, wherein at least one deformation characteristic comprises heave.

6194. The method of claim 6181, wherein at least one deformation characteristic comprises compaction.

6195. The method of claim 6181, wherein at least one deformation characteristic comprises shear deformation.

6196. The method of claim 6181, wherein a value of at least one formation characteristic comprises the formation characteristic as a function of time.

6197. The method of claim 6181, further comprising determining a value of at least one deformation characteristic based on the desired value of at least one operating condition using the simulation method.

6198. The method of claim 6181, wherein determining the desired value of at least one operating condition comprises interpolating the desired value from the determined values of at least one formation characteristic and the provided values of at least one operating condition.

6199. A method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, comprising:

providing a desired value of at least one deformation characteristic for the in situ process to the computer system, wherein the in situ process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the in situ process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

assessing a value of at least one operating condition to achieve the desired value of at least one deformation characteristic from a database in memory on the computer system comprising a relationship between at least one deformation characteristic and at least one operating condition for the in situ process.

6200. The method of claim 6199, further comprising operating the in situ system using the desired value of at least one operating condition.

6201. The method of claim 6199, wherein the in situ system comprises two or more heaters.

6202. The method of claim 6199, wherein the relationship is determined from one or more simulations of the in situ process using a simulation method.

6203. The method of claim 6199, wherein the relationship comprises one or more values of at least one deformation characteristic and corresponding values of at least one operating condition.

6204. The method of claim 6199, wherein the relationship comprises an analytical function.

6205. The method of claim 6199, wherein determining a value of at least one operating condition comprises interpolating a value of at least one operating condition from the relationship.

6206. A system, comprising:

a CPU;

a data memory coupled to the CPU; and

a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, the method comprising;

providing at least one property of the formation to a computer system;

providing at least one operating condition to the computer system;

determining at least one process characteristic of the in situ process, wherein the process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

determining at least one deformation characteristic of the formation using a simulation method from at least one property, at least one operating condition, and at least one process characteristic.

6207. A carrier medium comprising program instructions, wherein the program instructions are computer-executable to implement a method comprising:

providing at least one property of the formation to a computer system;

providing at least one operating condition to the computer system;

determining at least one process characteristic of the in situ process, wherein the process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

determining at least one deformation characteristic of the formation using a simulation method from at least one property, at least one operating condition, and at least one process characteristic.

6208. A system, comprising:

a CPU;

a data memory coupled to the CPU; and

a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, the method comprising;

providing to the computer system at least one set of operating conditions for the in situ process, wherein the process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing to the computer system at least one desired deformation characteristic for the in situ process; and

determining at least one additional operating condition of the formation that achieves at least one desired deformation characteristic.

6209. A carrier medium comprising program instructions, wherein the program instructions are computer-executable to implement a method comprising:

providing to the computer system at least one set of operating conditions for the in situ process, wherein the process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing to the computer system at least one desired deformation characteristic for the in situ process; and

determining at least one additional operating condition of the formation that achieves at least one desired deformation characteristic.

6210. A system, comprising:

a CPU;

a data memory coupled to the CPU; and

a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, the method comprising;

providing one or more values of at least one operating condition;

determining one or more values of at least one deformation characteristic using a simulation method based on the one or more values of at least one operating condition;

providing a desired value of at least one deformation characteristic for the in situ process to the computer system, wherein the process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

determining a desired value of at least one operating condition that achieves the desired value of at least one deformation characteristic from the determined values of at least one deformation characteristic and the provided values of at least one operating condition.

6211. A carrier medium comprising program instructions, wherein the program instructions are computer-executable to implement a method comprising:

providing one or more values of at least one operating condition;

determining one or more values of at least one deformation characteristic using a simulation method based on the one or more values of at least one operating condition;

providing a desired value of at least one deformation characteristic for the in situ process to the computer system, wherein the process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

determining a desired value of at least one operating condition that achieves the desired value of at least one deformation characteristic from the determined values of at least one deformation characteristic and the provided values of at least one operating condition.

6212. A system, comprising:

a CPU;

a data memory coupled to the CPU; and

a system memory coupled to the CPU, wherein the system memory is configured to store one or more computer programs executable by the CPU, and wherein the computer programs are executable to implement a method of using a computer system for modeling an in situ process for treating a hydrocarbon containing formation, the method comprising;

providing a desired value of at least one deformation characteristic for the in situ process to the computer system, wherein the process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

determining a value of at least one operating condition to achieve the desired value of at least one deformation characteristic from a database in memory on the computer system comprising a relationship between at least one formation characteristic and at least one operating condition for the in situ process.

6213. A carrier medium comprising program instructions, wherein the program instructions are computer-executable to implement a method comprising:

providing a desired value of at least one deformation characteristic for the in situ process to the computer system, wherein the process comprises providing heat from one or more heaters to at least one portion of the formation, and wherein the process comprises allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

determining a value of at least one operating condition to achieve the desired value of at least one deformation characteristic from a database in memory on the computer system comprising a relationship between at least one formation characteristic and at least one operating condition for the in situ process.

6214. A system configurable to provide heat to a hydrocarbon containing formation, comprising:

a first oxidizer configurable to be placed in an opening in the formation, wherein the first oxidizer is configurable to oxidize a first fuel during use;

a second oxidizer configurable to be placed in the opening, wherein the second oxidizer is configurable to oxidize a second fuel during use; and

wherein the system is configurable to allow heat from oxidation of the first fuel or the second fuel to transfer to the formation during use.

6215. The system of claim 6214, wherein the system is configured to provide heat to the hydrocarbon containing formation.

6216. The system of claim 6214, wherein the first oxidizer is configured to be placed in an opening in the formation and wherein the first oxidizer is configured to oxidize the first fuel during use.

6217. The system of claim 6214, wherein the second oxidizer is configured to be placed in the opening and wherein the second oxidizer is configured to oxidize the second fuel during use.

6218. The system of claim 6214, wherein the system is configured to allow the heat from the oxidation to transfer to the formation during use.

6219. The system of claim 6214, wherein the first oxidizer comprises a burner.

6220. The system of claim 6214, wherein the first oxidizer comprises an inline burner.

6221. The system of claim 6214, wherein the second oxidizer comprises a burner.

6222. The system of claim 6214, wherein the second oxidizer comprises a ring burner.

6223. The system of claim 6214, wherein a distance between the first oxidizer and the second oxidizer is less than about 250 meters.

6224. The system of claim 6214, further comprising a conduit configurable to be placed in the opening.

6225. The system of claim 6214, further comprising a conduit configurable to be placed in the opening, wherein the conduit is configurable to provide an oxidizing fluid to the first oxidizer during use.

6226. The system of claim 6214, further comprising a conduit configurable to be placed in the opening, wherein the conduit is configurable to provide the first fuel to the first oxidizer during use.

6227. The system of claim 6214, further comprising a conduit configurable to be placed in the opening, wherein the conduit is configurable to provide an oxidizing fluid to the second oxidizer during use.

6228. The system of claim 6214, further comprising a conduit configurable to be placed in the opening, wherein the conduit is configurable to provide the second fuel to the second oxidizer during use.

6229. The system of claim 6214, further comprising a third oxidizer configurable to be placed in the opening, wherein the third oxidizer is configurable to oxidize a third fuel during use.

6230. The system of claim 6214, further comprising a fuel source, wherein the fuel source is configurable to provide the first fuel to the first oxidizer or the second fuel to the second oxidizer during use.

6231. The system of claim 6214, wherein the first fuel is different from the second fuel.

6232. The system of claim 6214, wherein the first fuel is different from the second fuel, wherein the second fuel comprises hydrogen.

6233. The system of claim 6214, wherein a flow of the first fuel is separately controlled from a flow of the second fuel.

6234. The system of claim 6214, wherein the first oxidizer is configurable to be placed proximate an upper portion of the opening.

6235. The system of claim 6214, wherein the second oxidizer is configurable to be placed proximate a lower portion of the opening.

6236. The system of claim 6214, further comprising insulation configurable to be placed proximate the first oxidizer.

6237. The system of claim 6214, further comprising insulation configurable to be placed proximate the second oxidizer.

6238. The system of claim 6214, wherein products from oxidation of the first fuel or the second fuel are removed from the formation through the opening during use.

6239. The system of claim 6214, further comprising an exhaust conduit configurable to be coupled to the opening to allow exhaust fluid to flow from the formation through the exhaust conduit during use.

6240. The system of claim 6214, wherein the system is configured to allow the heat from the oxidation of the first fuel or the second fuel to transfer to the formation during use.

6241. The system of claim 6214, wherein the system is configured to allow the heat from the oxidation to transfer to a pyrolysis zone in the formation during use.

6242. The system of claim 6214, wherein the system is configured to allow the heat from the oxidation to transfer to a pyrolysis zone in the formation during use, and wherein the transferred heat causes pyrolysis of at least some hydrocarbons in the pyrolysis zone during use.

6243. The system of claim 6214, wherein at least some of the heat from the oxidation is generated at the first oxidizer.

6244. The system of claim 6214, wherein at least some of the heat from the oxidation is generated at the second oxidizer.

6245. The system of claim 6214, wherein a combination of heat from the first oxidizer and heat from the second oxidizer substantially uniformly heats a portion of the formation during use.

6246. The system of claim 6214, further comprising a first conduit configurable to be placed in the opening of the formation, wherein the first conduit is configurable to provide a first oxidizing fluid to the first oxidizer in the opening during use, and wherein the first conduit is further configurable to provide a second oxidizing fluid to the second oxidizer in the opening during use.

6247. The system of claim 6246, further comprising a fuel conduit configurable to be placed in the opening, wherein the fuel conduit is further configurable to provide the first fuel to the first oxidizer during use.

6248. The system of claim 6247, wherein the fuel conduit is further configurable to be placed in the first conduit.

6249. The system of claim 6247, wherein the first conduit is further configurable to be placed in the fuel conduit.

6250. The system of claim 6246, further comprising a fuel conduit configurable to be placed in the opening, wherein the fuel conduit is further configurable to provide the second fuel to the second oxidizer during use.

6251. The system of claim 6246, wherein the first conduit is further configurable to provide the first fuel to the first oxidizer during use.

6252. An in situ method for heating a hydrocarbon containing formation, comprising:

providing a first oxidizing fluid to a first oxidizer placed in an opening in the formation;

providing a first fuel to the first oxidizer;

oxidizing at least some of the first fuel in the first oxidizer;

providing a second oxidizing fluid to a second oxidizer placed in the opening in the formation;

providing a second fuel to the second oxidizer;

oxidizing at least some of the second fuel in the second oxidizer; and

allowing heat from oxidation of the first fuel and the second fuel to transfer to a portion of the formation.

6253. The method of claim 6252, wherein the first oxidizing fluid is provided to the first oxidizer through a conduit placed in the opening.

6254. The method of claim 6252, wherein the second oxidizing fluid is provided to the second oxidizer through a conduit placed in the opening.

6255. The method of claim 6252, wherein the first fuel is provided to the first oxidizer through a conduit placed in the opening.

6256. The method of claim 6252, wherein the first fuel is provided to the second oxidizer through a conduit placed in the opening.

6257. The method of claim 6252, wherein the first oxidizing fluid and the first fuel are provided to the first oxidizer through a conduit placed in the opening.

6258. The method of claim 6252, further comprising using exhaust fluid from the first oxidizer as a portion of the second fuel used in the second oxidizer.

6259. The method of claim 6252, further comprising allowing the heat to transfer substantially by conduction from the portion of the formation to a pyrolysis zone of the formation.

6260. The method of claim 6252, further comprising initiating oxidation of the second fuel in the second oxidizer with an ignition source.

6261. The method of claim 6252, further comprising removing exhaust fluids through the opening.

6262. The method of claim 6252, further comprising removing exhaust fluids through the opening, wherein the exhaust fluids comprise heat and allowing at least some heat in the exhaust fluids to transfer from the exhaust fluids to the first oxidizing fluid prior to oxidation in the first oxidizer.

6263. The method of claim 6252, further comprising removing exhaust fluids comprising heat through the opening, allowing at least some heat in the exhaust fluids to transfer from the exhaust fluids to the first oxidizing fluid prior to oxidation, and increasing a thermal efficiency of heating the hydrocarbon containing formation.

6264. The method of claim 6252, further comprising removing exhaust fluids through an exhaust conduit coupled to the opening.

6265. The method of claim 6252, further comprising removing exhaust fluids through an exhaust conduit coupled to the opening and providing at least a portion of the exhaust fluids to a fourth oxidizer to be used as a fourth fuel in a fourth oxidizer, wherein the fourth oxidizer is located in a separate opening in the formation.

6266. A system configurable to provide heat to a hydrocarbon containing formation, comprising:

an opening placed in the formation, wherein the opening comprises a first elongated portion, a second elongated portion, and a third elongated portion, wherein the second elongated portion diverges from the first elongated portion in a first direction, wherein the third elongated portion diverges from the first elongated portion in a second direction, and wherein the first direction is substantially different than the second direction;

a first heater configurable to be placed in the second elongated portion, wherein the first heater is configurable to heat at least a portion of the formation during use;

a second heater configurable to be placed in the third elongated portion, wherein the second heater is configurable to heat to at least a portion of the formation during use; and

wherein the system is configurable to allow heat to transfer to the formation during use.

6267. The system of claim 6266, wherein the first heater and the second heater are configurable to heat to at least a portion of the formation during use.

6268. The system of claim 6266, wherein the second and the third elongated portions are oriented substantially horizontally within the formation.

6269. The system of claim 6266, wherein the first direction is about 180°

opposite the second direction.

6270. The system of claim 6266, wherein the first elongated portion is placed substantially within an overburden of the formation.

6271. The system of claim 6266, wherein the transferred heat substantially uniformly heats a portion of the formation during use.

6272. The system of claim 6266, wherein the first heater or the second heater comprises a downhole combustor.

6273. The system of claim 6266, wherein the first heater or the second heater comprises an insulated conductor heater.

6274. The system of claim 6266, wherein the first heater or the second heater comprises a conductor-in-conduit heater.

6275. The system of claim 6266, wherein the first heater or the second heater comprises an elongated member heater.

6276. The system of claim 6266, wherein the first heater or the second heater comprises a natural distributed combustor heater.

6277. The system of claim 6266, wherein the first heater or the second heater comprises a flameless distributed combustor heater.

6278. The system of claim 6266, wherein the first heater comprises a first oxidizer and the second heater comprises a second oxidizer.

6279. The system of claim 6278, wherein the second elongated portion has a length of less than about 175 meters.

6280. The system of claim 6278, wherein the third elongated portion has a length of less than about 175 meters.

6281. The system of claim 6278, further comprising a fuel conduit configurable to be placed in the opening, wherein the fuel conduit is further configurable to provide fuel to the first oxidizer during use.

6282. The system of claim 6278, further comprising a fuel conduit configurable to be placed in the opening, wherein the fuel conduit is further configurable to provide fuel to the second oxidizer during use.

6283. The system of claim 6278, further comprising a fuel source, wherein the fuel source is configurable to provide fuel to the first oxidizer or the second oxidizer during use.

6284. The system of claim 6278, further comprising a third oxidizer placed within the first elongated portion of the opening.

6285. The system of claim 6284, further comprising a fuel conduit configurable to be placed in the opening, wherein the fuel conduit is further configurable to provide fuel to the third oxidizer during use.

6286. The system of claim 6284, further comprising a first fuel source configurable to provide a first fuel to the first fuel conduit, a second fuel source configurable to provide a second fuel to a second fuel conduit, and a third fuel source configurable to provide a third fuel to a third fuel conduit.

6287. The system of claim 6286, wherein the first fuel has a composition substantially different from the second fuel or the third fuel.

6288. The system of claim 6266, further comprising insulation configurable to be placed proximate the first heater.

6289. The system of claim 6266, further comprising insulation configurable to be placed proximate the second heater.

6290. The system of claim 6266, wherein a fuel is oxidized in the first heater or the second heater to generate heat and wherein products from oxidation are removed from the formation through the opening during use.

6291. The system of claim 6266, wherein a fuel is oxidized in the first heater and the second heater and wherein products from oxidation are removed from the formation through the opening during use.

6292. The system of claim 6266, further comprising an exhaust conduit configurable to be coupled to the opening to allow exhaust fluid to flow from the formation through the exhaust conduit during use.

6293. The system of claim 6278, wherein the system is configured to allow the heat from oxidation of fuel to transfer to the formation during use.

6294. The system of claim 6266, wherein the system is configured to allow heat to transfer to a pyrolysis zone in the formation during use.

6295. The system of claim 6266, wherein the system is configured to allow heat to transfer to a pyrolysis zone in the formation during use, and wherein the transferred heat causes pyrolysis of at least some hydrocarbons within the pyrolysis zone during use.

6296. The system of claim 6266, wherein a combination of the heat generated from the first heater and the heat generated from the second heater substantially uniformly heats a portion of the formation during use.

6297. The system of claim 6266, further comprising a third heater placed in the second elongated portion.

6298. The system of claim 6297, wherein the third heater comprises a downhole combustor.

6299. The system of claim 6297, further comprising a fourth heater placed in the third elongated portion.

6300. The system of claim 6299, wherein the fourth heater comprises a downhole combustor.

6301. The system of claim 6266, wherein the first heater is configured to be placed in the second elongated portion, wherein the first heater is configured to provide heat to at least a portion of the formation during use, wherein the second heater is configured to be placed in the third elongated portion, wherein the second heater is configured to provide heat to at least a portion of the formation during use, and wherein the system is configured to allow heat to transfer to the formation during use.

6302. The system of claim 6266, wherein the second and the third elongated portions are located in a substantially similar plane.

6303. The system of claim 6302, wherein the opening comprises a fourth elongated portion and a fifth elongated portion, wherein the fourth elongated portion diverges from the first elongated portion in a third direction, wherein the fifth elongated portion diverges from the first elongated portion in a fourth direction, and wherein the third direction is substantially different than the fourth direction.

6304. The system of claim 6303, wherein the fourth and fifth elongated portions are located in a plane substantially different than the second and the third elongated portions.

6305. The system of claim 6303, wherein a third heater is configurable to be placed in the fourth elongated portion, and wherein a fourth heater is configurable to be placed in the fifth elongated portion.

6306. An in situ method for heating a hydrocarbon containing formation, comprising:

providing heat from two or more heaters placed in an opening in the formation, wherein the opening comprises a first elongated portion, a second elongated portion, and a third elongated portion, wherein the second elongated portion diverges from the first elongated portion in a first direction, wherein the third elongated portion diverges from the first elongated portion in a second direction, and wherein the first direction is substantially different than the second direction;

allowing heat from the two or more heaters to transfer to a portion of the formation; and

wherein the two or more heaters comprise a first heater placed in the second elongated portion and a second heater placed in the third elongated portion.

6307. The method of claim 6306, wherein the second and the third elongated portions are oriented substantially horizontally within the formation.

6308. The method of claim 6306, wherein the first elongated portion is located substantially within an overburden of the formation.

6309. The method of claim 6306, further comprising substantially uniformly heating a portion of the formation.

6310. The method of claim 6306, wherein the first heater or the second heater comprises a downhole combustor.

6311. The method of claim 6306, wherein the first heater or the second heater comprises an insulated conductor heater.

6312. The method of claim 6306, wherein the first heater or the second heater comprises a conductor-in-conduit heater.

6313. The method of claim 6306, wherein the first heater or the second heater comprises an elongated member heater.

6314. The method of claim 6306, wherein the first heater or the second heater comprises a natural distributed combustor heater.

6315. The method of claim 6306, wherein the first beater or the second heater comprises a flameless distributed combustor heater.

6316. The method of claim 6306, wherein the first heater comprises a first oxidizer and the second heater comprises a second oxidizer.

6317. The method of claim 6306, wherein the first heater comprises a first oxidizer and the second heater comprises a second oxidizer and further comprising providing fuel to the first oxidizer through a fuel conduit placed in the opening.

6318. The method of claim 6306, wherein the first heater comprises a first oxidizer and the second heater comprises a second oxidizer and further comprising providing fuel to the second oxidizer through a fuel conduit placed in the opening.

6319. The method of claim 6306, wherein the two or more heaters comprise oxidizers and further comprising providing fuel to the oxidizers from a fuel source.

6320. The method of claim 6316, further comprising providing heat to a portion of the formation using a third oxidizer placed within the first elongated portion of the opening.

6321. The method of claim 6306, wherein the first heater comprises a first oxidizer and the second heater comprises a second oxidizer further comprising:

providing heat to a portion of the formation using a third oxidizer placed within the first elongated portion of the opening; and

providing fuel to the third oxidizer through a fuel conduit placed in the opening.

6322. The method of claim 6306, wherein the two or more heaters comprise oxidizers, and further comprising providing heat by oxidizing a fuel within the oxidizers and removing products of oxidation of fuel through the opening.

6323. The method of claim 6306, wherein the two or more heaters comprise oxidizers, and further comprising removing products from oxidation of fuel through an exhaust conduit coupled to the opening.

6324. The method of claim 6306, further comprising allowing the heat to transfer from the portion to a pyrolysis zone in the formation.

6325. The method of claim 6306, further comprising allowing the heat to transfer from the portion to a pyrolysis zone in the formation and pyrolyzing at least some hydrocarbons within the pyrolysis zone with the transferred heat.

6326. The method of claim 6306, further comprising allowing the heat to transfer to from the portion to a pyrolysis zone in the formation, pyrolyzing at least some hydrocarbons within the pyrolysis zone with the transferred heat, and producing a portion of the pyrolyzed hydrocarbons through a conduit placed in the first elongated portion.

6327. The method of claim 6306, further comprising providing heat to a portion of the formation using a third heater placed in the second elongated portion.

6328. The method of claim 6327, wherein the third heater comprises a downhole combustor.

6329. The method of claim 6327, further comprising providing heat to a portion of the formation using a fourth heater placed in the third elongated portion.

6330. The method of claim 6329, wherein the fourth heater comprises a downhole combustor.

6331. A system configurable to provide heat to a hydrocarbon containing formation, comprising:

an oxidizer configurable to be placed in an opening in the formation, wherein the oxidizer is configurable to oxidize fuel to generate heat during use;

a first conduit configurable to be placed in the opening of the formation, wherein the first conduit is configurable to provide oxidizing fluid to the oxidizer in the opening during use;

a heater configurable to be placed in the opening and configurable to provide additional heat; and

wherein the system is configurable to allow the generated heat and the additional heat to transfer to the formation during use.

6332. The system of claim 6331, wherein the heater comprises an insulated conductor.

6333. The system of claim 6331, wherein the heater comprises a conductor-in-conduit heater.

6334. The system of claim 6331, wherein the heater comprises an elongated member heater.

6335. The system of claim 6331, wherein the heater comprises a flameless distributed combustor.

6336. The system of claim 6331, wherein the oxidizer is configurable to be placed proximate an upper portion of the opening.

6337. The system of claim 6331, further comprising insulation configurable to be placed proximate the oxidizer.

6338. The system of claim 6331, wherein the heater is configurable to be coupled to the first conduit.

6339. The system of claim 6331, wherein products from the oxidation of the fuel are removed from the formation through the opening during use.

6340. The system of claim 6331, further comprising an exhaust conduit configurable to be coupled to the opening to allow exhaust fluid to flow from the formation through the exhaust conduit during use.

6341. The system of claim 6331, wherein the system is configured to allow the generated heat and the additional heat to transfer to the formation during use.

6342. The system of claim 6331, wherein the system is configured to allow the generated heat and the additional heat to transfer to a pyrolysis zone in the formation during use.

6343. The system of claim 6331, wherein the system is configured to allow the generated heat and the additional heat to transfer to a pyrolysis zone in the formation during use, and wherein the transferred heat pyrolyzes of at least some hydrocarbons within the pyrolysis zone during use.

6344. The system of claim 6331, wherein a combination of the generate heat and the additional heat substantially uniformly heats a portion of the formation during use.

6345. The system of claim 6331, wherein the oxidizer is configured to be placed in the opening in the formation and wherein the oxidizer is configured to oxidize at least some fuel during use.

6346. The system of claim 6331, wherein the first conduit is configured to be placed in the opening of the formation and wherein the first conduit is configured to provide oxidizing fluid to the oxidizer in the opening during use.

6347. The system of claim 6331, wherein the heater is configured to be placed in the opening and wherein the heater is configurable to provide heat to a portion of the formation during use.

6348. The system of claim 6331, wherein the system is configured to allow the heat from the oxidation of at least some fuel and from the heater to transfer to the formation during use.

6349. An in situ method for heating a hydrocarbon containing formation, comprising:

allowing heat to transfer from a heater placed in an opening to a portion of the formation.

providing oxidizing fluid to an oxidizer placed in the opening in the formation;

providing fuel to the oxidizer;

oxidizing at least some fuel in the oxidizer; and

allowing additional heat from oxidation of at least some fuel to transfer to the portion of the formation.

6350. The method of claim 6349, wherein the heater comprises an insulated conductor.

6351. The method of claim 6349, wherein the heater comprises a conductor-in-conduit heater.

6352. The method of claim 6349, wherein the heater comprises an elongated member heater.

6353. The method of claim 6349, wherein the heater comprises a flameless distributed combustor.

6354. The method of claim 6349, wherein the oxidizer is placed proximate an upper portion of the opening.

6355. The method of claim 6349, further comprising allowing the additional heat to transfer from the portion to a pyrolysis zone in the formation.

6356. The method of claim 6349, further comprising allowing the additional heat to transfer from the portion to a pyrolysis zone in the formation and pyrolyzing at least some hydrocarbons within the pyrolysis zone.

6357. The method of claim 6349, further comprising substantially uniformly heating the portion of the formation.

6358. The method of claim 6349, further comprising removing exhaust fluids through the opening.

6359. The method of claim 6349, further comprising removing exhaust fluids through an exhaust annulus in the formation.

6360. The method of claim 6349, further comprising removing exhaust fluids through an exhaust conduit coupled to the opening.

6361. A system configurable to provide heat to a hydrocarbon containing formation, comprising:

a heater configurable to be placed in an opening in the formation, wherein the heater is configurable to heat a portion of the formation to a temperature sufficient to sustain oxidation of hydrocarbons during use;

an oxidizing fluid source configurable to provide an oxidizing fluid to a reaction zone of the formation to oxidize at least some hydrocarbons in the reaction zone during use such that heat is generated in the reaction zone, and wherein at least some of the reaction zone has been previously heated by the heater;

a first conduit configurable to be placed in the opening, wherein the first conduit is configurable to provide the oxidizing fluid from the oxidizing fluid source to the reaction zone in the formation during use, wherein the flow of oxidizing fluid can be controlled along at least a segment of the first conduit; and

wherein the system is configurable to allow the generated heat to transfer from the reaction zone to the formation during use.

6362. The system of claim 6361, wherein the system is configurable to provide hydrogen to the reaction zone during use.

6363. The system of claim 6361, wherein the oxidizing fluid is transported through the reaction zone substantially by diffusion.

6364. The system of claim 6361, wherein the system is configurable to allow the generated heat to transfer from the reaction zone to a pyrolysis zone in the formation during use.

6365. The system of claim 6361, wherein the system is configurable to allow the generated heat to transfer substantially by conduction from the reaction zone to the formation during use.

6366. The system of claim 6361, wherein a temperature within the reaction zone can be controlled along at least a segment of the first conduit during use.

6367. The system of claim 6361, wherein a heating rate in at least a section of the formation proximate at least a segment of the first conduit be controlled.

6368. The system of claim 6361, wherein the oxidizing fluid is configurable to be transported through the reaction zone substantially by diffusion, and wherein a rate of diffusion of the oxidizing fluid can controlled by a temperature within the reaction zone.

6369. The system of claim 6361, wherein the first conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening during use.

6370. The system of claim 6361, wherein the first conduit comprises critical flow orifices, and wherein the critical flow orifices are positioned on the first conduit such that a flow rate of the oxidizing fluid is controlled at a selected rate during use.

6371. The system of claim 6361, further comprising a second conduit configurable to remove an oxidation product during use.

6372. The system of claim 6371, wherein the second conduit is further configurable to allow heat within the oxidation product to transfer to the oxidizing fluid in the first conduit during use.

6373. The system of claim 6371, wherein a pressure of the oxidizing fluid in the first conduit and a pressure of the oxidation product in the second conduit are controlled during use such that a concentration of the oxidizing fluid along the length of the first conduit is substantially uniform.

6374. The system of claim 6371, wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone during use.

6375. The system of claim 6361, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone during use.

6376. The system of claim 6361, wherein the portion of the formation extends radially from the opening a distance of less than approximately 3 m.

6377. The system of claim 6361, wherein the reaction zone extends radially from the opening a distance of less than approximately 3 m.

6378. The system of claim 6361, wherein the system is configurable to pyrolyze at least some hydrocarbons in a pyrolysis zone of the formation.

6379. The system of claim 6361, wherein the heater is configured to be placed in an opening in the formation and wherein the heater is configured to provide the heat to at least the portion of the formation during use.

6380. The system of claim 6361, wherein a first conduit is configured to be placed in the opening and wherein the first conduit is configured to provide the oxidizing fluid from the oxidizing fluid source to the reaction zone in the formation during use.

6381. The system of claim 6361, wherein the flow of oxidizing fluid is controlled along at least a segment of the length of the first conduit and wherein the system is configured to allow the additional heat to transfer from the reaction zone to the formation during use.

6382. An in situ method for providing heat to a hydrocarbon containing formation, comprising:

heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons with an oxidizing fluid within the portion of the formation;

providing the oxidizing fluid to a reaction zone in the formation;

controlling a flow of the oxidizing fluid along at least a length of the reaction zone;

generating heat within the reaction zone; and

allowing the generated heat to transfer to the formation.

6383. The method of claim 6382, further comprising allowing the oxidizing fluid to react with at least some of the hydrocarbons in the reaction zone to generate the heat in the reaction zone.

6384. The method of claim 6382, wherein at least a section of the reaction zone is proximate an opening in the formation.

6385. The method of claim 6382, further comprising transporting the oxidizing fluid through the reaction zone substantially by diffusion.

6386. The method of claim 6382, further comprising transporting the oxidizing fluid through the reaction zone substantially by diffusion, and controlling a rate of diffusions of the oxidizing fluid by controlling a temperature within the reaction zone.

6387. The method of claim 6382, wherein the generated heat transfers from the reaction zone to a pyrolysis zone in the formation.

6388. The method of claim 6382, wherein the generated heat transfers from the reaction zone to the formation substantially by conduction.

6389. The method of claim 6382, further comprising controlling a temperature along at least a length of the reaction zone.

6390. The method of claim 6382, further comprising controlling a flow of the oxidizing fluid along at least a length of the reaction zone, and controlling a temperature along at least a length of the reaction zone.

6391. The method of claim 6382, further comprising controlling a heating rate along at least a length of the reaction zone.

6392. The method of claim 6382, wherein the oxidizing fluid is provided through a conduit placed within an opening in the formation, wherein the conduit comprises orifices.

6393. The method of claim 6382, further comprising controlling a rate of oxidation by providing the oxidizing fluid to the reaction zone from a conduit having critical flow orifices.

6394. The method of claim 6382, wherein the oxidizing fluid is provided to the reaction zone through a conduit placed within the formation, and further comprising positioning critical flow orifices on the conduit such that the flow rate of the oxidizing fluid to at least a length of the reaction zone is controlled at a selected flow rate.

6395. The method of claim 6382, wherein the oxidizing fluid is provided to the reaction zone from a conduit placed within an opening in the formation, and further comprising sizing critical flow orifices on the conduit such that the flow rate of the oxidizing fluid to at least a length of the reaction zone is controlled at a selected flow rate.

6396. The method of claim 6382, further comprising increasing a volume of the reaction zone, and increasing the flow of the oxidizing fluid to the reaction zone such that a rate of oxidation within the reaction zone is substantially constant over time.

6397. The method of claim 6382, further comprising maintaining a substantially constant rate of oxidation within the reaction zone over time.

6398. The method of claim 6382, wherein a conduit is placed in an opening in the formation, and further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.

6399. The method of claim 6382, further comprising removing an oxidation product from the formation through a conduit placed in an opening in the formation.

6400. The method of claim 6382, further comprising removing an oxidation product from the formation through a conduit placed in an opening in the formation and substantially inhibiting the oxidation product from flowing into a surrounding portion of the formation.

6401. The method of claim 6382, further comprising inhibiting the oxidizing fluid from flowing into a surrounding portion of the formation.

6402. The method of claim 6382, further comprising removing at least some water from the formation prior to heating the portion.

6403. The method of claim 6382, further comprising providing additional heat to the formation from an electric heater placed in the opening.

6404. The method of claim 6382, further comprising providing additional heat to the formation from an electric heater placed in an opening in the formation such that the oxidizing fluid continuously oxidizes at least a portion of the hydrocarbons in the reaction zone.

6405. The method of claim 6382, further comprising providing additional heat to the formation from an electric heater placed in the opening to maintain a constant heat rate in the formation.

6406. The method of claim 6405, further comprising providing electricity to the electric heater using a wind powered device.

6407. The method of claim 6405, further comprising providing electricity to the electric heater using a solar powered device.

6408. The method of claim 6382, further comprising maintaining a temperature within the portion above about the temperature sufficient to support the reaction of hydrocarbons with the oxidizing fluid.

6409. The method of claim 6382, further comprising providing additional heat to the formation from an electric heater placed in the opening and controlling the additional heat such that a temperature of the portion is greater than about the temperature sufficient to support the reaction of hydrocarbons with the oxidizing fluid.

6410. The method of claim 6382, further comprising removing oxidation products from the formation, and generating electricity using oxidation products removed from the formation.

6411. The method of claim 6382, further comprising removing oxidation products from the formation, and using at least some of the removed oxidation products in an air compressor.

6412. The method of claim 6382, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone over time.

6413. The method of claim 6382, further comprising assessing a temperature in or proximate an opening in the formation, wherein the flow of oxidizing fluid along at least a section of the reaction zone is controlled as a function of the assessed temperature.

6414. The method of claim 6382, further comprising assessing a temperature in or proximate an opening in the formation, and increasing the flow of oxidizing fluid as the assessed temperature decreases.

6415. The method of claim 6382, further comprising controlling the flow of oxidizing fluid to maintain a temperature in or proximate an opening in the formation at a temperature less than a pre-selected temperature.

6416. A system configurable to provide heat to a hydrocarbon containing formation, comprising:

a heater configurable to be placed in an opening in the formation, wherein the heater is configurable to provide heat to at least a portion of the formation during use;

an oxidizing fluid source configurable to provide an oxidizing fluid to a reaction zone of the formation to generate heat in the reaction zone during use, wherein at least a portion of the reaction zone has been previously heated by the heater during use;

a conduit configurable to be placed in the opening, wherein the conduit is configurable to provide the oxidizing fluid from the oxidizing fluid source to the reaction zone in the formation during use;

wherein the system is configurable to provide molecular hydrogen to the reaction zone during use; and

wherein the system is configurable to allow the generated heat to transfer from the reaction zone to the formation during use.

6417. The system of claim 6416, wherein the system is configurable to allow the oxidizing fluid to be transported through the reaction zone substantially by diffusion during use.

6418. The system of claim 6416, wherein the system is configurable to allow the generated heat to transfer from the reaction zone to a pyrolysis zone in the formation during use.

6419. The system of claim 6416, wherein the system is configurable to allow the generated heat to transfer substantially by conduction from the reaction zone to the formation during use.

6420. The system of claim 6416, wherein the flow of oxidizing fluid can be controlled along at least a segment of the conduit such that a temperature can be controlled along at least a segment of the conduit during use.

6421. The system of claim 6416, wherein a flow of oxidizing fluid can be controlled along at least a segment of the conduit such that a heating rate in at least a section of the formation can be controlled.

6422. The system of claim 6416, wherein the oxidizing fluid is configurable to move through the reaction zone substantially by diffusion during use, wherein a rate of diffusion can controlled by a temperature of the reaction zone.

6423. The system of claim 6416, wherein the conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening during use.

6424. The system of claim 6416, wherein the conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled during use.

6425. The system of claim 6416, wherein the conduit comprises a first conduit and a second conduit, wherein the second conduit is configurable to remove an oxidation product during use.

6426. The system of claim 6416, wherein the oxidizing fluid is substantially inhibited from flowing from the reaction zone into a surrounding portion of the formation.

6427. The system of claim 6416, wherein at least the portion of the formation extends radially from the opening a distance of less than approximately 3 m.

6428. The system of claim 6416, wherein the reaction zone extends radially from the opening a distance of less than approximately 3 m.

6429. The system of claim 6416, wherein the system is configurable to allow transferred heat to pyrolyze at least some hydrocarbons in a pyrolysis zone of the formation.

6430. The system of claim 6416, wherein the heater is configured to be placed in an opening in the formation and wherein the heater is configured to provide heat to at least a portion of the formation during use.

6431. The system of claim 6416, wherein the conduit is configured to be placed in the opening to provide at least some of the oxidizing fluid from the oxidizing fluid source to the reaction zone in the formation during use, and wherein the flow of at least some of the oxidizing fluid can be controlled along at least a segment of the first conduit.

6432. The system of claim 6416, wherein the system is configured to allow heat to transfer from the reaction zone to the formation during use.

6433. The system of claim 6416, wherein the heater is configured to be placed in an opening in the formation and wherein the heater is configured to provide heat to at least a portion of the formation during use.

6434. The system of claim 6416, wherein the conduit is configured to be placed in the opening and wherein the conduit is configured to provide the oxidizing fluid from the oxidizing fluid source to the reaction zone in the formation during use.

6435. The system of claim 6416, wherein the flow of oxidizing fluid can be controlled along at least a segment of the conduit.

6436. The system of claim 6416, wherein the system is configured to allow heat to transfer from the reaction zone to the formation during use.

6437. The system of claim 6416, wherein at least some of the provided hydrogen is produced in the pyrolysis zone during use.

6438. The system of claim 6416, wherein at least some of the provided hydrogen is produced in the reaction zone during use.

6439. The system of claim 6416, wherein at least some of the provided hydrogen is produced in at least the heated portion of the formation during use.

6440. The system of claim 6416, wherein the system is configurable to provide hydrogen to the reaction zone during use such that production of carbon dioxide in the reaction zone is inhibited.

6441. An in situ method for heating a hydrocarbon containing formation, comprising:

heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidizing fluid;

providing the oxidizing fluid to a reaction zone in the formation;

allowing the oxidizing fluid to react with at least a portion of the hydrocarbons in the reaction zone to generate heat in the reaction zone;

providing molecular hydrogen to the reaction zone; and

transferring the generated heat from the reaction zone to a pyrolysis zone in the formation.

6442. The method of claim 6441, farther comprising producing the molecular hydrogen in the pyrolysis zone.

6443. The method of claim 6441, further comprising producing the molecular hydrogen in the reaction zone.

6444. The method of claim 6441, further comprising producing the molecular hydrogen in at least the heated portion of the formation.

6445. The method of claim 6441, further comprising inhibiting production of carbon dioxide in the reaction zone.

6446. The method of claim 6441, further comprising allowing the oxidizing fluid to transfer through the reaction zone substantially by diffusion.

6447. The method of claim 6441, further comprising allowing the oxidizing fluid to transfer through the reaction zone by diffusion, wherein a rate of diffusion is controlled by a temperature of the reaction zone.

6448. The method of claim 6441, wherein at least some of the generated heat transfers to the pyrolysis zone substantially by conduction.

6449. The method of claim 6441, further comprising controlling a flow of the oxidizing fluid along at least a segment reaction zone such that a temperature is controlled along at least a segment of the reaction zone.

6450. The method of claim 6441, further comprising controlling a flow of the oxidizing fluid along at least a segment of the reaction zone such that a heating rate is controlled along at least a segment of the reaction zone.

6451. The method of claim 6441, further comprising allowing at least some oxidizing fluid to flow into the formation through orifices in a conduit placed in an opening in the formation.

6452. The method of claim 6441, further comprising controlling a flow of the oxidizing fluid into the formation using critical flow orifices on a conduit placed in the opening such that a rate of oxidation is controlled.

6453. The method of claim 6441, further comprising controlling a flow of the oxidizing fluid into the formation with a spacing of critical flow orifices on a conduit placed in an opening in the formation.

6454. The method of claim 6441, further comprising controlling a flow of the oxidizing fluid with a diameter of critical flow orifices in a conduit placed in an opening in the formation.

6455. The method of claim 6441, further comprising increasing a volume of the reaction zone, and increasing the flow of the oxidizing fluid to the reaction zone such that a rate of oxidation within the reaction zone is substantially constant over time.

6456. The method of claim 6441, wherein a conduit is placed in an opening in the formation, and further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.

6457. The method of claim 6441, further comprising removing an oxidation product from the formation through a conduit placed in an opening in the formation.

6458. The method of claim 6441, further comprising removing an oxidation product from the formation through a conduit placed in an opening in the formation and inhibiting the oxidation product from flowing into a surrounding portion of the formation beyond the reaction zone.

6459. The method of claim 6441, further comprising inhibiting the oxidizing fluid from flowing into a surrounding portion of the formation beyond the reaction zone.

6460. The method of claim 6441, further comprising removing at least some water from the formation prior to heating the portion.

6461. The method of claim 6441, further comprising providing additional heat to the formation from an electric heater placed in the opening.

6462. The method of claim 6441, further comprising providing additional heat to the formation from an electric heater placed in the opening and continuously oxidizing at least a portion of the hydrocarbons in the reaction zone.

6463. The method of claim 6441, further comprising providing additional heat to the formation from an electric heater placed in an opening in the formation and maintaining a constant heat rate within the pyrolysis zone.

6464. The method of claim 6441, further comprising providing additional heat to the formation from an electric heater placed in the opening such that the oxidation of at least a portion of the hydrocarbons does not burn out.

6465. The method of claim 6441, further comprising removing oxidation products from the formation and generating electricity using at least some oxidation products removed from the formation.

6466. The method of claim 6441, further comprising removing oxidation products from the formation and using at least some oxidation products removed from the formation in an air compressor.

6467. The method of claim 6441, further comprising increasing a flow of the oxidizing fluid in the reaction zone to accommodate an increase in a volume of the reaction zone over time.

6468. The method of claim 6441, further comprising increasing a volume of the reaction zone such that an amount of heat provided to the formation increases.

6469. The method of claim 6441, further comprising assessing a temperature in or proximate the opening, and controlling the flow of oxidizing fluid as a function of the assessed temperature.

6470. The method of claim 6441, further comprising assessing a temperature in or proximate the opening, and increasing the flow of oxidizing fluid as the assessed temperature decreases.

6471. The method of claim 6441, further comprising controlling the flow of oxidizing fluid to maintain a temperature in or proximate the opening at a temperature less than a pre-selected temperature.

6472. A system configurable to heat a hydrocarbon containing formation, comprising:

a heater configurable to be placed in an opening in the formation, wherein the heater is configurable to provide heat to at least a portion of the formation during use;

an oxidizing fluid source, wherein an oxidizing fluid is selected to oxidize at least some hydrocarbons at a reaction zone during use such that heat is generated in the reaction zone;

a first conduit configurable to be placed in the opening, wherein the first conduit is configurable to provide the oxidizing fluid from the oxidizing fluid source to the reaction zone in the formation during use; and

;

a second conduit configurable to be placed in the opening, wherein the second conduit is configurable to remove a product of oxidation from the opening during use; and

wherein the system is configurable to allow the generated heat to transfer from the reaction zone to the formation during use.

6473. The system of claim 6472, wherein the second conduit is configurable to control the concentration of oxygen in the opening during use such that the concentration of oxygen in the opening is substantially constant in the opening.

6474. The system of claim 6472, wherein the second conduit comprises orifices, and wherein the second conduit comprises a greater concentration of orifices towards an upper end of the second conduit.

6475. The system of claim 6472, wherein the first conduit comprises orifices that direct oxidizing fluid in a direction substantially opposite the second conduit.

6476. The system of claim 6472, wherein the second conduit comprises orifices that remove the oxidation product from a direction substantially opposite the first conduit.

6477. The system of claim 6472, wherein the second conduit is configurable to remove a product of oxidation from the opening during use such that the reaction zone comprises a substantially uniform temperature profile.

6478. The system of claim 6472, wherein a flow of the oxidizing fluid can be varied along a portion of a length of the first conduit.

6479. The system of claim 6472, wherein the oxidizing fluid is configurable to generate heat in the reaction zone such that the oxidizing fluid is transported through the reaction zone substantially by diffusion.

6480. The system of claim 6472, wherein the system is configurable to allow heat to transfer from the reaction zone to a pyrolysis zone in the formation during use.

6481. The system of claim 6472, wherein the system is configurable to allow heat to transfer substantially by conduction from the reaction zone to the formation during use.

6482. The system of claim 6472, wherein a flow of oxidizing fluid can be controlled along at least a portion of a length of the first conduit such that a temperature can be controlled along at least a portion of the length of the first conduit during use.

6483. The system of claim 6472, wherein a flow of oxidizing fluid can be controlled along at least a portion of the length of the first conduit such that a heating rate in at least a portion of the formation can be controlled.

6484. The system of claim 6472, wherein the oxidizing fluid is configurable to generate heat in the reaction zone during use such that the oxidizing fluid is transported through the reaction zone during use substantially by diffusion, wherein a rate of diffusion can controlled by a temperature of the reaction zone.

6485. The system of claim 6472, wherein the first conduit comprises orifices, and wherein the orifices are configurable to provide the oxidizing fluid into the opening during use.

6486. The system of claim 6472, wherein the first conduit comprises critical flow orifices, and wherein the critical flow orifices are configurable to control a flow of the oxidizing fluid such that a rate of oxidation in the formation is controlled during use.

6487. The system of claim 6472, wherein the second conduit is further configurable to remove an oxidation product such that the oxidation product transfers heat to the oxidizing fluid in the first conduit during use.

6488. The system of claim 6472, wherein a pressure of the oxidizing fluid in the first conduit and a pressure of the oxidation product in the second conduit are controlled during use such that a concentration of the oxidizing fluid in along the length of the conduit is substantially uniform.

6489. The system of claim 6472, wherein the oxidation product is substantially inhibited from flowing into portions of the formation beyond the reaction zone during use.

6490. The system of claim 6472, wherein the oxidizing fluid is substantially inhibited from flowing into portions of the formation beyond the reaction zone during use.

6491. The system of claim 6472, wherein the portion of the formation extends radially from the opening a distance of less than approximately 3 m.

6492. The system of claim 6472, wherein the reaction zone extends radially from the opening a distance of less than approximately 3 m.

6493. The system of claim 6472, wherein the system is further configurable such that transferred heat can pyrolyze at least some hydrocarbons in the pyrolysis zone.

6494. The system of claim 6472, wherein the heater is configured to be placed in an opening in the formation and wherein the heater is configured to provide heat to at least a portion of the formation during use.

6495. The system of claim 6472, wherein the first conduit is configured to be placed in the opening, and wherein the first conduit is configured to provide the oxidizing fluid from the oxidizing fluid source to the reaction zone in the formation during use.

6496. The system of claim 6472, wherein the flow of oxidizing fluid can be controlled along at least a segment of the first conduit.

6497. The system of claim 6472, wherein the second conduit is configured to be placed in the opening, and wherein the second conduit is configured to remove a product of oxidation from the opening during use.

6498. The system of claim 6472, wherein the system is configured to allow heat to transfer from the reaction zone to the formation during use.

6499. An in situ method for heating a hydrocarbon containing formation, comprising:

heating a portion of the formation to a temperature sufficient to support reaction of hydrocarbons within the portion of the formation with an oxidizing fluid;

providing the oxidizing fluid to a reaction zone in the formation;

allowing the oxidizing fluid to react with at least a portion of the hydrocarbons in the reaction zone to generate heat in the reaction zone;

removing an oxidation product from the opening; and

transferring the generated heat from the reaction zone to the formation.

6500. The method of claim 6499, further comprising removing the oxidation product such that a concentration of oxygen in the opening is substantially constant in the opening.

6501. The method of claim 6499, further comprising removing the oxidation product from the opening and maintaining a substantially uniform temperature profile within the reaction zone.

6502. The method of claim 6499, further comprising transporting the oxidizing fluid through the reaction zone substantially by diffusion.

6503. The method of claim 6499, further comprising transporting the oxidizing fluid through the reaction zone by diffusion, wherein a rate of diffusion is controlled by a temperature of the reaction zone.

6504. The method of claim 6499, further comprising allowing heat to transfer from the reaction zone to a pyrolysis zone in the formation.

6505. The method of claim 6499, further comprising allowing heat to transfer from the reaction zone to the formation substantially by conduction.

6506. The method of claim 6499, further comprising controlling a flow of the oxidizing fluid along at least a portion of the length of the reaction zone such that a temperature is controlled along at least a portion of the length of the reaction zone.

6507. The method of claim 6499, further comprising controlling a flow of the oxidizing fluid along at least a portion of the length of the reaction zone such that a heating rate is controlled along at least a portion of the length of the reaction zone.

6508. The method of claim 6499, further comprising allowing at least a portion of the oxidizing fluid into the opening through orifices of a conduit placed in the opening.

6509. The method of claim 6499, further comprising controlling a flow of the oxidizing fluid with critical flow orifices in a conduit placed in the opening such that a rate of oxidation is controlled.

6510. The method of claim 6499, further comprising controlling a flow of the oxidizing fluid with a spacing of critical flow orifices in a conduit placed in the opening.

6511. The method of claim 6499, further comprising controlling a flow of the oxidizing fluid with a diameter of critical flow orifices in a conduit placed in the opening.

6512. The method of claim 6499, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone such that a rate of oxidation is substantially constant over time within the reaction zone.

6513. The method of claim 6499, wherein a conduit is placed in the opening, and further comprising cooling the conduit with the oxidizing fluid to reduce heating of the conduit by oxidation.

6514. The method of claim 6499, further comprising removing an oxidation product from the formation through a conduit placed in the opening.

6515. The method of claim 6499, further comprising removing an oxidation product from the formation through a conduit placed in the opening and substantially inhibiting the oxidation product from flowing into portions of the formation beyond the reaction zone.

6516. The method of claim 6499, further comprising substantially inhibiting the oxidizing fluid from flowing into portions of the formation beyond the reaction zone.

6517. The method of claim 6499, further comprising removing water from the formation prior to heating the portion.

6518. The method of claim 6499, further comprising providing additional heat to the formation from an electric heater placed in the opening.

6519. The method of claim 6499, further comprising providing additional heat to the formation from an electric heater placed in the opening such that the oxidizing fluid continuously oxidizes at least a portion of the hydrocarbons in the reaction zone.

6520. The method of claim 6499, further comprising providing additional heat to the formation from an electric heater placed in the opening such that a constant heat rate in the formation is maintained.

6521. The method of claim 6499, further comprising providing additional heat to the formation from an electric heater placed in the opening such that the oxidation of at least a portion of the hydrocarbons does not burn out.

6522. The method of claim 6499, further comprising generating electricity using oxidation products removed from the formation.

6523. The method of claim 6499, further comprising using oxidation products removed from the formation in an air compressor.

6524. The method of claim 6499, further comprising increasing a flow of the oxidizing fluid in the opening to accommodate an increase in a volume of the reaction zone over time.

6525. The method of claim 6499, further comprising increasing the amount of heat provided to the formation by increasing the reaction zone.

6526. The method of claim 6499, further comprising assessing a temperature in or proximate the opening, and controlling the flow of oxidizing fluid as a function of the assessed temperature.

6527. The method of claim 6499, further comprising assessing a temperature in or proximate the opening, and increasing the flow of oxidizing fluid as the assessed temperature decreases.

6528. The method of claim 6499, further comprising controlling the flow of oxidizing fluid to maintain a temperature in or proximate the opening at a temperature less than a pre-selected temperature.

6529. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

controlling the heat from the one or more heaters such that an average temperature within at least a selected section of the formation is less than about 375°

C.;

producing a mixture from the formation from a production well; and

controlling heating in or proximate the production well to produce a selected yield of non-condensable hydrocarbons in the produced mixture.

6530. The method of claim 6529, further comprising controlling heating in or proximate the production well to produce a selected yield of condensable hydrocarbons in the produced mixture.

6531. The method of claim 6529, wherein the mixture comprises more than about 50 weight percent non-condensable hydrocarbons.

6532. The method of claim 6529, wherein the mixture comprises more than about 50 weight percent condensable hydrocarbons.

6533. The method of claim 6529, wherein the average temperature and a pressure within the formation are controlled such that production of carbon dioxide is substantially inhibited.

6534. The method of claim 6529, heating in or proximate the production well is controlled such that production of carbon dioxide is substantially inhibited.

6535. The method of claim 6529, wherein at least a portion of the mixture produced from a first portion of the formation at a lower temperature is recycled into a second portion of the formation at a higher temperature such that production of carbon dioxide is substantially inhibited.

6536. The method of claim 6529, wherein the mixture comprises a volume ratio of molecular hydrogen to carbon monoxide of about 2 to 1, and wherein producing the mixture is controlled such that the volume ratio is maintained between about 1.8 to 1 and about 2.2 to 1.

6537. The method of claim 6529, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6538. The method of claim 6529, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6539. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

controlling the heat from the one or more heaters such that an average temperature within at least a selected section of the formation is less than about 375°

C.; and

producing a mixture from the formation.

6540. The method of claim 6539, removing a fluid from the formation through a production well.

6541. The method of claim 6539, further comprising removing a liquid through a production well.

6542. The method of claim 6539, further comprising removing water through a production well.

6543. The method of claim 6539, further comprising removing a fluid through a production well prior to providing heat to the formation.

6544. The method of claim 6539, further comprising removing water from the formation through a production well prior to providing heat to the formation.

6545. The method of claim 6539, further comprising removing the fluid through a production well using a pump.

6546. The method of claim 6539, further comprising removing a fluid through a conduit.

6547. The method of claim 6539, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6548. The method of claim 6539, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6549. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

controlling the heat from the one or more heaters such that an average temperature within at least a selected section of the formation is less than about 375°

C.;

measuring a temperature within a wellbore placed in the formation; and

producing a mixture from the formation.

6550. The method of claim 6549, further comprising measuring the temperature using a moveable thermocouple.

6551. The method of claim 6549, further comprising measuring the temperature using an optical fiber assembly.

6552. The method of claim 6549, further comprising measuring the temperature within a production well.

6553. The method of claim 6549, further comprising measuring the temperature within a heater well.

6554. The method of claim 6549, further comprising measuring the temperature within a monitoring well.

6555. The method of claim 6549, further comprising providing a pressure wave from a pressure wave source into the wellbore, wherein the wellbore comprises a plurality of discontinuities along a length of the wellbore, measuring a reflection signal of the pressure wave, and using the reflection signal to assess at least one temperature between at least two discontinuities.

6556. The method of claim 6549, further comprising assessing an average temperature in the formation using one or more temperatures measured within at least one wellbore.

6557. The method of claim 6549, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6558. The method of claim 6549, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6559. An in situ method of measuring assessing a temperature within a wellbore in a hydrocarbon containing formation, comprising:

providing a pressure wave from a pressure wave source into the wellbore, wherein the wellbore comprises a plurality of discontinuities along a length of the wellbore;

measuring a reflection signal of the pressure wave; and

using the reflection signal to assess at least one temperature between at least two discontinuities.

6560. The method of claim 6559, wherein the plurality of discontinuities are placed along a length of a conduit placed in the wellbore.

6561. The method of claim 6560, wherein the pressure wave is propagated through a wall of the conduit.

6562. The method of claim 6560, wherein the plurality of discontinuities comprises collars placed within the conduit.

6563. The method of claim 6560, wherein the plurality of discontinuities comprises welds placed within the conduit.

6564. The method of claim 6559, wherein determining the at least one temperature between at least the two discontinuities comprises relating a velocity of the pressure wave between discontinuities to the at least one temperature.

6565. The method of claim 6559, further comprising measuring a reference signal of the pressure wave within the wellbore at an ambient temperature.

6566. The method of claim 6559, further comprising measuring a reference signal of the pressure wave within the wellbore at an ambient temperature, and then determining the at least one temperature between at least the two discontinuities by comparing the measured signal to the reference signal.

6567. The method of claim 6559, wherein the at least one temperature is a temperature of a gas between at least the two discontinuities.

6568. The method of claim 6559, wherein the wellbore comprises a production well.

6569. The method of claim 6559, wherein the wellbore comprises a heater well.

6570. The method of claim 6559, wherein the wellbore comprises a monitoring well.

6571. The method of claim 6559, wherein the pressure wave source comprises a solenoid valve.

6572. The method of claim 6559, wherein the pressure wave source comprises an explosive device.

6573. The method of claim 6559, wherein the pressure wave source comprises a sound device.

6574. The method of claim 6559, wherein the pressure wave is propagated through the wellbore.

6575. The method of claim 6559, wherein the plurality of discontinuities have a spacing between each discontinuity of about 5 m.

6576. The method of claim 6559, further comprising repeatedly providing the pressure wave into the wellbore at a selected frequency and continuously measuring the reflected signal to increase a signal-to-noise ratio of the reflected signal.

6577. The method of claim 6559, further comprising providing heat from one or more heaters to a portion of the formation.

6578. The method of claim 6559, further comprising pyrolyzing at least some hydrocarbons within a portion of the formation.

6579. The method of claim 6559, further comprising generating synthesis gas in at least a portion of the formation.

6580. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

controlling the heat from the one or more heaters such that an average temperature within at least a majority of the selected section of the formation is less than about 375°

C.; and

producing a mixture from the formation through a heater well.

6581. The method of claim 6580, wherein producing the mixture through the heater well increases a production rate of the mixture from the formation.

6582. The method of claim 6580, further comprising providing heat using at least 2 heaters.

6583. The method of claim 6580, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons with the selected section of the formation.

6584. The method of claim 6580, wherein the one or more heaters comprise a pattern of heaters in a formation, and wherein superposition of heat from the pattern of heaters pyrolyzes at least some hydrocarbons with the selected section of the formation.

6585. The method of claim 6580, wherein heating of a majority of selected section is controlled such that a temperature of the majority of the selected section is less than about 375°

C.

6586. The method of claim 6580, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6587. The method of claim 6580, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6588. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

wherein heating is provided from at least a first heater and at least a second heater, wherein the first heater has a first heating cost and the second heater has a second heating cost;

controlling a heating rate of at least a portion of the selected section to preferentially use the first heater when the first heating cost is less than the second heating cost; and

controlling the heat from the one or more heaters to pyrolyze at least some hydrocarbon in the selected section of the formation.

6589. The method of claim 6588, further comprising controlling the heating rate such that a temperature within at least a majority of the selected section of the formation is less than about 375°

C.

6590. The method of claim 6588, further comprising providing heat using at least 2 heaters.

6591. The method of claim 6588, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons with the selected section of the formation.

6592. The method of claim 6588, wherein the one or more heaters comprise a pattern of heaters in a formation, and wherein superposition of heat from the pattern of heaters pyrolyzes at least some hydrocarbons with the selected section of the formation.

6593. The method of claim 6588, further comprising controlling the heating to preferentially use the second heater when the second heating cost is less than the first heating cost.

6594. The method of claim 6588, further comprising producing a mixture from the formation.

6595. The method of claim 6588, wherein heating of a majority of selected section is controlled such that a temperature of the majority of the selected section is less than about 375°

C.

6596. The method of claim 6588, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6597. The method of claim 6588, further comprising producing a mixture from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6598. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

wherein heating is provided from at least a first heater and at least a second heater, wherein the first heater has a first heating cost and the second heater has a second heating cost;

controlling a heating rate of at least a portion of the selected section such that a cost associated with heating the selected section is minimized; and

controlling the heat from the one or more heaters to pyrolyze at least some hydrocarbon in at least a portion of the selected section of the formation.

6599. The method of claim 6598, wherein the heating rate is varied within a day depending on a cost associated with heating at various times in the day.

6600. The method of claim 6598, further comprising controlling the heating rate such that a temperature within at least a majority of the selected section of the formation is less than about 375°

C.

6601. The method of claim 6598, further comprising providing heat using at least 2 heaters.

6602. The method of claim 6598, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons with the selected section of the formation.

6603. The method of claim 6598, wherein the one or more heaters comprise a pattern of heaters in a formation, and wherein superposition of heat from the pattern of heaters pyrolyzes at least some hydrocarbons with the selected section of the formation.

6604. The method of claim 6598, further comprising producing a mixture from the formation.

6605. The method of claim 6598, wherein heating of a majority of selected section is controlled such that a temperature of the majority of the selected section is less than about 375°

C.

6606. The method of claim 6598, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6607. The method of claim 6598, further comprising producing a mixture from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6608. A method for controlling an in situ system of treating a hydrocarbon containing formation, comprising:

monitoring at least one acoustic event within the formation using at least one acoustic detector placed within a wellbore in the formation;

recording at least one acoustic event with an acoustic monitoring system;

analyzing at least one acoustic event to determine at least one property of the formation; and

controlling the in situ system based on the analysis of the at least one acoustic event.

6609. The method of claim 6608, wherein the at least one acoustic event comprises a seismic event.

6610. The method of claim 6608, wherein the method is continuously operated.

6611. The method of claim 6608, wherein the acoustic monitoring system comprises a seismic monitoring system.

6612. The method of claim 6608, further comprising recording the at least one acoustic event with the acoustic monitoring system.

6613. The method of claim 6608, further comprising monitoring more than one acoustic event simultaneously with the acoustic monitoring system.

6614. The method of claim 6608, further comprising monitoring the at least one acoustic event at a sampling rate of about at least once every 0.25 milliseconds.

6615. The method of claim 6608, wherein analyzing the at least one acoustic event comprises interpreting the at least one acoustic event.

6616. The method of claim 6608, wherein the at least one property of the formation comprises a location of at least one fracture in the formation.

6617. The method of claim 6608, wherein the at least one property of the formation comprises an extent of at least one fracture in the formation.

6618. The method of claim 6608, wherein the at least one property of the formation comprises an orientation of at least one fracture in the formation.

6619. The method of claim 6608, wherein the at least one property of the formation comprises a location and an extent of at least one fracture in the formation.

6620. The method of claim 6608, wherein controlling the in situ system comprises modifying a temperature of the in situ system.

6621. The method of claim 6608, wherein controlling the in situ system comprises modifying a pressure of the in situ system.

6622. The method of claim 6608, wherein the at least one acoustic detector comprises a geophone.

6623. The method of claim 6608, wherein the at least one acoustic detector comprises a hydrophone.

6624. The method of claim 6608, further comprising providing heat to at least a portion of the formation.

6625. The method of claim 6608, further comprising pyrolyzing hydrocarbons within at least a portion of the formation.

6626. The method of claim 6608, further comprising providing heat from one or more heaters to a portion of the formation.

6627. The method of claim 6608, further comprising pyrolyzing at least some hydrocarbons within a portion of the formation.

6628. The method of claim 6608, further comprising generating synthesis gas in at least a portion of the formation.

6629. A method of predicting characteristics of a formation fluid produced from an in situ process, wherein the in situ process is used for treating a hydrocarbon containing formation, comprising:

determining an isothermal experimental temperature that can be used when treating a sample of the formation, wherein the isothermal experimental temperature is correlated to a selected in situ heating rate for the formation; and

treating a sample of the formation at the determined isothermal experimental temperature, wherein the experiment is used to assess at least one product characteristic of the formation fluid produced from the formation for the selected heating rate.

6630. The method of claim 6629, further comprising determining the at least one product characteristic at a selected pressure.

6631. The method of claim 6629, further comprising modifying the selected heating rate so that at least one desired product characteristic of the formation fluid is obtained.

6632. The method of claim 6629, further comprising using a selected well spacing in the formation to determine the selected heating rate.

6633. The method of claim 6629, further comprising using a selected heat input into the formation to determine the selected heating rate.

6634. The method of claim 6629, further comprising using at least one property of the formation to determine the selected heating rate.

6635. The method of claim 6629, further comprising selecting a desired heating rate such that at least one desired product characteristic of the formation fluid is obtained.

6636. The method of claim 6629, further comprising determining the isothermal temperature using an equation that estimates a temperature in which a selected amount of hydrocarbons in the formation are converted.

6637. The method of claim 6629, wherein the selected heating rate is less than about 1°

C. per day.

6638. The method of claim 6629, wherein the sample is treated in an insulated vessel.

6639. The method of claim 6629, wherein at least one assessed produced characteristic is used to design at least one surface processing system, wherein the surface processing system is used to treat produced fluids on the surface.

6640. The method of claim 6629, wherein the formation is treated using a heating rate of about the selected heating rate.

6641. The method of claim 6629, further comprising using at least one product characteristic to assess a pressure to be maintained in the formation during treatment.

6642. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

adding hydrogen to the selected section after a temperature of the selected section is at least about 270°

C.; and

producing a mixture from the formation.

6643. The method of claim 6642, wherein the temperature of the selected section is at least about 290°

C.

6644. The method of claim 6642, wherein the temperature of the selected section is at least about 320°

C.

6645. The method of claim 6642, wherein the temperature of the selected section is less than about 375°

C.

6646. The method of claim 6642, wherein the temperature of the selected section is less than about 400°

C.

6647. The method of claim 6642, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6648. The method of claim 6642, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6649. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

controlling a temperature of a majority of the selected section by selectively adding hydrogen to the formation.

6650. The method of claim 6649, further comprising controlling the temperature such that the temperature is less than about 375°

C.

6651. The method of claim 6649, further comprising controlling the temperature such that the temperature is less than about 400°

C.

6652. The method of claim 6649, further comprising controlling a heating rate such that the temperature is less than about 375°

C.

6653. The method of claim 6649, wherein the one or more heaters comprise a pattern of heaters in a formation, and wherein superposition of heat form the heaters pyrolyzes at least some hydrocarbons with the selected section of the formation.

6654. The method of claim 6649, further comprising producing a mixture from the formation.

6655. The method of claim 6649, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6656. The method of claim 6649, further comprising producing a mixture from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6657. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least the portion to a selected section of the formation; and

producing fluids from the formation wherein at least a portion of the produced fluids have been heated by the heat provided by one or more of the heaters, and wherein at least a portion of the produced fluids are produced at a temperature greater than about 200°

C.

6658. The method of claim 6657, wherein at least a portion of the produced fluids are produced at a temperature greater than about 250°

C.

6659. The method of claim 6657, wherein at least a portion of the produced fluids are produced at a temperature greater than about 300°

C.

6660. The method of claim 6657, further comprising varying the heat provided to the one or more heaters to vary heat in at least a portion of the produced fluids.

6661. The method of claim 6657, wherein the produced fluids are produced from a well comprising at least one of the heaters, and further comprising varying the heat provided to the one or more heaters to vary heat in at least a portion of the produced fluids.

6662. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a hydrotreating unit.

6663. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a hydrotreating unit, and further comprising varying the heat provided to the one or more heaters to vary heat in at least a portion of the produced fluids provided to the hydrotreating unit.

6664. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a hydrotreating unit, and using heat in the produced fluids when hydrotreating at least a portion of the produced fluids.

6665. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a hydrotreating unit, and hydrotreating at least a portion of the produced fluids without using a surface heater to heat produced fluids.

6666. The method of claim 6657, further comprising:

providing at least a portion of the produced fluids to a hydrotreating unit; and

hydrotreating at least a portion of the produced fluids;

wherein at least 50% of heat used for hydrotreating is provided by heat in the produced fluids.

6667. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a hydrotreating unit, wherein at least a portion of the produced fluids are provided to the hydrotreating unit via an insulated conduit, and wherein the insulated conduit is insulated to inhibit heat loss from the produced fluids.

6668. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a hydrotreating unit, wherein at least a portion of the produced fluids are provided to the hydrotreating unit via a heated conduit.

6669. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a hydrotreating unit, wherein the produced fluids are produced at a wellhead, and wherein at least a portion of the produced fluids are provided to the hydrotreating unit at a temperature that is within about 50°

C. of the temperature of the produced fluids at the wellhead.

6670. The method of claim 6657, further comprising hydrotreating at least a portion of the produced fluids such that the volume of hydrotreated produced fluids is about 4% greater than a volume of the produced fluids.

6671. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a hydrotreating unit, wherein the produced fluids comprise molecular hydrogen, and using the molecular hydrogen in the produced fluids to hydrotreat at least a portion of the produced fluids.

6672. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a hydrotreating unit, wherein the produced fluids comprise molecular hydrogen, hydrotreating at least a portion of the produced fluids, and wherein at least 50% of molecular hydrogen used for hydrotreating is provided by the molecular hydrogen in the produced fluids.

6673. The method of claim 6657, wherein the produced fluids comprise molecular hydrogen, separating at least a portion of the molecular hydrogen from the produced fluids, and providing at least a portion of the separated molecular hydrogen to a surface treatment unit.

6674. The method of claim 6657, wherein the produced fluids comprise molecular hydrogen, separating at least a portion of the molecular hydrogen from the produced fluids, and providing at least a portion of the separated molecular hydrogen to an in situ treatment area.

6675. The method of claim 6657, further comprising providing a portion of the produced fluids to an olefin generating unit.

6676. The method of claim 6657, further comprising providing a portion of the produced fluids to a steam cracking unit.

6677. The method of claim 6657, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and further comprising varying heat provided to the one or more heaters to vary the heat in at least a portion of the produced fluids provided to the olefin generating unit.

6678. The method of claim 6657, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and using heat in the produced fluids when generating olefins from at least a portion of the produced fluids.

6679. The method of claim 6657, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and generating olefins from at least a portion of the produced fluids without using a surface heater to heat produced fluids.

6680. The method of claim 6657, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and generating olefins from at least a portion of the produced fluids, and wherein at least 50% of the heat used for generating olefins is provided by heat in the produced fluids.

6681. The method of claim 6657, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via an insulated conduit, and wherein the insulated conduit is insulated to inhibit heat loss from the produced fluids.

6682. The method of claim 6657, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via a heated conduit.

6683. The method of claim 6657, further comprising providing at least a portion of the produced fluids to an olefin generating unit, wherein the produced fluids are produced at a wellhead, and wherein at least a portion of the produced fluids are provided to the olefin generating unit at a temperature that is within about 50°

C. of the temperature of the produced fluids at the wellhead.

6684. The method of claim 6657, further comprising removing heat from the produced fluids in a heat exchanger.

6685. The method of claim 6657, further comprising separating the produced fluids into two or more streams comprising at least a synthetic condensate stream, and a non-condensable fluid stream.

6686. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a separating unit, and separating at least a portion of the produced fluids into two or more streams.

6687. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a separating unit, and separating at least a portion of the produced fluids into two or more streams, and further comprising separating at least one of such streams into two or more substreams.

6688. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a separating unit, and separating at least a portion of the produced fluids into three or more streams, and wherein such streams comprise at least a top stream, a bottom stream, and a middle stream.

6689. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a separating unit, and further comprising varying heat provided to the one or more heaters to vary the heat in at least a portion of the produced fluids provided to the separating unit.

6690. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a separating unit, and using heat in the produced fluids when separating at least a portion of the produced fluids.

6691. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a separating unit, and separating at least a portion of the produced fluids without using a surface heater to heat produced fluids.

6692. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a separating unit, and separating at least a portion of the produced fluids, and wherein at least 50% of the heat used for separating is provided by heat in the produced fluids.

6693. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a separating unit wherein at least a portion of the produced fluids are provided to the separating unit via an insulated conduit, and wherein the insulated conduit is insulated to inhibit heat loss from the produced fluids.

6694. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a separating unit wherein at least a portion of the produced fluids are provided to the separating unit via a heated conduit.

6695. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a separating unit, wherein the produced fluids are produced at a wellhead, and wherein at least a portion of the produced fluids are provided to the separating unit at a temperature that is within about 50°

C. of the temperature of the produced fluids at the wellhead.

6696. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a separating unit, and separating at least a portion of the produced fluids into four or more streams, and wherein such streams comprise at least a top stream, a bottoms stream, and at least two middle streams wherein one of the middle streams is heavier than the other middle stream.

6697. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a separating unit, and separating at least a portion of the produced fluids into five or more streams, and wherein such streams comprise at least a top stream, a bottoms stream, a naphtha stream, diesel stream, and a jet fuel stream.

6698. The method of claim 6657, further comprising providing at least a portion of the produced fluids to a distillation column, and using heat in the produced fluids when distilling at least a portion of the produced fluids.

6699. The method of claim 6657, wherein the produced fluids comprise pyrolyzation fluids.

6700. The method of claim 6657, wherein the produced fluids comprise carbon dioxide, and further comprising separating at least a portion of the carbon dioxide from the produced fluids.

6701. The method of claim 6657, wherein the produced fluids comprise carbon dioxide, and further comprising separating at least a portion of the carbon dioxide from the produced fluids, and utilizing at least some carbon dioxide in one or more treatment processes.

6702. The method of claim 6657, wherein the produced fluids comprise molecular hydrogen and wherein the molecular hydrogen is used when treating the produced fluids.

6703. The method of claim 6657, wherein the produced fluids comprise steam and wherein the steam is used when treating the produced fluids.

6704. The method of claim 6657, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6705. The method of claim 6657, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6706. A method of converting formation fluids into olefins, comprising:

converting formation fluids into olefins, wherein the formation fluids are obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from one or more heaters to a selected section of the formation such that at least some hydrocarbons in the formation are pyrolyzed; and

producing formation fluids from the formation.

6707. The method of claim 6706, wherein the produced fluids comprise steam.

6708. The method of claim 6706, wherein the produced fluids comprise steam and wherein the steam in the produced fluids comprises at least a portion of steam used in the olefin generating unit.

6709. The method of claim 6706, further comprising providing at least a portion of the produced fluids to an olefin generating unit.

6710. The method of claim 6706, further comprising providing at least a portion of the produced fluids to a steam cracking unit.

6711. The method of claim 6706, wherein olefins comprise ethylene.

6712. The method of claim 6706, wherein olefins comprise propylene.

6713. The method of claim 6706, further comprising separating liquids from the produced fluids, and then separating olefin generating compounds from the produced fluids, and then providing at least a portion of the olefin generating compounds to an olefin generating unit.

6714. The method of claim 6706, wherein the produced fluids comprise molecular hydrogen, and further comprising removing at least a portion of the molecular hydrogen from the produced fluids prior to using the produced fluids to produce olefins.

6715. The method of claim 6706, wherein the produced fluids comprise molecular hydrogen, and further comprising separating at least a portion of the molecular hydrogen from the produced fluids, and utilizing at least a portion of the separated molecular hydrogen in one or more treatment processes.

6716. The method of claim 6706, wherein the produced fluids comprise molecular hydrogen, and further comprising removing at least a portion of the molecular hydrogen from the produced fluids using a hydrogen removal unit prior to using the produced fluids to produce olefins.

6717. The method of claim 6706, wherein the produced fluids comprises molecular hydrogen, and further comprising removing at least a portion of the molecular hydrogen from the produced fluids using a membrane prior to using the produced fluids to produce olefins.

6718. The method of claim 6706, further comprising generating molecular hydrogen during production of olefins, and providing at least a portion of the generated molecular hydrogen to one or more hydrotreating units.

6719. The method of claim 6706, further comprising generating molecular hydrogen during production of olefins, and providing at least a portion of the generated molecular hydrogen to an in situ treatment area.

6720. The method of claim 6706, further comprising generating molecular hydrogen during production of olefins, and providing at least a portion of the generated molecular hydrogen to one or more fuel cells.

6721. The method of claim 6706, further comprising generating molecular hydrogen during production of olefins, and using at least a portion of the generated molecular hydrogen to hydrotreat pyrolysis liquids generated in the olefin generation plant.

6722. The method of claim 6706, wherein the produced fluids are at least 200°

C., and further comprising using heat in the produced fluids to produce olefins.

6723. The method of claim 6706, further comprising providing at least a portion of the produced fluids to a hydrotreating unit, wherein the produced fluids are produced at a wellhead, and wherein at least a portion of the produced fluids are provided to the olefins generating unit at a temperature that is within about 50°

C. of the temperature of the produced fluids at the wellhead.

6724. The method of claim 6706, wherein the produced fluids can be used to make olefins without substantial hydrotreating of the produced fluids.

6725. The method of claim 6706, further comprising separating liquids from the produced fluids, and then using at least a portion of the produced fluids to produce olefins.

6726. The method of claim 6706, further comprising controlling a fluid pressure within at least a portion of the formation to enhance production of olefin generating compounds in the produced fluids.

6727. The method of claim 6706, further comprising controlling a temperature within at least a portion of the formation to enhance production of olefin generating compounds in the produced fluids.

6728. The method of claim 6706, further comprising controlling a temperature profile within at least a portion of the formation to enhance production of olefin generating compounds in the produced fluids.

6729. The method of claim 6706, further comprising controlling a heating rate within at least a portion of the formation to enhance production of olefin generating compounds in the produced fluids.

6730. The method of claim 6706, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and further comprising varying heat provided to the one or more heaters to vary the heat in at least a portion of the produced fluids provided to the olefin generating unit.

6731. The method of claim 6706, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and using heat in the produced fluids when generating olefins from at least a portion of the produced fluids.

6732. The method of claim 6706, wherein the produced fluids comprise steam, and further comprising providing at least a portion of the produced fluids to an olefin generating unit, and using steam in the produced fluids when generating olefins from at least a portion of the produced fluids.

6733. The method of claim 6706, wherein the produced fluids comprise steam, and further comprising providing at least a portion of the produced fluids to an olefin generating unit, generating olefins from at least a portion of the produced fluids, and wherein at least some steam used for generating olefins is provided by the steam in the produced fluids.

6734. The method of claim 6706, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via an insulated conduit, and wherein the insulated conduit is insulated to inhibit heat loss from the produced fluids.

6735. The method of claim 6706, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via a heated conduit.

6736. The method of claim 6706, further comprising separating at least a portion of the produced fluids into one or more fractions wherein the one or more fractions comprise a naphtha fraction, and further comprising providing the naphtha fraction to an olefin generating unit.

6737. The method of claim 6706, further comprising separating at least a portion of the produced fluids into one or more fractions wherein the one or more fractions comprise a olefin generating fraction wherein the olefin generating fraction comprises hydrocarbons having a carbon number greater than about 1 and a carbon number less than about 8, and further comprising providing the olefin generating fraction to a olefin generating unit.

6738. The method of claim 6706, further comprising separating at least a portion of the produced fluids into one or more fractions wherein the one or more fractions comprise an olefin generating fraction wherein the olefin generating fraction comprises hydrocarbons having a carbon number greater than about 1 and a carbon number less than about 6, and further comprising providing the olefin generating fraction to a olefin generating unit.

6739. The method of claim 6706, further comprising providing at least the portion of the produced fluids to a component removal unit such that at least one component stream and a reduced component fluid stream are formed, and then providing the reduced component fluid stream to an olefin generating unit.

6740. The method of claim 6739, wherein the component comprises a metal.

6741. The method of claim 6739, wherein the component comprises arsenic.

6742. The method of claim 6739, wherein the component comprises mercury.

6743. The method of claim 6739, wherein the component comprises lead.

6744. The method of claim 6706, further comprising providing at least the portion of the produced fluids to a component removal unit such that at least one component stream and a reduced component fluid stream are formed, then providing the reduced component fluid stream to a molecular hydrogen separating unit such that a molecular hydrogen stream and a reduced hydrogen fluid stream are formed, then providing the molecular hydrogen stream to a hydrotreating unit, and then providing the reduced hydrogen produced fluid stream to an olefin generating unit.

6745. The method of claim 6706, wherein the produced fluids comprise molecular hydrogen and wherein the molecular hydrogen is used when treating the produced fluids.

6746. The method of claim 6706, wherein the produced fluids comprise steam and wherein the steam is used when treating the produced fluids.

6747. The method of claim 6706, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and using heat in the produced fluids when generating olefins from at least a portion of the produced fluids.

6748. The method of claim 6706, wherein the produced fluids comprise steam, and further comprising providing at least a portion of the produced fluids to an olefin generating unit, and using steam in the produced fluids when generating olefins from at least a portion of the produced fluids.

6749. The method of claim 6706, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via an insulated conduit, and wherein the insulated conduit is insulated to inhibit heat loss from the produced fluids.

6750. The method of claim 6706, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via a heated conduit.

6751. The method of claim 6706, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6752. The method of claim 6706, wherein the formation fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6753. A method of separating olefins from fluids produced from a hydrocarbon containing formation, comprising:

separating olefins from the produced fluids, wherein the produced fluids are obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing fluids from the formation, wherein the produced fluids comprise olefins.

6754. The method of claim 6753, wherein olefins comprise ethylene.

6755. The method of claim 6753, wherein olefins comprise propylene.

6756. The method of claim 6753, further comprising separating liquids from the produced fluids.

6757. The method of claim 6753, wherein the produced fluids comprise molecular hydrogen, and further comprising separating at least a portion of the molecular hydrogen from the produced fluids, and utilizing at least a portion of the separated molecular hydrogen in one or more treatment processes.

6758. The method of claim 6753, wherein the produced fluids comprise molecular hydrogen, and further comprising removing at least a portion of the molecular hydrogen from the produced fluids using a hydrogen removal unit.

6759. The method of claim 6753, wherein the produced fluids comprises molecular hydrogen, and further comprising removing at least a portion of the molecular hydrogen from the produced fluids using a membrane.

6760. The method of claim 6753, further comprising controlling a fluid pressure within at least a portion of the formation to enhance production of olefins in the produced fluids.

6761. The method of claim 6753, further comprising controlling a temperature within at least a portion of the formation to enhance production of olefins in the produced fluids.

6762. The method of claim 6753, further comprising controlling a temperature profile within at least a portion of the formation to enhance production of olefins in the produced fluids.

6763. The method of claim 6753, further comprising controlling a heating rate within at least a portion of the formation to enhance production of olefins in the produced fluids.

6764. The method of claim 6753, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and further comprising varying heat provided to the one or more heaters to vary the heat in at least a portion of the produced fluids provided to the olefin generating unit.

6765. The method of claim 6753, further comprising providing at least a portion of the produced fluids to an olefin generating unit, and using heat in the produced fluids when generating olefins from at least a portion of the produced fluids.

6766. The method of claim 6753, wherein the produced fluids comprise steam, and further comprising providing at least a portion of the produced fluids to an olefin generating unit, and using steam in the produced fluids when generating olefins from at least a portion of the produced fluids.

6767. The method of claim 6753, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via an insulated conduit, and wherein the insulated conduit is insulated to inhibit heat loss from the produced fluids.

6768. The method of claim 6753, further comprising providing at least a portion of the produced fluids to an olefin generating unit wherein at least a portion of the produced fluids are provided to the olefin generating unit via a heated conduit.

6769. The method of claim 6753, further comprising separating at least a portion of the produced fluids into one or more fractions wherein the one or more fractions comprise a naphtha fraction, and further comprising providing the naphtha fraction to an olefin generating unit.

6770. The method of claim 6753, further comprising separating at least a portion of the produced fluids into one or more fractions wherein the one or more fractions comprise a olefin generating fraction wherein the olefin generating fraction comprises hydrocarbons having a carbon number greater than about 1 and a carbon number less than about 8, and further comprising providing the olefin generating fraction to a olefin generating unit.

6771. The method of claim 6753, further comprising separating at least a portion of the produced fluids into one or more fractions wherein the one or more fractions comprise an olefin generating fraction wherein the olefin generating fraction comprises hydrocarbons having a carbon number greater than about 1 and a carbon number less than about 6, and further comprising providing the olefin generating fraction to a olefin generating unit.

6772. The method of claim 6753, further comprising providing at least the portion of the produced fluids to a component removal unit such that at least one component stream and a reduced component fluid stream are formed, and then providing the reduced component fluid stream to an olefin generating unit.

6773. The method of claim 6772, wherein the component comprises a metal.

6774. The method of claim 6772, wherein the component comprises arsenic.

6775. The method of claim 6772, wherein the component comprises mercury.

6776. The method of claim 6772, wherein the component comprises lead.

6777. The method of claim 6753, further comprising providing at least the portion of the produced fluids to a component removal unit such that at least one component stream and a reduced component fluid stream are formed, then providing the reduced component fluid stream to a molecular hydrogen separating unit such that a molecular hydrogen stream and a reduced hydrogen fluid stream are formed, then providing the molecular hydrogen stream to a hydrotreating unit, and then providing the reduced hydrogen produced fluid stream to an olefin generating unit.

6778. The method of claim 6753, further comprising controlling a temperature gradient within at least a portion of the formation to enhance production of olefins in the produced fluids.

6779. The method of claim 6753, further comprising controlling a fluid pressure within at least a portion of the formation to enhance production of olefins in the produced fluids.

6780. The method of claim 6753, further comprising controlling a temperature within at least a portion of the formation to enhance production of olefins in the produced fluids.

6781. The method of claim 6753, further comprising controlling a heating rate within at least a portion of the formation to enhance production of olefins in the produced fluids.

6782. The method of claim 6753, further comprising separating the olefins from the produced fluids such that an amount of molecular hydrogen utilized in one or more downstream hydrotreating units decreases.

6783. The method of claim 6753, further comprising removing at least a portion of the olefins prior to hydrotreating produced fluids.

6784. A method of enhancing phenol production from an in situ hydrocarbon containing formation, comprising:

controlling at least one condition within at least a portion of the formation to enhance production of phenols in formation fluid, wherein the formation fluid is obtained by;

providing heat from one or more heaters to at least the portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing formation fluids from the formation.

6785. The method of claim 6784, further comprising separating at least a portion of the phenols from the produced fluids.

6786. The method of claim 6784, wherein controlling at least one condition in the formation comprises controlling a fluid pressure within at least a portion of the formation.

6787. The method of claim 6784, wherein controlling at least one condition in the formation comprises controlling a temperature gradient within at least a portion of the formation.

6788. The method of claim 6784, wherein controlling at least one condition in the formation comprises controlling a temperature within at least a portion of the formation.

6789. The method of claim 6784, wherein controlling at least one condition in the formation comprises controlling a heating rate within at least a portion of the formation.

6790. The method of claim 6784 wherein the at least one condition in the formation is controlled such that an average carbon number of the produced fluids is lowered.

6791. The method of claim 6784, further comprising separating at least a portion of the produced fluids into a phenols fraction at a wellhead using condensation.

6792. The method of claim 6784, further comprising separating at least a portion of the produced fluids into a phenols fraction at a wellhead using fractionation.

6793. The method of claim 6784, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a naphtha fraction, and further comprising providing the naphtha fraction to an extraction unit, and separating at least some phenols from the naphtha fraction.

6794. The method of claim 6784, further comprising separating the produced fluids into a gas stream and a liquid stream, separating the liquid stream into a phenols fraction and a hydrocarbon containing fraction, and providing the hydrocarbon containing fraction to a pipeline.

6795. The method of claim 6784, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a phenols fraction, and further comprising providing the phenols fraction to an extraction unit, and separating at least some phenols from the phenols fluids.

6796. The method of claim 6784, further comprising separating the phenols from the produced fluids with a water/methanol extraction process.

6797. The method of claim 6784, further comprising separating the phenols from the produced fluids such that an amount of molecular hydrogen utilized in one or more downstream hydrotreating units decreases.

6798. The method of claim 6784, wherein controlling a condition comprises lowering the average carbon number of the produced fluids.

6799. The method of claim 6784, further comprising removing at least a portion of the phenols prior to hydrotreating produced fluids.

6800. The method of claim 6784, further comprising removing at least a portion of the phenols prior to hydrotreating produced fluids, and wherein removing at least the portion reduces an amount of molecular hydrogen required in a hydrotreating unit.

6801. The method of claim 6784, further comprising reacting at least a portion of the phenols with molecular hydrogen to form phenol.

6802. The method of claim 6784, wherein the selected section has been selected for heating using an oxygen content of at least some hydrocarbons in the selected section.

6803. The method of claim 6784, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6804. The method of claim 6784, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6805. A method of controlling phenol production from a hydrocarbon containing formation, comprising;

converting at least a portion of formation fluid into phenol, wherein the formation fluids in situ are obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section; and

producing formation fluids from the formation.

6806. The method of claim 6805, wherein the formation fluids comprise phenols.

6807. The method of claim 6805, wherein converting at least a portion of formation fluid into phenol comprises reacting at least a portion of the phenols with molecular hydrogen to form phenol.

6808. The method of claim 6805, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6809. The method of claim 6805, wherein the formation fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6810. A method of separating phenols from fluids produced from a hydrocarbon containing formation, comprising:

separating phenols from the produced fluids, wherein the produced fluids are obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing fluids from the formation, wherein the produced fluids comprise phenols.

6811. The method of claim 6810, further comprising controlling a fluid pressure within at least a portion of the formation.

6812. The method of claim 6810, further comprising controlling a temperature gradient within at least a portion of the formation.

6813. The method of claim 6810, further comprising controlling a temperature within at least a portion of the formation.

6814. The method of claim 6810, further comprising controlling a heating rate within at least a portion of the formation.

6815. The method of claim 6810, wherein separating the phenols from the produced fluids, further comprises removing a naphtha fraction from the produced fluids, and separating phenols from the naphtha fraction.

6816. The method of claim 6810, wherein separating the phenols from the produced fluids, further comprises removing a phenols fraction from the produced fluids, and separating at least some phenols from the phenols fraction.

6817. The method of claim 6810, wherein separating the phenols from the produced fluids, further comprises removing phenols with a water/methanol extraction.

6818. The method of claim 6810, wherein separating the phenols from the produced fluids decreases an amount of molecular hydrogen utilized in one or more downstream hydrotreating units.

6819. The method of claim 6810, wherein controlling a condition comprises lowering the average carbon number of the produced fluids.

6820. The method of claim 6810, further comprising removing at least a portion of the phenols prior to hydrotreating produced fluids.

6821. The method of claim 6810, further comprising removing at least a portion of the phenols prior to hydrotreating produced fluids, and wherein removing at least the portion reduces an amount of molecular hydrogen required in a hydrotreating unit.

6822. The method of claim 6810, further comprising reacting at least a portion of the phenols with molecular hydrogen to form phenol.

6823. The method of claim 6810, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6824. The method of claim 6810, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6825. A method of enhancing phenol production from a hydrocarbon containing formation, comprising:

controlling at least one condition within at least a portion of the formation to enhance production of phenols in formation fluid, wherein the formation fluid is obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing formation fluids from the formation.

6826. The method of claim 6825, further comprising separating at least a portion of the phenols from the produced fluids.

6827. The method of claim 6825, further comprising controlling at least one condition in situ such that an average carbon number of the produced fluids is lowered.

6828. The method of claim 6825, further comprising controlling a temperature gradient within at least a portion of the formation.

6829. The method of claim 6825, further comprising controlling a fluid pressure within at least a portion of the formation.

6830. The method of claim 6825, further comprising controlling a temperature within at least a portion of the formation.

6831. The method of claim 6825, further comprising controlling a heating rate within at least a portion of the formation.

6832. The method of claim 6825, further comprising separating at least a portion of the produced fluids into a phenols fraction at a wellhead using condensation.

6833. The method of claim 6825, further comprising separating at least a portion of the produced fluids into a phenols fraction at a wellhead using fractionation.

6834. The method of claim 6825, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a naphtha fraction, and further comprising providing the naphtha fraction to an extraction unit, and separating at least some phenols from the naphtha fraction.

6835. The method of claim 6825, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a phenols fraction, and further comprising providing the phenols fraction to an extraction unit, and separating at least some phenols from the phenols fluids.

6836. The method of claim 6825, further comprising separating the phenols from the produced fluids with a water/methanol extraction process.

6837. The method of claim 6825, further comprising separating the phenols from the produced fluids such that an amount of molecular hydrogen utilized in one or more downstream hydrotreating units decreases.

6838. The method of claim 6825, further comprising removing at least a portion of the phenols prior to hydrotreating produced fluids.

6839. The method of claim 6825, further comprising removing at least a portion of the phenols prior to hydrotreating produced fluids, and wherein removing at least the portion reduces an amount of molecular hydrogen required in a hydrotreating unit.

6840. The method of claim 6825, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6841. The method of claim 6825, wherein the formation fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6842. A method of enhancing BTEX compounds production from a hydrocarbon containing formation, comprising:

controlling at least one condition within at least a portion of the formation to enhance production of BTEX compounds in formation fluid, wherein the formation fluid is obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing formation fluids from the formation.

6843. The method of claim 6842, further comprising separating at least a portion of the BTEX compounds from the produced fluids.

6844. The method of claim 6842, further comprising separating at least a portion of the BTEX compounds from the produced fluids via solvent extraction.

6845. The method of claim 6842, further comprising separating at least a portion of the BTEX compounds from the produced fluids via distillation.

6846. The method of claim 6842, further comprising separating at least a portion of the BTEX compounds from the produced fluids via condensation.

6847. The method of claim 6842, further comprising separating at least a portion of the BTEX compounds from the produced fluids such that an amount of molecular hydrogen utilized in one or more downstream hydrotreating units decreases.

6848. The method of claim 6842, wherein controlling at least one condition in the formation comprises controlling a fluid pressure within at least a portion of the formation.

6849. The method of claim 6842, wherein controlling at least one condition in the formation comprises controlling a temperature gradient within at least a portion of the formation.

6850. The method of claim 6842, wherein controlling at least one condition in the formation comprises controlling a temperature within at least a portion of the formation.

6851. The method of claim 6842, wherein controlling at least one condition in the formation comprises controlling a heating rate within at least a portion of the formation.

6852. The method of claim 6842, further comprising removing at least a portion of the BTEX compounds prior to hydrotreating produced fluids.

6853. The method of claim 6842, further comprising removing at least a portion of the phenols prior to hydrotreating produced fluids, and wherein removing at least the portion reduces an amount of molecular hydrogen required in a hydrotreating unit.

6854. The method of claim 6842, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6855. The method of claim 6842, wherein the formation fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6856. A method of separating BTEX compounds from formation fluid from a hydrocarbon containing formation, comprising:

separating at least a portion of the BTEX compounds from the formation fluid wherein the formation fluid is obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing fluids from the formation, wherein the produced fluids comprise BTEX compounds.

6857. The method of claim 6856, further comprising hydrotreating at least a portion of the produced fluids after the BTEX compounds have been separated from same.

6858. The method of claim 6856, wherein separating at least a portion of the BTEX compounds from the produced fluids comprises extracting at least the portion of the BTEX compounds from the produced fluids via solvent extraction.

6859. The method of claim 6856, wherein separating at least a portion of the BTEX compounds from the produced fluids comprises distilling at least the portion of the BTEX compounds from the produced fluids.

6860. The method of claim 6856, wherein separating at least a portion of the BTEX compounds from the produced fluids comprises condensing at least the portion of the BTEX compounds from the produced fluids.

6861. The method of claim 6856, wherein separating at least a portion of the BTEX compounds from the produced fluids such that an amount of molecular hydrogen utilized in one or more downstream hydrotreating units decreases.

6862. The method of claim 6856, further comprising controlling a fluid pressure within at least a portion of the formation.

6863. The method of claim 6856, further comprising controlling a temperature gradient within at least a portion of the formation.

6864. The method of claim 6856, further comprising controlling a temperature within at least a portion of the formation.

6865. The method of claim 6856, further comprising controlling a heating rate within at least a portion of the formation.

6866. The method of claim 6856, wherein separating at least the portion of BTEX compounds from the produced fluids further comprises removing a naphtha fraction from the produced fluids, and separating at least the portion of BTEX compounds from the naphtha fraction.

6867. The method of claim 6856, wherein separating at least the portion of BTEX compounds from the produced fluids, further comprises removing a BTEX fraction from the produced fluids, and separating at some BTEX compounds from the BTEX fraction.

6868. The method of claim 6856, wherein separating at least the portion of BTEX compounds from the produced fluids decreases an amount of molecular hydrogen utilized in one or more downstream hydrotreating units.

6869. A method of in situ converting at least a portion of formation fluid into BTEX compounds, comprising:

in situ converting at least the portion of the formation fluid into BTEX compounds, wherein the formation fluid are obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation such that at least some hydrocarbons in the formation are pyrolyzed; and

producing formation fluid from the formation.

6870. The method of claim 6869, further comprising providing at least a portion of the formation fluid to an BTEX generating unit.

6871. The method of claim 6869, further comprising providing at least a portion of the formation fluid to a catalytic reforming unit.

6872. The method of claim 6869, further comprising hydrotreating at least some of the formation fluid, and then separating the hydrotreated mixture into one more streams comprising a naphtha stream, and then reforming at least a portion the naphtha stream to form a reformate comprising BTEX compounds, and then separating at least a portion of the BTEX compounds from the reformate.

6873. The method of claim 6869, further comprising hydrotreating at least some of the formation fluid, and then separating the hydrotreated mixture into one more streams comprising a naphtha stream, and then reforming at least apportion the naphtha stream to form a molecular hydrogen stream and a reformate comprising BTEX compounds, and then separating at least a portion of the BTEX compounds from the reformate, and then utilizing the molecular hydrogen stream to hydrotreat at least some of the formation fluid.

6874. The method of claim 6869, further comprising hydrotreating the formation fluid, and then separating the hydrotreated formation fluid into one more streams comprising a naphtha stream, and then reforming at least a portion the naphtha stream to form a reformate comprising BTEX compounds, and then separating at least a portion of the reformate into two or more streams comprising a raffinate and a BTEX stream.

6875. The method of claim 6869, wherein the formation fluid is at least 200°

C., and fturther comprising using heat in the formation fluid to hydrotreat at least a portion of the formation fluid.

6876. The method of claim 6869, further comprising separating at least a portion of the formation fluid into one or more fractions wherein the one or more fractions comprise a naphtha fraction, and further comprising providing the naphtha fraction to a catalytic reforming unit.

6877. The method of claim 6869, further comprising separating at least a portion of the formation fluid into one or more fractions wherein the one or more fractions comprise a BTEX compound generating fraction wherein the BTEX compound generating fraction comprises hydrocarbons, and further comprising providing the BTEX compound generating fraction to a catalytic reforming unit.

6878. The method of claim 6869, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6879. The method of claim 6869, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6880. A method of enhancing naphthalene production from a hydrocarbon containing formation, comprising:

controlling at least one condition within at least a portion of the formation to enhance production of naphthalene in formation fluid, wherein the formation fluid is obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing formation fluids from the formation.

6881. The method of claim 6880, further comprising separating at least a portion of the naphthalene from the produced fluids.

6882. The method of claim 6880, wherein controlling at least one condition in the formation comprises controlling a fluid pressure within at least a portion of the formation.

6883. The method of claim 6880, wherein controlling at least one condition in the formation comprises controlling a temperature gradient within at least a portion of the formation.

6884. The method of claim 6880, wherein controlling at least one condition in the formation comprises controlling a temperature within at least a portion of the formation.

6885. The method of claim 6880, wherein controlling at least one condition in the formation comprises controlling a heating rate within at least a portion of the formation.

6886. The method of claim 6880, further comprising separating the produced fluids into one or more fractions using distillation.

6887. The method of claim 6880, further comprising separating the produced fluids into one or more fractions using condensation.

6888. The method of claim 6880, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and further comprising providing the heart cut to an extraction unit, and separating at least some naphthalene from the heart cut.

6889. The method of claim 6880, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a naphthalene fraction, and further comprising providing the naphthalene fraction to an extraction unit, and separating at least some naphthalene from the naphthalene fraction.

6890. The method of claim 6880, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6891. The method of claim 6880, wherein the formation fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6892. A method of separating naphthalene from fluids produced from a hydrocarbon containing formation, comprising:

separating naphthalene from the produced fluids, wherein the produced fluids are obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing fluids from the formation, wherein the produced fluids comprise naphthalene.

6893. The method of claim 6892, further comprising controlling a fluid pressure within at least a portion of the formation.

6894. The method of claim 6892, further comprising controlling a temperature gradient within at least a portion of the formation.

6895. The method of claim 6892, further comprising controlling a temperature within at least a portion of the formation.

6896. The method of claim 6892, further comprising controlling a heating rate within at least a portion of the formation.

6897. The method of claim 6892, wherein separating at least some naphthalene from the produced fluids further comprises separating the produced fluids into one or more fractions using distillation.

6898. The method of claim 6892, wherein separating at least some naphthalene-from the produced fluids further comprises separating the produced fluids into one or more fractions using condensation.

6899. The method of claim 6892, wherein separating at least some naphthalene from the produced fluids further comprises separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and extracting at least a portion of the naphthalene from the heart cut.

6900. The method of claim 6892, wherein separating at least some naphthalene from the produced fluids further comprises removing a naphtha fraction from the produced fluids, and separating at least a portion of the naphthalene from the naphtha fraction.

6901. The method of claim 6892, wherein separating at least some naphthalene from the produced fluids further comprises removing an naphthalene fraction from the produced fluids, and separating at least a portion of the naphthalene from the naphthalene fraction.

6902. The method of claim 6892, wherein separating the naphthalene from the produced fluids further comprises removing naphthalene using distillation.

6903. The method of claim 6892, wherein separating the naphthalene from the produced fluids further comprises removing naphthalene using crystallization.

6904. The method of claim 6892, further comprising removing at least a portion of the naphthalene prior to hydrotreating produced fluids.

6905. The method of claim 6892, further comprising removing at least a portion of the phenols prior to hydrotreating produced fluids, and wherein removing at least the portion reduces an amount of molecular hydrogen required in a hydrotreating unit.

6906. The method of claim 6892, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6907. The method of claim 6892, wherein the formation fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6908. A method of enhancing anthracene production from a hydrocarbon containing formation, comprising:

controlling at least one condition within at least a portion of the formation to enhance production of anthracene in formation fluid, wherein the formation fluid is obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing formation fluids from the formation.

6909. The method of claim 6908, further comprising separating at least a portion of the anthracene from the produced fluids.

6910. The method of claim 6908, wherein controlling at least one condition in the formation comprises controlling a fluid pressure within at least a portion of the formation.

6911. The method of claim 6908, wherein controlling at least one condition in the formation comprises controlling a temperature gradient within at least a portion of the formation.

6912. The method of claim 6908, wherein controlling at least one condition in the formation comprises controlling a temperature within at least a portion of the formation.

6913. The method of claim 6908, wherein controlling at least one condition in the formation comprises controlling a heating rate within at least a portion of the formation.

6914. The method of claim 6908, further comprising separating the produced fluids into one or more fractions using distillation.

6915. The method of claim 6908, further comprising separating the produced fluids into one or more fractions using condensation.

6916. The method of claim 6908, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and further comprising providing the heart cut to an extraction unit, and separating at least some anthracene from the heart cut.

6917. The method of claim 6908, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a anthracene fraction, and further comprising providing the anthracene fraction to an extraction unit, and separating at least some anthracene from the anthracene fraction.

6918. The method of claim 6908, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6919. The method of claim 6908, wherein the formation fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6920. A method of separating anthracene from fluids produced from a hydrocarbon containing formation, comprising:

separating anthracene from the produced fluids, wherein the produced fluids are obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing fluids from the formation, wherein the produced fluids comprise anthracene.

6921. The method of claim 6920, further comprising controlling a fluid pressure within at least a portion of the formation.

6922. The method of claim 6920, further comprising controlling a temperature gradient within at least a portion of the formation.

6923. The method of claim 6920, further comprising controlling a temperature within at least a portion of the formation.

6924. The method of claim 6920, further comprising controlling a heating rate within at least a portion of the formation.

6925. The method of claim 6920, wherein separating at least some anthracene from the produced fluids further comprises separating the produced fluids into one or more fractions using distillation.

6926. The method of claim 6920, wherein separating at least some anthracene from the produced fluids further comprises separating the produced fluids into one or more fractions using condensation.

6927. The method of claim 6920, wherein separating at least some anthracene from the produced fluids further comprises separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and extracting at least a portion of the anthracene from the heart cut.

6928. The method of claim 6920, wherein separating at least some anthracene from the produced fluids further comprises removing a naphtha fraction from the produced fluids, and separating at least a portion of the anthracene from the naphtha fraction.

6929. The method of claim 6920, wherein separating at least some anthracene from the produced fluids further comprises removing an anthracene fraction from the produced fluids, and separating at least a portion of the anthracene from the anthracene fraction.

6930. The method of claim 6920, wherein separating the anthracene from the produced fluids further comprises removing anthracene using distillation.

6931. The method of claim 6920, wherein separating the anthracene from the produced fluids further comprises removing anthracene using crystallization.

6932. The method of claim 6920, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6933. The method of claim 6920, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6934. A method of separating ammonia from fluids produced from a hydrocarbon containing formation, comprising:

separating at least a portion of the ammonia from the produced fluid, wherein the produced fluids are obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing fluids from the formation.

6935. The method of claim 6934, wherein the produced fluids are pyrolyzation fluids.

6936. The method of claim 6934, wherein separating at least a portion of the ammonia from the produced fluids further comprises providing at least a portion of the produced fluids to a sour water stripper.

6937. The method of claim 6934, wherein separating at least a portion of the ammonia from the produced fluids further comprises separating the produced fluids into one or more fractions, and providing at least a portion of the one or more fractions to a stripping unit.

6938. The method of claim 6934, further comprising using at least a portion of the separated ammonia to generate ammonium sulfate.

6939. The method of claim 6934, further comprising using at least a portion of the separated ammonia to generate urea.

6940. The method of claim 6934, wherein the produced fluids comprise carbon dioxide, and further comprising separating the carbon dioxide from the produced fluids, and reacting the carbon dioxide with at least some ammonia to form urea.

6941. The method of claim 6934, wherein the produced fluids comprise hydrogen sulfide, and further comprising separating the hydrogen sulfide from the produced fluids, converting at least some hydrogen sulfide into sulfuric acid, and reacting at lest some sulfuric acid with at lease some ammonia to form ammonium sulfate.

6942. The method of claim 6934, wherein the produced fluids further comprise hydrogen sulfide, and further comprising separating at least a portion of the hydrogen sulfide from the produced fluids, and converting at least some hydrogen sulfide into sulfuric acid.

6943. The method of claim 6934, further comprising generating ammonium bicarbonate using separated ammonia.

6944. The method of claim 6934, further comprising providing separated ammonia to a fluid comprising carbon dioxide to generate ammonium bicarbonate.

6945. The method of claim 6934, further comprising providing separated ammonia to at least some synthesis gas to generate ammonium bicarbonate.

6946. The method of claim 6934, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6947. The method of claim 6934, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6948. A method of generating ammonia from fluids produced from a hydrocarbon containing formation, comprising:

hydrotreating at least a portion of the produced fluids to generate ammonia, wherein the produced fluids are obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing fluids from the formation.

6949. The method of claim 6948, wherein the produced fluids are pyrolyzation fluids.

6950. The method of claim 6948, further comprising separating at least a portion of the ammonia from the hydrotreated fluids.

6951. The method of claim 6948, further comprising using at least a portion of the ammonia to generate ammonium sulfate.

6952. The method of claim 6948, further comprising using at least a portion of the ammonia to generate urea.

6953. The method of claim 6948, wherein the produced fluids further comprise carbon dioxide, and further comprising separating at least a portion of the carbon dioxide from the produced fluids, and reacting at least the portion of the carbon dioxide with at least a portion of ammonia to form urea.

6954. The method of claim 6948, wherein the produced fluids further comprise hydrogen sulfide, and further comprising separating at least a portion of the hydrogen sulfide from the produced fluids, converting at least some hydrogen sulfide into sulfuric acid, and reacting at least some sulfuric acid with at least a portion of the ammonia to form ammonium sulfate.

6955. The method of claim 6948, wherein the produced fluids further comprise hydrogen sulfide, and further comprising separating at least a portion of the hydrogen sulfide from the produced fluids, and converting at least some hydrogen sulfide into sulfuric acid.

6956. The method of claim 6948, further comprising generating ammonium bicarbonate using at least a portion of the ammonia.

6957. The method of claim 6948, further comprising providing at least a portion of the ammonia to a fluid comprising carbon dioxide to generate ammonium bicarbonate.

6958. The method of claim 6948, further comprising providing at least a portion of the ammonia to at least some synthesis gas to generate ammonium bicarbonate.

6959. The method of claim 6948, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6960. The method of claim 6948, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6961. A method of enhancing pyridines production from a hydrocarbon containing formation, comprising:

controlling at least one condition within at least a portion of the formation to enhance production of pyridines in formation fluid, wherein the formation fluid is obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing formation fluids from the formation.

6962. The method of claim 6961, further comprising separating at least a portion of the pyridines from the produced fluids.

6963. The method of claim 6961, wherein controlling at least one condition in the formation comprises controlling a fluid pressure within at least a portion of the formation.

6964. The method of claim 6961, wherein controlling at least one condition in the formation comprises controlling a temperature gradient within at least a portion of the formation.

6965. The method of claim 6961, wherein controlling at least one condition in the formation comprises controlling a temperature within at least a portion of the formation.

6966. The method of claim 6961, wherein controlling at least one condition in the formation comprises controlling a heating rate within at least a portion of the formation.

6967. The method of claim 6961, further comprising separating the produced fluids into one or more fractions using distillation.

6968. The method of claim 6961, further comprising separating the produced fluids into one or more fractions using condensation.

6969. The method of claim 6961, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and further comprising providing the heart cut to an extraction unit, and separating at least some pyridines from the heart cut.

6970. The method of claim 6961, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a pyridines fraction, and further comprising providing the pyridines fraction to an extraction unit, and separating at least some pyridines from the pyridines fraction.

6971. The method of claim 6961, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6972. The method of claim 6961, wherein the formation fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6973. A method of separating pyridines from fluids produced from a hydrocarbon containing formation, comprising:

separating pyridines from the produced fluids, wherein the produced fluids are obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing fluids from the formation, wherein the produced fluids comprise pyridines.

6974. The method of claim 6973, further comprising controlling a fluid pressure within at least a portion of the formation.

6975. The method of claim 6973, further comprising controlling a temperature gradient within at least a portion of the formation.

6976. The method of claim 6973, further comprising controlling a temperature within at least a portion of the formation.

6977. The method of claim 6973, further comprising controlling a heating rate within at least a portion of the formation.

6978. The method of claim 6973, wherein separating at least some pyridines from the produced fluids further comprises separating the produced fluids into one or more fractions using distillation.

6979. The method of claim 6973, wherein separating at least some pyridines from the produced fluids further comprises separating the produced fluids into one or more fractions using condensation.

6980. The method of claim 6973, wherein separating at least some pyridines from the produced fluids further comprises separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and extracting at least a portion of the pyridines from the heart cut.

6981. The method of claim 6973, wherein separating at least some pyridines from the produced fluids further comprises removing a naphtha fraction from the produced fluids, and separating at least a portion of the pyridines from the naphtha fraction.

6982. The method of claim 6973, wherein separating at least some pyridines from the produced fluids further comprises removing an pyridines fraction from the produced fluids, and separating at least a portion of the pyridines from the pyridines fraction.

6983. The method of claim 6973, wherein separating the pyridines from the produced fluids further comprises removing pyridines using distillation.

6984. The method of claim 6973, wherein separating the pyridines from the produced fluids further comprises removing pyridines using crystallization.

6985. The method of claim 6973, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6986. The method of claim 6973, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6987. A method of enhancing pyrroles production from a hydrocarbon containing formation, comprising:

controlling at least one condition within at least a portion of the formation to enhance production of pyrroles in formation fluid, wherein the formation fluid is obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing formation fluids from the formation.

6988. The method of claim 6987, further comprising separating at least a portion of the pyrroles from the produced fluids.

6989. The method of claim 6987, wherein controlling at least one condition in the formation comprises controlling a fluid pressure within at least a portion of the formation.

6990. The method of claim 6987, wherein controlling at least one condition in the formation comprises controlling a temperature gradient within at least a portion of the formation.

6991. The method of claim 6987, wherein controlling at least one condition in the formation comprises controlling a temperature within at least a portion of the formation.

6992. The method of claim 6987, wherein controlling at least one condition in the formation comprises controlling a heating rate within at least a portion of the formation.

6993. The method of claim 6987, further comprising separating the produced fluids into one or more fractions using distillation.

6994. The method of claim 6987, further comprising separating the produced fluids into one or more fractions using condensation.

6995. The method of claim 6987, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and further comprising providing the heart cut to an extraction unit, and separating at least some pyrroles from the heart cut.

6996. The method of claim 6987, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a pyrroles fraction, and further comprising providing the pyrroles fraction to an extraction unit, and separating at least some pyrroles from the pyrroles fraction.

6997. The method of claim 6987, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

6998. The method of claim 6987, wherein the formation fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

6999. A method of separating pyrroles from fluids produced from a hydrocarbon containing formation, comprising:

separating pyrroles from the produced fluids, wherein the produced fluids are obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing fluids from the formation, wherein the produced fluids comprise pyrroles.

7000. The method of claim 6999, further comprising controlling a fluid pressure within at least a portion of the formation.

7001. The method of claim 6999, further comprising controlling a temperature gradient within at least a portion of the formation.

7002. The method of claim 6999, further comprising controlling a temperature within at least a portion of the formation.

7003. The method of claim 6999, further comprising controlling a heating rate within at least a portion of the formation.

7004. The method of claim 6999, wherein separating at least some pyrroles from the produced fluids further comprises separating the produced fluids into one or more fractions using distillation.

7005. The method of claim 6999, wherein separating at least some pyrroles from the produced fluids further comprises separating the produced fluids into one or more fractions using condensation.

7006. The method of claim 6999, wherein separating at least some pyrroles from the produced fluids further comprises separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and extracting at least a portion of the pyrroles from the heart cut.

7007. The method of claim 6999, wherein separating at least some pyrroles from the produced fluids further comprises removing a naphtha fraction from the produced fluids, and separating at least a portion of the pyrroles from the naphtha fraction.

7008. The method of claim 6999, wherein separating at least some pyrroles from the produced fluids further comprises removing an pyrroles fraction from the produced fluids, and separating at least a portion of the pyrroles from the pyrroles fraction.

7009. The method of claim 6999, wherein separating the pyrroles from the produced fluids further comprises removing pyrroles using distillation.

7010. The method of claim 6999, wherein separating the pyrroles from the produced fluids further comprises removing pyrroles using crystallization.

7011. The method of claim 6999, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

7012. The method of claim 6999, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

7013. A method of enhancing thiophenes production from a hydrocarbon containing formation, comprising:

controlling at least one condition within at least a portion of the-formation to enhance production of thiophenes in formation fluid, wherein the formation fluid is obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing formation fluids from the formation.

7014. The method of claim 7013, further comprising separating at least a portion of the thiophenes from the produced fluids.

7015. The method of claim 7013, wherein controlling at least one condition in the formation comprises controlling a fluid pressure within at least a portion of the formation.

7016. The method of claim 7013, wherein controlling at least one condition in the formation comprises controlling a temperature gradient within at least a portion of the formation.

7017. The method of claim 7013, wherein controlling at least one condition in the formation comprises controlling a temperature within at least a portion of the formation.

7018. The method of claim 7013, wherein controlling at least one condition in the formation comprises controlling a heating rate within at least a portion of the formation.

7019. The method of claim 7013, further comprising separating the produced fluids into one or more fractions using distillation.

7020. The method of claim 7013, further comprising separating the produced fluids into one or more fractions using condensation.

7021. The method of claim 7013, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and further comprising providing the heart cut to an extraction unit, and separating at least some thiophenes from the heart cut.

7022. The method of claim 7013, further comprising separating the produced fluids into one or more fractions wherein the one or more fractions comprise a thiophenes fraction, and further comprising providing the thiophenes fraction to an extraction unit, and separating at least some thiophenes from the thiophenes fraction.

7023. The method of claim 7013, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

7024. The method of claim 7013, wherein the formation fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

7025. A method of separating thiophenes from fluids produced from a hydrocarbon containing formation, comprising:

separating thiophenes from the produced fluids, wherein the produced fluids are obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing fluids from the formation, wherein the produced fluids comprise thiophenes.

7026. The method of claim 7025, further comprising controlling a fluid pressure within at least a portion of the formation.

7027. The method of claim 7025, further comprising controlling a temperature gradient within at least a portion of the formation.

7028. The method of claim 7025, further comprising controlling a temperature within at least a portion of the formation.

7029. The method of claim 7025, further comprising controlling a heating rate within at least a portion of the formation.

7030. The method of claim 7025, wherein separating at least some thiophenes from the produced fluids further comprises separating the produced fluids into one or more fractions using distillation.

7031. The method of claim 7025, wherein separating at least some thiophenes from the produced fluids further comprises separating the produced fluids into one or more fractions using condensation.

7032. The method of claim 7025, wherein separating at least some thiophenes from the produced fluids further comprises separating the produced fluids into one or more fractions wherein the one or more fractions comprise a heart cut, and extracting at least a portion of the thiophenes from the heart cut.

7033. The method of claim 7025, wherein separating at least some thiophenes from the produced fluids further comprises removing a naphtha fraction from the produced fluids, and separating at least a portion of the thiophenes from the naphtha fraction.

7034. The method of claim 7025, wherein separating at least some thiophenes from the produced fluids further comprises removing an thiophenes fraction from the produced fluids, and separating at least a portion of the thiophenes from the thiophenes fraction.

7035. The method of claim 7025, wherein separating the thiophenes from the produced fluids further comprises removing thiophenes using distillation.

7036. The method of claim 7025, wherein separating the thiophenes from the produced fluids further comprises removing thiophenes using crystallization.

7037. The method of claim 7025, wherein the heat provided from at least one heater is transferred to the formation substantially by conduction.

7038. The method of claim 7025, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

7039. A method of treating a hydrocarbon containing formation comprising:

providing a barrier to at least a portion of the formation to inhibit migration of fluids into or out of a treatment area of the formation;

providing heat from one or more heaters to the treatment area;

allowing the heat to transfer from the treatment area to a selected section of the formation; and

producing fluids from the formation.

7040. The method of claim 7039, wherein the heat provided from at least one of the one or more heaters is transferred to at least a portion of the formation substantially by conduction.

7041. The method of claim 7039, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

7042. The method of claim 7039, further comprising hydraulically isolating the treatment area from a surrounding portion of the formation.

7043. The method of claim 7039, further comprising pyrolyzing at least a portion of hydrocarbon containing material within the treatment area.

7044. The method of claim 7039, further comprising generating synthesis gas in at least a portion of the treatment area.

7045. The method of claim 7039, further comprising controlling a pressure within the treatment area.

7046. The method of claim 7039, further comprising controlling a temperature within the treatment area.

7047. The method of claim 7039, further comprising controlling a heating rate within the treatment area.

7048. The method of claim 7039, further comprising controlling an amount of fluid removed from the treatment area.

7049. The method of claim 7039, wherein at least section of the barrier comprises one or more sulfur wells.

7050. The method of claim 7039, wherein at least section of the barrier comprises one or more dewatering wells.

7051. The method of claim 7039, wherein at least section of the barrier comprises one or more injection wells and one or more dewatering wells.

7052. The method of claim 7039, wherein providing a barrier comprises:

providing a circulating fluid to the a portion of the formation surrounding the treatment area; and

removing the circulating fluid proximate the treatment area.

7053. The method of claim 7039, wherein at least section of the barrier comprises a ground cover on a surface of the earth.

7054. The method of claim 7053, wherein at least section of the ground cover is sealed to a surface of the earth.

7055. The method of claim 7039, further comprising inhibiting a release of formation fluid to the earth'"'"'s atmosphere with a ground cover;

and freezing at least a portion of the ground cover to a surface of the earth.

7056. The method of claim 7039, further comprising inhibiting a release of formation fluid to the earth'"'"'s atmosphere.

7057. The method of claim 7039, further comprising inhibiting fluid seepage from a surface of the earth into the treatment area.

7058. The method of claim 7039, wherein at least a section of the barrier is naturally occurring.

7059. The method of claim 7039, wherein at least a section of the barrier comprises a low temperature zone.

7060. The method of claim 7039, wherein at least a section of the barrier comprises a frozen zone.

7061. The method of claim 7039, wherein the barrier comprises an installed portion and a naturally occurring portion.

7062. The method of claim 7039, further comprising:

hydraulically isolating the treatment area from a surrounding portion of the formation; and

maintaining a fluid pressure within the treatment area at a pressure greater than about a fluid pressure within the surrounding portion of the formation.

7063. The method of claim 7039, wherein at least a section of the barrier comprises an impermeable section of the formation.

7064. The method of claim 7039, wherein the barrier comprises a self-sealing portion.

7065. The method of claim 7039, wherein the one or more heaters are positioned at a distance greater than about 5 m from the barrier.

7066. The method of claim 7039, wherein at least one of the one or more heaters is positioned at a distance less than about 1.5 m from the barrier.

7067. The method of claim 7039, wherein at least a portion of the barrier comprises a low temperature zone, and further comprising lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.

7068. The method of claim 7039, wherein the barrier comprises a barrier well and further comprising positioning at least a portion of the barrier well below a water table of the formation.

7069. The method of claim 7039, wherein the treatment area comprises a first treatment area and a second treatment area, and further comprising:

treating the first treatment area using a first treatment process; and

treating the second treatment area using a second treatment process.

7070. A method of treating a hydrocarbon containing formation in situ, comprising:

providing a refrigerant to a plurality of barrier wells placed in a portion of the formation;

establishing a frozen barrier zone to inhibit migration of fluids into or out of a treatment area;

providing heat from one or more heaters to the treatment area;

allowing the heat to transfer from the treatment area to a selected section; and

producing fluids from the formation.

7071. The method of claim 7070, wherein the heat provided from at least one of the one or more heaters is transferred to at least a portion of the formation substantially by conduction.

7072. The method of claim 7070, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

7073. The method of claim 7070, further comprising controlling a fluid pressure within the treatment area.

7074. The method of claim 7070, wherein the frozen barrier zone is proximate the treatment area of the formation.

7075. The method of claim 7070, further comprising hydraulically isolating the treatment area from a surrounding portion of the formation.

7076. The method of claim 7070, further comprising thermally isolating the treatment area from a surrounding portion of the formation.

7077. The method of claim 7070, further comprising maintaining the fluid pressure above a hydrostatic pressure of the formation.

7078. The method of claim 7070, further comprising removing liquid water from at least a portion of the treatment area.

7079. The method of claim 7070, wherein the treatment area is below a water table of the formation.

7080. The method of claim 7070, wherein at least one barrier well of the plurality of barrier wells comprises a corrosion inhibitor.

7081. The method of claim 7070, wherein heating is initiated after formation of the frozen barrier zone.

7082. The method of claim 7070, wherein the refrigerant comprises one or more hydrocarbons.

7083. The method of claim 7070, wherein the refrigerant comprises propane.

7084. The method of claim 7070, wherein the refrigerant comprises isobutane.

7085. The method of claim 7070, wherein the refrigerant comprises cyclopentane.

7086. The method of claim 7070, wherein the refrigerant comprises ammonia.

7087. The method of claim 7070, wherein the refrigerant comprises an aqueous salt mixture.

7088. The method of claim 7070, wherein the refrigerant comprises an organic acid salt.

7089. The method of claim 7070, wherein the refrigerant comprises a salt of an organic acid.

7090. The method of claim 7070, wherein the refrigerant comprises an organic acid.

7091. The method of claim 7070, wherein the refrigerant has a freezing point of less than about minus 60 degrees Celsius.

7092. The method of claim 7070, wherein the refrigerant comprises calcium chloride.

7093. The method of claim 7070, wherein the refrigerant comprises lithium chloride.

7094. The method of claim 7070, wherein the refrigerant comprises liquid nitrogen.

7095. The method of claim 7070, wherein the refrigerant is provided at a temperature of less than about minus 50 degrees Celsius.

7096. The method of claim 7070, wherein the refrigerant comprises carbon dioxide.

7097. The method of claim 7070, wherein at least one of the plurality of barrier wells is located along strike of a hydrocarbon containing portion of the formation.

7098. The method of claim 7070, wherein at least one of the plurality of barrier wells is located along dip of a hydrocarbon containing portion of the formation.

7099. The method of claim 7070, wherein the one or more heaters are placed greater than about 5 m from a frozen barrier zone.

7100. The method of claim 7070, wherein at least one of the one or more heaters is positioned less than about 1.5 m from a frozen barrier zone.

7101. The method of claim 7070, wherein a distance between a center of at least one barrier well and a center of at least one adjacent barrier well is greater than about 2 m.

7102. The method of claim 7070, further comprising desorbing methane from the formation.

7103. The method of claim 7070, further comprising pyrolyzing at least some hydrocarbon containing material within the treatment area.

7104. The method of claim 7070, further comprising producing synthesis gas from at least a portion of the formation.

7105. The method of claim 7070, further comprising:

providing a solvent to the treatment area such that the solvent dissolves a component in the treatment area; and

removing the solvent from the treatment area, wherein the removed solvent comprises the component.

7106. The method of claim 7070, further comprising sequestering a compound in at least a portion of the treatment area.

7107. The method of claim 7070, further comprising thawing at least a portion of the frozen barrier zone;

and wherein material in a thawed barrier zone area is substantially unaltered by the application of heat.

7108. The method of claim 7070, wherein a location of the frozen barrier zone has been selected using a flow rate of groundwater and wherein the selected groundwater flow rate is less than about 50 m/day.

7109. The method of claim 7070, further comprising providing water to the frozen barrier zone.

7110. The method of claim 7070, further comprising positioning one or more monitoring wells outside the frozen barrier zone, and then providing a tracer to the treatment area, and then monitoring for movement of the tracer at the monitoring wells.

7111. The method of claim 7070, further comprising:

positioning one or more monitoring wells outside the frozen barrier zone;

then providing an acoustic pulse to the treatment area; and

then monitoring for the acoustic pulse at the monitoring wells.

7112. The method of claim 7070, wherein a fluid pressure within the treatment area can be controlled at fluid pressures different from a fluid pressure that exists in a surrounding portion of the formation.

7113. The method of claim 7070, wherein fluid pressure within an area at least partially bounded by the frozen barrier zone can be controlled higher than, or lower than, hydrostatic pressures that exist in a surrounding portion of the formation.

7114. The method of claim 7070, further comprising controlling compositions of fluids produced from the formation by controlling the fluid pressure within an area at least partially bounded by the frozen barrier zone.

7115. The method of claim 7070, wherein a portion of at least one of the plurality of barrier wells is positioned below a water table of the formation.

7116. A method of treating a hydrocarbon containing formation comprising:

providing a refrigerant to one or more barrier wells placed in a portion of the formation;

establishing a low temperature zone proximate a treatment area of the formation;

providing heat from one or more heaters to a treatment area of the formation;

allowing the heat to transfer from the treatment area to a selected section of the formation; and

producing fluids from the formation.

7117. The method of claim 7116, further comprising forming a frozen barrier zone within the low temperature zone, wherein the frozen barrier zone hydraulically isolates the treatment area from a surrounding portion of the formation.

7118. The method of claim 7116, further comprising forming a frozen barrier zone within the low temperature zone, and wherein fluid pressure within an area at least partially bounded by the frozen barrier zone can be controlled at different fluid pressures from the fluid pressures that exist outside of the frozen barrier zone.

7119. The method of claim 7116, further comprising forming a frozen barrier zone within the low temperature zone, and wherein fluid pressure within an area at least partially bounded by the frozen barrier zone can be controlled higher than, or lower than, hydrostatic pressures that exist outside of the frozen barrier zone.

7120. The method of claim 7116, further comprising forming a frozen barrier zone within the low temperature zone, and wherein fluid pressure within an area at least partially bounded by the frozen barrier zone can be controlled higher than, or lower than, hydrostatic pressures that exist outside of the frozen barrier zone, and further comprising controlling compositions of fluids produced from the formation by controlling the fluid pressure within the area at least partially bounded by the frozen barrier zone.

7121. The method of claim 7116, further comprising thawing at least a portion of the low temperature zone, wherein material within the thawed portion is substantially unaltered by the application of heat such that the structural integrity of the hydrocarbon containing formation is substantially maintained.

7122. The method of claim 7116, wherein an inner boundary of the low temperature zone is determined by monitoring a pressure wave using one or more piezometers.

7123. The method of claim 7116, further comprising controlling a fluid pressure within the treatment area at a pressure less than about a formation fracture pressure.

7124. The method of claim 7116, further comprising positioning one or more monitoring wells outside the frozen barrier zone, and then providing an acoustic pulse to the treatment area, and then monitoring for the acoustic pulse at the monitoring wells.

7125. The method of claim 7116, further comprising positioning a segment of at least one of the one or more barrier wells below a water table of the formation.

7126. The method of claim 7116, further comprising positioning the one or more barrier wells to establish a continuous low temperature zone.

7127. The method of claim 7116, wherein the refrigerant comprises one or more hydrocarbons.

7128. The method of claim 7116, wherein the refrigerant comprises propane.

7129. The method of claim 7116, wherein the refrigerant comprises isobutane.

7130. The method of claim 7116, wherein the refrigerant comprises cyclopentane.

7131. The method of claim 7116, wherein the refrigerant comprises ammonia.

7132. The method of claim 7116, wherein the refrigerant comprises an aqueous salt mixture.

7133. The method of claim 7116, wherein the refrigerant comprises an organic acid salt.

7134. The method of claim 7116, wherein the refrigerant comprises a salt of an organic acid.

7135. The method of claim 7116, wherein the refrigerant comprises an organic acid.

7136. The method of claim 7116, wherein the refrigerant has a freezing point of less than about minus 60 degrees Celsius.

7137. The method of claim 7116, wherein the refrigerant is provided at a temperature of less than about minus 50 degrees Celsius.

7138. The method of claim 7116, wherein the refrigerant is provided at a temperature of less than about minus 25 degrees Celsius.

7139. The method of claim 7116, wherein the refrigerant comprises carbon dioxide.

7140. The method of claim 7116, further comprising:

cooling at least a portion of the refrigerant in an absorption refrigeration unit; and

providing a thermal energy source to the absorption refrigeration unit.

7141. The method of claim 7116, wherein the thermal energy source comprises water.

7142. The method of claim 7116, wherein the thermal energy source comprises steam.

7143. The method of claim 7116, wherein the thermal energy source comprises at least a portion of the produced fluids.

7144. The method of claim 7116, wherein the thermal energy source comprises exhaust gas.

7145. A method of treating a hydrocarbon containing formation, comprising:

inhibiting migration of fluids into or out of a treatment area of the formation from a surrounding portion of the formation;

providing heat from one or more heaters to at least a portion of the treatment area;

allowing the heat to transfer from at least the portion to a selected section of the formation; and

producing fluids from the formation.

7146. The method of claim 7145, wherein the heat provided from at least one of the one or more heaters is transferred to at least a portion of the formation substantially by conduction.

7147. The method of claim 7145, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

7148. The method of claim 7145, further comprising providing a barrier to at least a portion of the formation.

7149. The method of claim 7148, wherein at least section of the barrier comprises one or more sulfur wells.

7150. The method of claim 7148, wherein at least section of the barrier comprises one or more pumping wells.

7151. The method of claim 7148, wherein at least section of the barrier comprises one or more injection wells and one or more pumping wells.

7152. The method of claim 7148, wherein at least a section of the barrier is naturally occurring.

7153. The method of claim 7145, further comprises establishing a barrier in at least a portion of the formation, and wherein heat is provided after at least a portion of the barrier has been established.

7154. The method of claim 7145, further comprising establishing a barrier in at least a portion of the formation, and wherein heat is provided while at least a portion of the barrier is being established.

7155. The method of claim 7145, further comprising providing a barrier to at least a portion of the formation, and wherein heat is provided before the barrier is established.

7156. The method of claim 7145, further comprising controlling an amount of fluid removed from the treatment area.

7157. The method of claim 7145, wherein isolating a treatment area from a surrounding portion of the formation comprises providing a low temperature zone to at least a portion of the formation.

7158. The method of claim 7145, wherein isolating a treatment area from a surrounding portion of the formation comprises providing a frozen barrier zone to at least a portion of the formation.

7159. The method of claim 7145, wherein isolating a treatment area from a surrounding portion of the formation comprises providing a grout wall.

7160. The method of claim 7145, further comprising inhibiting flow of water into or out of at least a portion of a treatment area.

7161. The method of claim 7145, further comprising:

providing a material to the treatment area; and

storing at least some of the material within the treatment area.

7162. A method of treating a hydrocarbon containing formation, comprising:

providing a barrier to a portion of the formation, wherein the portion has previously undergone an in situ conversion process; and

inhibiting migration of fluids into and out of the converted portion to a surrounding portion of the formation.

7163. The method of claim 7162, wherein the barrier comprises a frozen barrier zone.

7164. The method of claim 7162, wherein the barrier comprises a low temperature zone.

7165. The method of claim 7162, wherein the barrier comprises a sealing mineral phase.

7166. The method of claim 7162, wherein the barrier comprises a sulfur barrier.

7167. The method of claim 7162, wherein the contaminant comprises a metal.

7168. The method of claim 7162, wherein the contaminant comprises organic residue.

7169. A method of treating a hydrocarbon containing formation, comprising:

introducing a first fluid into at least a portion of the formation, wherein the portion has previously undergone an in situ conversion process;

producing a mixture of the first fluid and a second fluid from the formation; and

providing at least a portion of the mixture to an energy producing unit.

7170. The method of claim 7169, wherein the first fluid is selected to recover heat from the formation.

7171. The method of claim 7169, wherein the first fluid is selected to recover heavy compounds from the formation.

7172. The method of claim 7169, wherein the first fluid is selected to recover hydrocarbons from the formation.

7173. The method of claim 7169, wherein the mixture comprises an oxidizable heat recovery fluid.

7174. The method of claim 7169, wherein producing the mixture remediates the portion of the formation by removing contaminants from the formation in the mixture.

7175. The method of claim 7169, wherein the first fluid comprises a hydrocarbon fluid.

7176. The method of claim 7169, wherein the first fluid comprises methane.

7177. The method of claim 7169, wherein the first fluid comprises ethane.

7178. The method of claim 7169, wherein the first fluid comprises molecular hydrogen.

7179. The method of claim 7169, wherein the energy producing unit comprises a turbine, and generating electricity by passing mixture through the energy producing unit.

7180. The method of claim 7169, further comprising combusting mixture within the energy producing unit.

7181. The method of claim 7169, further comprising inhibiting spread of the mixture from the portion of the formation with a barrier.

7182. A method of treating a hydrocarbon containing formation, comprising:

providing a first fluid to at least a portion of a treatment area, wherein the treatment area includes one or more components;

producing a fluid from the formation wherein the produced fluid comprises first fluid and at least some of the one or more components; and

wherein the treatment area is obtained by providing heat from heaters to a portion of a hydrocarbon containing formation to convert a portion of hydrocarbons to desired products and removing a portion of the desired hydrocarbons from the formation.

7183. The method of claim 7182, wherein the first fluid comprises water.

7184. The method of claim 7182, wherein the first fluid comprises carbon dioxide.

7185. The method of claim 7182, wherein the first fluid comprises steam.

7186. The method of claim 7182, wherein the first fluid comprises air.

7187. The method of claim 7182, wherein the first fluid comprises a combustible gas.

7188. The method of claim 7182, wherein the first fluid comprises hydrocarbons.

7189. The method of claim 7182, wherein the first fluid comprises methane.

7190. The method of claim 7182, wherein the first fluid comprises ethane.

7191. The method of claim 7182, wherein the first fluid comprises molecular hydrogen.

7192. The method of claim 7182, wherein the first fluid comprises propane.

7193. The method of claim 7182, further comprising reacting a portion of the contaminants with the first fluid.

7194. The method of claim 7182, further comprising providing at least a portion of the produced fluid to an energy generating unit to generate electricity.

7195. The method of claim 7182, further comprising providing at least a portion of the produced fluid to a combustor.

7196. The method of claim 7182, wherein a frozen barrier defines at least a segment of a barrier within the formation, allowing a portion of the frozen barrier to thaw prior to providing the first fluid to the treatment area, and providing at least some of the first fluid into the thawed portion of the barrier.

7197. The method of claim 7182, wherein a volume of first fluid provided to the treatment area is greater than about one pore volume of the treatment area.

7198. The method of claim 7182, further comprising separating contaminants from the first fluid.

7199. A method of recovering thermal energy from a heated hydrocarbon containing formation, comprising:

injecting a heat recovery fluid into a heated portion of the formation;

allowing heat from the portion of the formation to transfer to the heat recovery fluid; and

producing fluids from the formation.

7200. The method of claim 7199, wherein the heat recovery fluid comprises water.

7201. The method of claim 7199, wherein the heat recovery fluid comprises saline water.

7202. The method of claim 7199, wherein the heat recovery fluid comprises non-potable water.

7203. The method of claim 7199, wherein the heat recovery fluid comprises alkaline water.

7204. The method of claim 7199, wherein the heat recovery fluid comprises hydrocarbons.

7205. The method of claim 7199, wherein the heat recovery fluid comprises an inert gas.

7206. The method of claim 7199, wherein the heat recovery fluid comprises carbon dioxide.

7207. The method of claim 7199, wherein the heat recovery fluid comprises a product stream produced by an in situ conversion process.

7208. The method of claim 7199, further comprising vaporizing at least some of the heat recovery fluid.

7209. The method of claim 7199, wherein an average temperature of the portion of the post treatment formation prior to injection of heat recovery fluid is greater than about 300°

C.

7210. The method of claim 7199, further comprising providing the heat recovery fluid to the formation through a heater well.

7211. The method of claim 7199, wherein fluids are produced from one or more production wells in the formation.

7212. The method of claim 7199, further comprising providing at least some of the produced fluids to a treatment process in a section of the formation.

7213. The method of claim 7199, further comprising recovering at least some of the heat from the produced fluids.

7214. The method of claim 7199, further comprising providing at least some of the produced fluids to a power generating unit.

7215. The method of claim 7199, further comprising providing at least some of the produced fluids to a heat exchange mechanism.

7216. The method of claim 7199, further comprising providing at least some of the produced fluids to a steam cracking unit.

7217. The method of claim 7199, further comprising providing at least some of the produced fluids to a hydrotreating unit.

7218. The method of claim 7199, further comprising providing at least some of the produced fluids to a distillation column.

7219. The method of claim 7199, wherein the heat recovery fluid comprises carbon dioxide, and wherein at least some of the carbon dioxide is adsorbed onto the surface of carbon in the formation.

7220. The method of claim 7199, wherein the heat recovery fluid comprises carbon dioxide, and further comprising:

allowing at least some hydrocarbons within the formation to desorb from the formation; and

producing at least some of the desorbed hydrocarbons from the formation.

7221. The method of claim 7199, further comprising providing at least some of the produced fluids to a treatment process in a section of the formation.

7222. The method of claim 7199, wherein the heat recovery fluid is saline water, and further comprising:

providing carbon dioxide to the portion of the formation; and

precipitating carbonate compounds.

7223. The method of claim 7199, further comprising reducing an average temperature of the formation to a temperature less than about an ambient boiling temperature of water at a post treatment pressure.

7224. The method of claim 7199, wherein the produced fluids comprise low molecular weight hydrocarbons.

7225. The method of claim 7199, wherein the produced fluids comprise hydrocarbons.

7226. The method of claim 7199, wherein the produced fluids comprise heat recovery fluid.

7227. A method of treating a hydrocarbon containing formation, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

controlling at least one condition within the selected section;

producing a mixture from the formation; and

wherein at least the one condition is controlled such that the mixture comprises a carbon dioxide emission level less than about a selected carbon dioxide emission level.

7228. The method of claim 7227, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7229. The method of claim 7227, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

7230. The method of claim 7227, wherein the selected carbon dioxide emission level is less than about 5.6×

10<sup>−

8</sup> kg CO₂ produced for every Joule of energy.

7231. The method of claim 7227, wherein the selected carbon dioxide emission level is less than about 1.6×

10<sup>−

8</sup> kg CO₂ produced for every Joule of energy.

7232. The method of claim 7227, wherein the selected carbon dioxide emission level is less than about 1.6×

10<sup>−

10</sup> kg CO₂ produced for every Joule of energy.

7233. The method of claim 7227, further comprising blending the mixture with a fluid to form a blended product comprising a carbon dioxide emission level less than about the selected baseline carbon dioxide emission level.

7234. The method of claim 7227, wherein controlling conditions within a selected section comprises controlling a pressure within the selected section.

7235. The method of claim 7227, wherein controlling conditions within a selected section comprises controlling an average temperature within the selected section.

7236. The method of claim 7227, wherein controlling conditions within a selected section comprises controlling an average heating rate within the selected section.

7237. A method for producing molecular hydrogen from a hydrocarbon containing formation, comprising:

providing heat from one or more heaters to at least one portion of the formation such that carbon dioxide production is minimized;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

producing a mixture comprising molecular hydrogen from the formation; and

controlling the heat from the one or more heaters to enhance production of molecular hydrogen.

7238. The method of claim 7237, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7239. The method of claim 7237, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

7240. The method of claim 7237, wherein controlling the heat comprises controlling a temperature proximate the production wellbore at or above a decomposition temperature of methane.

7241. The method of claim 7237, wherein heat is generated by oxidizing molecular hydrogen in at least one heater.

7242. The method of claim 7237, wherein heat is generated by electricity produced from wind power.

7243. The method of claim 7237, wherein heat is generated from electrical power.

7244. The method of claim 7237, wherein the heaters form an array of heaters.

7245. The method of claim 7237, further comprising heating at least a portion of the selected section of the formation to greater than about 600°

C.

7246. The method of claim 7237, wherein the produced mixture is produced from a production wellbore, and further comprising controlling the heat from one or more heaters such that the temperature in the formation proximate the production wellbore is at least about 600°

C.

7247. The method of claim 7237, wherein the produced mixture is produced from a production wellbore, and further comprising heating at least a portion of the formation with a heater proximate the production wellbore.

7248. The method of claim 7237, further comprising recycling at least a portion of the produced molecular hydrogen into the formation.

7249. The method of claim 7237, wherein the produced mixture comprises methane, and further comprising oxidizing at least a portion of the methane to provide heat to the formation.

7250. The method of claim 7237, wherein controlling the heat comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

7251. The method of claim 7237, wherein the one or more heaters comprise one or more electrical heaters powered by a fuel cell, and wherein at least a portion of the molecular hydrogen in the produced mixture is used in the fuel cell.

7252. The method of claim 7237, further comprising controlling a pressure within at least a majority of the selected section of the formation.

7253. The method of claim 7237, further comprising controlling the heat such that an average heating rate of the selected section is less than about 3°

C. per day during pyrolysis.

7254. The method of claim 7237, wherein allowing the heat to transfer from the one or more heaters to the selected section comprises transferring heat substantially by conduction.

7255. The method of claim 7237, wherein at least 50% by volume of the produced mixture comprises molecular hydrogen.

7256. The method of claim 7237, wherein less than about 3.3×

10<sup>−

8</sup> kg CO₂ is produced for every Joule of energy in the produced mixture.

7257. The method of claim 7237, wherein less than about 1.6×

10<sup>−

10</sup> kg CO₂ is produced for every Joule of energy in the produced mixture.

7258. The method of claim 7237, wherein less than about 3.3×

10<sup>−

10</sup> kg CO₂ is produced for every Joule of energy in the produced mixture.

7259. The method of claim 7237, wherein the produced mixture is produced from a production wellbore, and further comprising controlling the heat from one or more heaters such that the temperature in the formation proximate the production wellbore is at least about 500°

C.

7260. The method of claim 7237, wherein the produced mixture comprises methane and molecular hydrogen, and further comprising:

separating at least a portion of the molecular hydrogen from the produced mixture; and

providing at least a portion of the separated mixture to at least one of the one or more heaters for use as fuel.

7261. The method of claim 7237, wherein the produced mixture comprises methane and molecular hydrogen, and further comprising:

separating at least a portion of the molecular hydrogen from the produced mixture; and

providing at least some of the molecular hydrogen to a fuel cell to generate electricity.

7262. A method for producing methane from a hydrocarbon containing formation in situ while minimizing production of CO₂, comprising:

providing heat from one or more heaters to at least one portion of the formation such that CO₂ production is minimized;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

producing a mixture comprising methane from the formation; and

controlling the heat from the one or more heaters to enhance production of methane.

7263. The method of claim 7262, wherein the heat provided from at least one of the one or more heater is transferred to at least a portion of the formation substantially by conduction.

7264. The method of claim 7262, wherein controlling the heat comprises controlling a temperature proximate the production wellbore at or above a decomposition temperature of ethane.

7265. The method of claim 7262, wherein heat is generated by oxidizing methane in at least one heater.

7266. The method of claim 7262, wherein heat is generated by electricity produced from wind power.

7267. The method of claim 7262, wherein heat is generated from electrical power.

7268. The method of claim 7262, wherein the heaters form an array of heaters.

7269. The method of claim 7262, further comprising heating at least a portion of the selected section of the formation to greater than about 400°

C.

7270. The method of claim 7262, wherein the produced mixture is produced from a production wellbore, and further comprising controlling the heat from one or more heaters such that the temperature in the formation proximate the production wellbore is at least about 400°

C.

7271. The method of claim 7262, wherein the produced mixture is produced from a production wellbore, and further comprising heating at least a portion of the formation with a heater proximate the production wellbore.

7272. The method of claim 7262, further comprising recycling at least a portion of the produced methane into the formation.

7273. The method of claim 7262, wherein the produced mixture comprises methane, and further comprising oxidizing at least a portion of the methane to provide heat to the formation.

7274. The method of claim 7262, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

7275. The method of claim 7262, wherein controlling the heat comprises maintaining a temperature within the selected section within a pyrolysis temperature range.

7276. The method of claim 7262, wherein the one or more heaters comprise one or more electrical heaters powered by a fuel cell, and wherein at least a portion of the molecular hydrogen in the produced mixture is used in the fuel cell.

7277. The method of claim 7262, further comprising controlling a pressure within at least a majority of the selected section of the formation.

7278. The method of claim 7262, further comprising controlling the heat such that an average heating rate of the selected section is less than about 3°

C. per day during pyrolysis.

7279. The method of claim 7262, wherein allowing the heat to transfer from the one or more heaters to the selected section comprises transferring heat substantially by conduction.

7280. The method of claim 7262, wherein less than about 8.4×

10<sup>−

8</sup> kg CO₂ is produced for every Joule of energy in the produced mixture.

7281. The method of claim 7262, wherein less than about 7.4×

10<sup>−

8</sup> kg CO₂ is produced for every Joule of energy in the produced mixture.

7282. The method of claim 7262, wherein less than about 5.6×

10<sup>−

8</sup> kg CO₂ is produced for every Joule of energy in the produced mixture.

7283. A method for upgrading hydrocarbons in a hydrocarbon containing formation, comprising:

providing heat from one or more heaters to a portion of the formation;

allowing the heat to transfer from the first portion to a selected section of the formation;

providing hydrocarbons to the selected section; and

producing a mixture from the formation, wherein the mixture comprises hydrocarbons that were provided to the selected section and upgraded in the formation.

7284. The method of claim 7283, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

7285. The method of claim 7283, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7286. The method of claim 7283, wherein the provided hydrocarbons comprise heavy hydrocarbons.

7287. The method of claim 7283, wherein the provided hydrocarbons comprise naphtha.

7288. The method of claim 7283, wherein the provided hydrocarbons comprise asphaltenes.

7289. The method of claim 7283, wherein the provided hydrocarbons comprise crude oil.

7290. The method of claim 7283, wherein the provided hydrocarbons comprise surface mined tar from relatively permeable formations.

7291. The method of claim 7283, wherein the provided hydrocarbons comprise an emulsion produced from a relatively permeable formation, and further comprising providing the produced emulsion to the first portion after a temperature in the selected section is greater than about a pyrolysis temperature.

7292. The method of claim 7283, further comprising providing steam to the selected section.

7293. The method of claim 7283, further comprising:

producing formation fluids from the formation;

separating the produced formation fluids into one or more components; and

wherein the provided hydrocarbons comprise at least one of the one or more components.

7294. The method of claim 7283, further comprising:

providing steam to the selected section, wherein the provided hydrocarbons are mixed with the steam; and

controlling an amount of steam such that a residence time of the provided hydrocarbons within the selected section is controlled.

7295. The method of claim 7283, wherein the produced mixture comprises upgraded hydrocarbons, and further comprising controlling a residence time of the provided hydrocarbons within the selected section to control a molecular weight distribution within the upgraded hydrocarbons.

7296. The method of claim 7283, wherein the produced mixture comprises upgraded hydrocarbons, and further comprising controlling a residence time of the provided hydrocarbons in the selected section to control an API gravity of the upgraded hydrocarbons.

7297. The method of claim 7283, further comprising steam cracking in at least a portion of the selected section.

7298. The method of claim 7283, wherein the provided hydrocarbons are produced from a second portion of the formation.

7299. The method of claim 7283, further comprising allowing some of the provided hydrocarbons to crack in the formation to generate upgraded hydrocarbons.

7300. The method of claim 7283, further comprising controlling a temperature of the first portion of the formation by controlling a pressure and a temperature within at least a majority of the selected section of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

7301. The method of claim 7283, further comprising controlling a pressure within at least a majority of the selected section of the formation.

7302. The method of claim 7283, wherein a temperature in the first portion is greater than about a pyrolysis temperature.

7303. The method of claim 7283, further comprising:

controlling the heat such that a temperature of the first portion is greater than about a pyrolysis temperature of hydrocarbons; and

producing at least some of the provided hydrocarbons from the first portion of the formation.

7304. The method of claim 7283, further comprising producing at least some of the provided hydrocarbons from a second portion of the formation.

7305. The method of claim 7283, further comprising:

controlling the heat such that a temperature of a second portion is less than about a pyrolysis temperature of hydrocarbons; and

producing at least some of the provided hydrocarbons from the second portion of the formation.

7306. The method of claim 7283, further comprising producing at least some of the provided hydrocarbons from a second portion of the formation and wherein a temperature of the second portion is about an ambient temperature of the formation.

7307. The method of claim 7283, wherein the upgraded hydrocarbons are produced from a production well and wherein the heat is controlled such that the upgraded hydrocarbons can be produced from the formation as a vapor.

7308. A method for producing methane from a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing hydrocarbon fluids to at least the selected section of the formation; and

producing mixture comprising methane from the formation.

7309. The method of claim 7308, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7310. The method of claim 7308, further comprising controlling heat from at least one of the heaters to enhance production of methane from the hydrocarbon fluids.

7311. The method of claim 7308, further comprising controlling a temperature within at least a selected section in a range to from greater than about 400°

C. to less than about 600°

C.

7312. The method of claim 7308, further comprising cooling the mixture to inhibit further reaction of the methane.

7313. The method of claim 7308, further comprising controlling at least some condition in the formation to enhance production of methane.

7314. The method of claim 7308, further comprising adding water to the formation.

7315. The method of claim 7308, further comprising separating at least a portion of the methane from the mixture and recycling at least some of the separated mixture to the formation.

7316. The method of claim 7308, further comprising cracking the hydrocarbon fluids to form methane.

7317. The method of claim 7308, wherein the mixture is produced from the formation through a production well, and wherein the heat is controlled such that the mixture can be produced from the formation as a vapor.

7318. The method of claim 7308, wherein the mixture is produced from the formation through a production well, and further comprising heating a wellbore of the production well to inhibit condensation of the mixture within the wellbore.

7319. The method of claim 7308, wherein the mixture is produced from the formation through a production well, wherein a wellbore of the production well comprises a heater element configured to heat the formation adjacent to the wellbore, and further comprising heating the formation with the heater element to produce the mixture.

7320. A method for hydrotreating a fluid in a heated formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

providing a fluid to the selected section;

controlling a H₂ partial pressure in the selected section of the formation;

hydrotreating at least some of the fluid in the selected section; and

producing a mixture comprising hydrotreated fluids from the formation.

7321. The method of claim 7320, wherein the mixture is produced from the formation when a partial pressure of hydrogen in the selected section is at least about 0.5 bars absolute.

7322. The method of claim 7320, wherein the heat provided from at least one of the one or more heater is transferred to at least a portion of the formation substantially by conduction.

7323. The method of claim 7320, further comprising providing hydrogen to the selected section of the formation.

7324. The method of claim 7320, further comprising controlling the heat such that a temperature within the selected section is in a range from about 200°

C. to about 450°

C.

7325. The method of claim 7320, wherein the provided fluid comprises an olefin.

7326. The method of claim 7320, wherein the provided fluid comprises pitch.

7327. The method of claim 7320,wherein the provided fluid comprises oxygenated compounds.

7328. The method of claim 7320, wherein the provided fluid comprises sulfur containing compounds.

7329. The method of claim 7320, wherein the provided fluid comprises nitrogen containing compounds.

7330. The method of claim 7320, wherein the provided fluid comprises crude oil.

7331. The method of claim 7320, wherein the provided fluid comprises synthetic crude oil.

7332. The method of claim 7320, wherein the produced mixture comprises a hydrocarbon mixture.

7333. The method of claim 7320, wherein the produced mixture comprises less than about 1% by weight ammonia.

7334. The method of claim 7320, wherein the produced mixture comprises less than about 1% by weight hydrogen sulfide.

7335. The method of claim 7320, wherein the produced mixture comprises less than about 1% oxygenated compounds.

7336. The method of claim 7320, further comprising producing the mixture from the formation through a production well, wherein the heating is controlled such that the mixture can be produced from the formation as a vapor.

7337. A method for producing hydrocarbons from a heated formation in situ, comprising:

providing heat from one or more heaters to at least one portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that at least some of the selected section comprises a temperature profile;

providing a hydrocarbon mixture to the selected section;

separating the hydrocarbon mixture into one or more mixtures of components; and

producing the one or more mixtures of components from one or more production wells.

7338. The method of claim 7337, wherein the heat provided from at least one of the one or more heater is transferred to at least a portion of the formation substantially by conduction.

7339. The method of claim 7337, wherein the one or more of the heaters comprise heaters.

7340. The method of claim 7337, wherein at least one of the one or more mixtures is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

7341. The method of claim 7337, further comprising controlling a pressure within at least a majority of the selected section.

7342. The method of claim 7337, wherein the temperature profile extends horizontally through the formation.

7343. The method of claim 7337, wherein the temperature profile extends vertically through the formation.

7344. The method of claim 7337, wherein the selected section comprises a spent formation.

7345. The method of claim 7337, wherein the production well comprises a plurality of production wells placed at various distances from at least one of the one or more heaters along the temperature gradient zone.

7346. The method of claim 7337, wherein the production well comprises a first production well and a second production well, further comprising:

positioning the first production well at a first distance from a heater of the one or more heaters;

positioning the second production well at a second distance from the heater of the one or more heaters;

producing a first component of the one or more portions from the first production well; and

producing a second component of the one or more portions from the second production well.

7347. The method of claim 7337, further comprising heating a wellbore of the production well to inhibit condensation of at least the one component within the wellbore.

7348. The method of claim 7337, wherein the one or more components comprise hydrocarbons.

7349. The method of claim 7337, wherein separating the one or more components further comprises:

producing a low molecular weight component of the one or more components from the formation;

allowing a high molecular weight component of the one or more components to remain within the formation;

providing additional heat to the formation; and

producing at least some of the high molecular weight component.

7350. The method of claim 7337, further comprising producing at least the one component from the formation through a production well, wherein the heating is controlled such that the mixture can be produced from the formation as a vapor.

7351. A method of utilizing heat of a heated formation, comprising:

placing a conduit in the formation,;

allowing heat from the formation to transfer to at least a portion of the conduit;

generating a region of reaction in the conduit;

allowing a material to flow through the region of reaction;

reacting at least some of the material in the region of reaction; and

producing a mixture from the conduit.

7352. The method of claim 7351, wherein a conduit input is located separately from a conduit output

7353. The method of claim 7351, wherein the conduit is configured to inhibit contact between the material and the formation.

7354. The method of claim 7351, wherein the conduit comprises a u-shaped conduit, and further comprising placing the u-shaped conduit within a heater well in the heated formation.

7355. The method of claim 7351, wherein the material comprises a first hydrocarbon and wherein the first hydrocarbon reacts to form a second hydrocarbon.

7356. The method of claim 7351, wherein the material comprises water.

7357. The method of claim 7351, wherein the produced mixture comprises hydrocarbons.

7358. A method for storing fluids within a hydrocarbon containing formation, comprising:

providing a barrier to a portion of the formation to form an in situ storage area, wherein at least a portion of the in situ storage area has previously undergone an in situ conversion process, and wherein migration of fluids into or out of the storage area is inhibited;

providing a material to the in situ storage area;

storing at least some of the provided fluids within the in situ storage area; and

wherein one or more conditions of the in situ storage area inhibits reaction within the material.

7359. The method of claim 7358, further comprising producing at least some of the stored material from the in situ storage area.

7360. The method of claim 7358, further comprising producing at least some of the stored material from the in situ storage area as a liquid.

7361. The method of claim 7358, further comprising producing at least some of the stored material from the in situ storage area as a gas.

7362. The method of claim 7358, wherein the stored material is a solid, and further comprising:

providing a solvent to the in situ storage area;

allowing at least a portion of the stored material to dissolve; and

producing at least some of the dissolved material from the in situ storage area.

7363. The method of claim 7358, wherein the material comprises inorganic compounds.

7364. The method of claim 7358, wherein the material comprises organic compounds.

7365. The method of claim 7358, wherein the material comprises hydrocarbons.

7366. The method of claim 7358, wherein the material comprises formation fluids

7367. The method of claim 7358, wherein the material comprises synthesis gas.

7368. The method of claim 7358, wherein the material comprises a solid.

7369. The method of claim 7358, wherein the material comprises a liquid.

7370. The method of claim 7358, wherein the material comprises a gas.

7371. The method of claim 7358, wherein the material comprises natural gas.

7372. The method of claim 7358, wherein the material comprises compressed air.

7373. The method of claim 7358, wherein the material comprises compressed air, and wherein the compressed air is used as a supplement for electrical power generation.

7374. The method of claim 7358, further comprising:

producing at least some of the material from the in situ treatment area through a production well; and

heating at least a portion of a wellbore of the production well to inhibit condensation of the material within the wellbore.

7375. The method of claim 7358, wherein the in situ conversion process comprises pyrolysis.

7376. The method of claim 7358, wherein the in situ conversion process comprises synthesis gas generation.

7377. The method of claim 7358, wherein the in situ conversion process comprises solution mining.

7378. A method of filtering water within a hydrocarbon containing formation comprising:

providing water to at least a portion of the formation, wherein the portion has previously undergone an in situ conversion process, and wherein the water comprises one or more components;

removing at least one of the one or more components from the provided water; and

producing at least some of the water from the formation.

7379. The method of claim 7378, wherein at least one of the one or more components comprises a dissolved cation, and further comprising:

converting at least some of the provided water to steam;

allowing at least some of the dissolved cation to remain in the portion of the formation; and

producing at least a portion of the steam from the formation.

7380. The method of claim 7378, wherein the portion of the formation is above the boiling point temperature of the provided water at a pressure of the portion, wherein at least one of the one or more components comprises mineral cations, and wherein the provided water is converted to steam such that the mineral cations are deposited within the formation.

7381. The method of claim 7378, further comprising converting at least a portion of the provided water into steam and wherein at least one of the one or more components is separated from the water as the provided water is converted into steam.

7382. The method of claim 7378, wherein a temperature of the portion of the formation is greater than about 90°

C., and further comprising sterilizing at least some of the provided water within the portion of the formation.

7383. The method of claim 7378, wherein a temperature within the portion is less than about a boiling temperature of the provided water at a fluid pressure of the portion.

7384. The method of claim 7378, further comprising remediating at least the one portion of the formation.

7385. The method of claim 7378, wherein the one or more components comprise cations.

7386. The method of claim 7378, wherein the one or more components comprise calcium.

7387. The method of claim 7378, wherein the one or more components comprise magnesium.

7388. The method of claim 7378, wherein the one or more components comprise a microorganism.

7389. The method of claim 7378, wherein the converted portion of the formation further comprises a pore size such that at least one of the one or more components is removed from the provided water.

7390. The method of claim 7378, wherein the converted portion of the formation adsorbs at least one of the one or more components in the provided water.

7391. The method of claim 7378, wherein the provided water comprises formation water.

7392. The method of claim 7378, wherein the in situ conversion process comprises pyrolysis.

7393. The method of claim 7378, wherein the in situ conversion process comprises synthesis gas generation.

7394. The method of claim 7378, wherein the in situ conversion process comprises solution mining.

7395. A method for sequestering carbon dioxide in a hydrocarbon containing formation, comprising:

providing carbon dioxide to a portion of the formation, wherein the portion has previously undergone an in situ conversion process;

providing a fluid to the portion;

allowing at least some of the provided carbon dioxide to contact the fluid in the portion; and

precipitating carbonate compounds.

7396. The method of claim 7395, wherein providing a solution to the portion comprises allowing groundwater to flow into the portion.

7397. The method of claim 7395, wherein the solution comprises one or more dissolved ions.

7398. The method of claim 7395, wherein the solution comprises a solution obtained from a formation aquifer.

7399. The method of claim 7395, wherein the solution comprises a man-made industrial solution.

7400. The method of claim 7395, wherein the solution comprises agricultural run-off.

7401. The method of claim 7395, wherein the solution comprises seawater.

7402. The method of claim 7395, wherein the solution comprises a brine solution.

7403. The method of claim 7395, further comprising controlling a temperature within the portion.

7404. The method of claim 7395, further comprising controlling a pressure within the portion.

7405. The method of claim 7395, further comprising removing at least some of the solution from the formation.

7406. The method of claim 7395, further comprising removing at least some of the solution from the formation and recycling at least some of the removed solution into the formation.

7407. The method of claim 7395, further comprising providing a buffering compound to the solution.

7408. The method of claim 7395, further comprising:

providing the solution to the formation; and

allowing at least some of the solution to migrate through the formation to increase a contact time between the solution and the provided carbon dioxide.

7409. The method of claim 7395, wherein the solution is provided to the formation after carbon dioxide has been provided to the formation.

7410. The method of claim 7395, further comprising providing heat to the portion.

7411. The method of claim 7395, wherein providing carbon dioxide to a portion of the formation comprises providing carbon dioxide to a first location, wherein providing a solution to the portion comprises providing the solution to a second location, and wherein the first location is downdip of the second location.

7412. The method of claim 7395, wherein allowing at least some of the provided carbon dioxide to contact the solution in the portion comprises allowing at least some of the carbon dioxide and at least some of the solution to migrate past each other.

7413. The method of claim 7395, wherein the solution is provided to the formation prior to providing the carbon dioxide, and further comprising providing at least some of the carbon dioxide to a location positioned proximate a lower surface of the portion such that some of the carbon dioxide may migrate up through the portion.

7414. The method of claim 7395, wherein the solution is provided to the formation prior to providing the carbon dioxide, and further comprising allowing at least some carbon dioxide to migrate through the portion.

7415. The method of claim 7395, further comprising:

providing heat to the portion, wherein the portion comprises a temperature greater than about a boiling point of the solution;

vaporizing at least some of the solution;

producing a fluid from the formation.

7416. The method of claim 7395, further comprising decreasing leaching of metals from the formation into groundwater.

7417. A method of treating a hydrocarbon containing formation, comprising:

injecting a recovery fluid into a portion of the formation;

allowing heat within the recovery fluid, and heat from one or more heaters, to transfer to a selected section of the formation, wherein the selected section comprises hydrocarbons;

mobilizing at least some of the hydrocarbons within the selected section; and

producing a mixture from the formation.

7418. The method of claim 7417, wherein the portion has been previously produced.

7419. The method of claim 7417, wherein the portion has previously undergone an in situ conversion process.

7420. The method of claim 7417, further comprising upgrading at least some hydrocarbons within the selected section to decrease a viscosity of the hydrocarbons.

7421. The method of claim 7417, wherein the produced mixture comprises hydrocarbons having an average API gravity greater than about 25°

.

7422. The method of claim 7417, further comprising vaporizing at least some of the hydrocarbons within the selected section.

7423. The method of claim 7417, wherein the recovery fluid comprises water.

7424. The method of claim 7417, wherein the recovery fluid comprises hydrocarbons.

7425. The method of claim 7417, wherein the mixture comprises pyrolyzation fluids.

7426. The method of claim 7417, wherein the mixture comprises hydrocarbons.

7427. The method of claim 7417, wherein the mixture is produced from a production well and further comprising controlling a pressure such that a fluid pressure proximate to the production well is less than about a fluid pressure proximate to a location where the fluid is injected.

7428. The method of claim 7417, further comprising:

monitoring a composition of the produced mixture; and

controlling a fluid pressure in at least a portion of the formation to control the composition of the produced mixture.

7429. The method of claim 7417, further comprising pyrolyzing at least some of the hydrocarbons within the selected section of the formation.

7430. The method of claim 7417, wherein the formation comprises a heavy hydrocarbon containing formation.

7431. The method of claim 7417, wherein the formation comprises a bitumen formation.

7432. The method of claim 7417, wherein the formation comprises a relatively permeable formation.

7433. The method of claim 7417, wherein the formation comprises a coal formation.

7434. The method of claim 7417, wherein the formation comprises an oil shale formation.

7435. The method of claim 7417, wherein the formation comprises an oil containing formation.

7436. The method of claim 7417, wherein the average temperature of the selected section is between about 275°

C. to about 375°

C., and wherein a fluid pressure of the recovery fluid is between about 60 bars to about 220 bars, and wherein the recovery fluid comprises steam.

7437. The method of claim 7417, further comprising controlling pressure within the selected section such that a fluid pressure within the selected section is at least about a hydrostatic pressure of a surrounding portion of the formation.

7438. The method of claim 7417, further comprising controlling pressure within the selected section such that a fluid pressure within the selected section is greater than about a hydrostatic pressure of a surrounding portion of the formation.

7439. The method of claim 7417, wherein a depth of the selected section is between about 300 m to about 400 m.

7440. The method of claim 7417, wherein the mixture comprises pyrolysis products.

7441. The method of claim 7417, further comprising vaporizing at least some of the hydrocarbons within the selected section and wherein the vaporized hydrocarbons comprise hydrocarbons having a carbon number greater than about 1 and a carbon number less than about 4.

7442. The method of claim 7417, further comprising allowing the injected recovery fluid to contact a substantial portion of a volume of the selected section.

7443. The method of claim 7417, wherein the recovery fluid comprises steam, and wherein the pressure of the injected steam is at least about 90 bars, and wherein the temperature of the injected steam is at least about 300°

C.

7444. The method of claim 7417, further comprising upgrading at least a portion of the hydrocarbons within the selected section of the formation such that a viscosity of the portion of the hydrocarbons is decreased.

7445. The method of claim 7417, further comprising separating the recovery fluid from pyrolyzation fluid and distilled hydrocarbons in the formation, and further comprising producing the pyrolyzation fluid and distilled hydrocarbons.

7446. The method of claim 7417, wherein the transfer fluid and vaporized hydrocarbons are separated with membranes.

7447. The method of claim 7417, wherein the selected section comprises a first selected section and a second selected section and further comprising:

mobilizing at least some of the hydrocarbons within the selected first section of the formation;

allowing at least some of the mobilized hydrocarbons to flow from the selected first section of the formation to a selected second section of the formation, and wherein the selected second section comprises hydrocarbons; and

heating at least a portion of the formation using one or more heaters;

pyrolyzing at least some of the hydrocarbons within the selected second section of the formation; and

producing a mixture from the formation.

7448. The method of claim 7417, wherein a residence time of the recovery fluid in the formation is greater than about one month and less than about six months.

7449. The method of claim 7417, further comprising:

allowing the recovery fluid to soak in the selected section of the formation for a selected time period; and

producing at least a portion of the recovery fluid from the formation.

7450. A method of treating hydrocarbon containing formation in situ, comprising:

injecting a recovery fluid into the formation;

providing heat from one or more heaters to the formation;

allowing the heat to transfer from one or more of the heaters to a selected section of the formation, wherein the selected section comprises hydrocarbons;

mobilizing at least some of the hydrocarbons; and

producing a mixture from the formation, wherein the produced mixture comprises hydrocarbons having an average API gravity greater than about 25°

.

7451. The method of claim 7450, wherein the heat provided from at least one of the one or more heaters is transferred to at least a portion of the formation substantially by conduction.

7452. The method of claim 7450, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

7453. The method of claim 7450, further comprising pyrolyzing at least some of the hydrocarbons within selected section.

7454. The method of claim 7450, further comprising pyrolyzing at least some of the mobilized hydrocarbons.

7455. The method of claim 7450, wherein the recovery fluid comprises water.

7456. The method of claim 7450, wherein the recovery fluid comprises hydrocarbons.

7457. The method of claim 7450, wherein the mixture comprises pyrolyzation fluids.

7458. The method of claim 7450, wherein the mixture comprises steam.

7459. The method of claim 7450, wherein a pressure is controlled such that a fluid pressure proximate to one or more of the heaters is greater than a fluid pressure proximate to a location where the fluid is produced.

7460. The method of claim 7450, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the selected section of the formation.

7461. The method of claim 7450, wherein the heat is provided such that an average temperature in the selected section ranges from approximately about 270°

C. to about 375°

C.

7462. The method of claim 7450, further comprising:

monitoring a composition of the produced mixture; and

controlling a pressure in at least a portion of the formation to control the composition of the produced mixture.

7463. The method of claim 7462, wherein the pressure is controlled by a valve proximate to a location where the mixture is produced.

7464. The method of claim 7462, wherein the pressure is controlled such that pressure proximate to one or more of the heaters is greater than a pressure proximate to a location where the mixture is produced.

7465. The method of claim 7450, wherein a residence time of the recovery fluid in the formation is less than about one month to greater than about six months.

7466. The method of claim 7450, further comprising:

allowing the recovery fluid to soak in the selected section of the formation for a selected time period; and

producing at least a portion of the recovery fluid from the formation.

7467. A method of treating a hydrocarbon containing formation in situ, comprising:

injecting a recovery fluid into a formation;

allowing the recovery fluid to migrate through at least a portion of the formation, wherein a size of a selected section increases as a recovery fluid front migrates through an untreated portion of the formation, and wherein the selected section is a portion of the formation treated by the recovery fluid;

allowing heat from the recovery fluid to transfer heat to the selected section, wherein the heat from the recovery fluid, and heat from one or more heaters, pyrolyzes at least some of the hydrocarbons within the selected section of the formation;

allowing the heat from the recovery fluid or one or more heaters to mobilize at least some of the hydrocarbons at the recovery fluid front;

allowing the heat from the recovery fluid, and heat from one or more heaters, to pyrolyze at least a portion of the hydrocarbons in the mobilized fluid; and

producing a mixture from the formation.

7468. The method of claim 7467, wherein the formation comprises a heavy hydrocarbon containing formation.

7469. The method of claim 7467, wherein one or more heaters are heaters.

7470. The method of claim 7467, wherein the mixture is produced as a mixture of vapors.

7471. The method of claim 7467, wherein the formation comprises a bitumen formation.

7472. The method of claim 7467, wherein the formation comprises a relatively permeable formation.

7473. The method of claim 7467, wherein the formation comprises a coal formation.

7474. The method of claim 7467, wherein the formation comprises an oil shale formation.

7475. The method of claim 7467, wherein an average temperature of the selected section is about 300°

C., and wherein the recovery fluid pressure is about 90 bars.

7476. The method of claim 7467, wherein the mobilized hydrocarbons flow substantially parallel to the recovery fluid front.

7477. The method of claim 7467, wherein the mixture is produced from an upper portion of the formation.

7478. The method of claim 7467, wherein a portion of the recovery fluid condenses and migrates due to gravity to a lower portion of the selected section, and further comprising producing a portion of the condensed recovery fluid.

7479. The method of claim 7467, wherein the pyrolyzed fluid migrates to an upper portion of the formation.

7480. The method of claim 7467, wherein the mixture comprises pyrolyzation fluids.

7481. The method of claim 7467, wherein the mixture comprises recovery fluid.

7482. The method of claim 7467, wherein the recovery fluid comprises steam.

7483. The method of claim 7467, wherein the recovery fluid is injected through one or more injection wells.

7484. The method of claim 7483, wherein the one or more injection wells are located substantially horizontally in the formation.

7485. The method of claim 7483, wherein the one or more injection wells are located substantially vertically in the formation.

7486. The method of claim 7467, wherein the mixture is produced through one or more production wells.

7487. The method of claim 7486, wherein the one or more production wells are located substantially horizontally in the formation.

7488. The method of claim 7467, wherein the mixture is produced through a heater wellbore.

7489. The method of claim 7467, wherein the produced mixture comprises hydrocarbons having an average API gravity at least about 25°

.

7490. The method of claim 7467, wherein at least about 20% of the hydrocarbons in the selected first section and the selected second section are pyrolyzed.

7491. The method of claim 7467, further comprising providing heat from one or more heaters to at least one portion of the formation.

7492. The method of claim 7467, wherein the heat from the one or more heaters vaporizes water injected into the formation.

7493. The method of claim 7467, wherein the heat from the one or more heaters heats recovery fluid in the formation, wherein the recovery fluid comprises steam.

7494. The method of claim 7467, wherein the one or more heaters comprise electrical heaters.

7495. The method of claim 7467, wherein the one or more heaters comprise flame distributed combustors.

7496. The method of claim 7467, wherein the one or more heaters comprise natural distributed combustors.

7497. The method of claim 7467, further comprising separating recovery fluid from pyrolyzation fluids in the formation.

7498. The method of claim 7467, further comprising producing liquid hydrocarbons from the formation, and further comprising reinjecting the produced liquid hydrocarbons into the formation.

7499. The method of claim 7467, further comprising producing a liquid mixture from the formation, wherein the produced liquid mixture comprises substantially of condensed recovery fluid.

7500. The method of claim 7467, further comprising separating condensed recovery fluid from liquid hydrocarbons in the formation, and further comprising producing the condensed recovery fluid from the formation.

7501. The method of claim 7467, wherein the recovery fluid is injected into regions of relatively high water saturation.

7502. The method of claim 7467, wherein injected recovery fluid contacts a substantial portion of a volume of the selected section.

7503. The method of claim 7467, wherein the recovery fluid comprises steam, and wherein the pressure of the injected steam is at least about 90 bars, and wherein the temperature of the injected steam is at least about 300°

C.

7504. The method of claim 7467, wherein at least a portion of sulfur is retained in the formation.

7505. The method of claim 7467, wherein the heat from recovery fluid partially upgrades at least a portion of the hydrocarbons within the selected section of the formation, and wherein the partial upgrading reduces the viscosity of the portion of the hydrocarbons.

7506. The method of claim 7467, further comprising separating the recovery fluid from pyrolyzation fluid and distilled hydrocarbons in the formation, and further comprising producing the pyrolyzation fluid and distilled hydrocarbons.

7507. The method of claim 7467, wherein the recovery fluid and vaporized hydrocarbons are separated with membranes.

7508. The method of claim 7467, wherein a residence time of the recovery fluid in the formation is less than about one month to greater than about six months.

7509. The method of claim 7467, further comprising:

allowing the heat transfer fluid to soak in the selected section of the formation for a selected time period; and

producing at least a portion of the heat transfer fluid from the formation.

7510. A method of recovering methane from a hydrocarbon containing formation, comprising:

providing heat from one or more heaters to at least one portion of the formation, wherein the portion comprises methane;

allowing the heat to transfer from the one or more heaters to a selected section of the formation; and

producing fluids from the formation, wherein the produced fluids comprise methane.

7511. The method of claim 7510, further comprising providing a barrier to at least a segment of the formation.

7512. The method of claim 7510, further comprising:

providing a refrigerant to a plurality of barrier wells to form a low temperature zone around the portion of the formation;

lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water; and

removing water from the portion of the formation.

7513. The method of claim 7510, wherein an average temperature of the selected section is less than about 100°

C.

7514. The method of claim 7510, wherein an average temperature of the selected section is less than about a boiling point of water at an ambient pressure in the formation.

7515. The method of claim 7510, wherein an amount of methane produced from the formation is in a range from about 1 m³ of methane per ton of formation to about 30 m³ of methane per ton of formation.

7516. The method of claim 7510, wherein the methane produced from the formation is used as fuel for an in situ treatment of a hydrocarbon containing formation.

7517. The method of claim 7510, wherein the methane produced from the formation is used to generate power for electrical heater wells.

7518. The method of claim 7510, wherein the methane produced from the formation is used as fuel for gas fired heater wells.

7519. The method of claim 7510, further comprising providing carbon dioxide to the treatment area and allowing at least a portion of the methane to desorb.

7520. The method of claim 7510, wherein the hydrocarbon containing formation comprises a coal containing formation.

7521. The method of claim 7510, wherein the hydrocarbon containing formation comprises an oil shale containing formation.

7522. The method of claim 7510, wherein the fluids are produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

7523. The method of claim 7510, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7524. The method of claim 7510, wherein the one or more of the heaters comprise heaters.

7525. A method of recovering methane from a hydrocarbon containing formation, comprising:

providing a barrier to a portion of the formation, wherein the portion comprises methane;

removing the water from the portion; and

producing fluids from the formation, wherein the produced fluids comprise methane.

7526. The method of claim 7525, wherein the hydrocarbon containing formation comprises a coal containing formation.

7527. The method of claim 7525, wherein the hydrocarbon containing formation comprises an oil shale containing formation.

7528. The method of claim 7525, wherein removing water from the portion comprises pumping at least some water from the formation.

7529. The method of claim 7525, wherein the barrier inhibits migration of fluids into or out of a treatment area of the formation.

7530. The method of claim 7525, further comprising decreasing a fluid pressure within the portion and allowing at least some of the methane to desorb.

7531. The method of claim 7525, further comprising providing carbon dioxide to the portion and allowing at least some of the methane to desorb.

7532. The method of claim 7525, wherein providing a barrier comprises:

providing refrigerant to a plurality of freeze wells to form a low temperature zone around the portion; and

lowering a temperature within the low temperature zone to a temperature less than about a freezing temperature of water.

7533. The method of claim 7525, wherein providing a barrier comprises providing refrigerant to a plurality of freeze wells to form a frozen barrier zone and wherein the frozen barrier zone hydraulically isolates the treatment area from a surrounding portion of the formation.

7534. The method of claim 7525, further comprising:

providing heat from one or more heaters to at least one portion of the formation; and

allowing the heat to transfer from the one or more heaters to a selected section of the formation.

7535. The method of claim 7525, wherein an average temperature of the selected section is less than about 100°

C.

7536. The method of claim 7525, wherein an average temperature of the selected section is less than about a boiling point of water at an ambient pressure in the formation.

7537. A method of shutting-in an in situ treatment process in a hydrocarbon containing formation, comprising:

terminating heating from one or more heaters providing heat to a portion of the formation;

monitoring a pressure in at least a portion of the formation;

controlling the pressure in the portion of the formation such that the pressure is maintained approximately below a fracturing or breakthrough pressure of the formation.

7538. The method of claim 7537, wherein monitoring the pressure in the formation comprises detecting fractures with passive acoustic monitoring.

7539. The method of claim 7537, wherein controlling the pressure in the portion of the formation comprises:

producing hydrocarbon vapor from the formation when the pressure is greater than approximately the fracturing or breakthrough pressure of the formation; and

allowing produced hydrocarbon vapor to oxidize at a surface of the formation.

7540. The method of claim 7537, wherein controlling the pressure in the portion of the formation comprises:

producing hydrocarbon vapor from the formation when the pressure is greater than approximately the fracturing or breakthrough pressure of the formation; and

storing at least a portion of the produced hydrocarbon vapor.

7541. A method of shutting-in an in situ treatment process in a hydrocarbon containing formation, comprising:

terminating heating from one or more heaters providing heat to a portion of the formation;

producing hydrocarbon vapor from the formation; and

injecting at least a portion of the produced hydrocarbon vapor into a portion of a storage formation.

7542. The method of claim 7541, wherein the storage formation comprises a spent formation.

7543. The method of claim 7542, wherein an average temperature of the portion of the spent formation is less than about 100°

C.

7544. The method of claim 7542, wherein a substantial portion of condensable compounds in the injected hydrocarbon vapor condense in the spent formation.

7545. The method of claim 7541, wherein the storage formation comprises a relatively high temperature formation, and further comprising converting a substantial portion of injected hydrocarbons into coke and molecular hydrogen.

7546. The method of claim 7545, wherein the average temperature of the portion of the relatively high temperature formation is greater than about 300°

C.

7547. The method of claim 7545, further comprising:

producing at least a portion of the H₂ from the relatively high temperature formation; and

allowing the produced molecular hydrogen to oxidize at a surface of the relatively high temperature formation.

7548. The method of claim 7541, wherein the storage formation comprises a depleted formation.

7549. The method of claim 7548, wherein the depleted formation comprises an oil field.

7550. The method of claim 7548, wherein the depleted formation comprises a gas field.

7551. The method of claim 7548, wherein the depleted formation comprises a water zone comprising seal and trap integrity.

7552. A method of mining coal from a coal containing formation, comprising:

mining coal from at least a portion of the treated formation, wherein the treated formation is obtained by;

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from at least one or more heaters to a selected section of the formation; and

producing fluids from the formation.

7553. The method of claim 7552, wherein mining the coal comprises providing a fluid to the portion to remove at least some coal.

7554. The method of claim 7552, wherein the mined coal comprises anthracite.

7555. The method of claim 7552, wherein mining the coal comprises mining the coal as a powder.

7556. The method of claim 7552, wherein mining the coal comprises mining the coal as a slurry.

7557. The method of claim 7552, wherein the coal, before treatment, did not comprise a substantial quantity of anthracite, and the mined coal comprises a substantial quantity of anthracite.

7558. The method of claim 7552, wherein at least some of the mined coal comprises a carbon content of greater than about 87 weight %.

7559. The method of claim 7552, wherein at least some of the mined coal comprises a volatile matter content of less than about 5 weight %

7560. The method of claim 7552, wherein at least some of the mined coal comprises a heating value greater than about 25,000 kJ/kg.

7561. The method of claim 7552, wherein at least some of the mined coal comprises a vitrinite reflectance of greater than about 2.9%.

7562. The method of claim 7552, wherein at least some hydrocarbons in the coal have been pyrolyzed.

7563. A method for treating a kerogen and liquid hydrocarbon containing formation, comprising:

providing heat from one or more heaters to at least one portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation;

mobilizing at least a portion of the liquid hydrocarbons in the selected section;

pyrolyzing at least a portion of the kerogen in the selected section; and

producing a mixture from the formation.

7564. The method of claim 7563, further comprising increasing a permeability of the selected section.

7565. The method of claim 7563, further comprising increasing a permeability at least a portion of the formation, wherein at least some of the liquid hydrocarbons in the selected section are mobilized due to the increase in the permeability in at least a portion the formation.

7566. The method of claim 7563, further comprising:

vaporizing at least a portion of aqueous fluids in the selected section; and

increasing a permeability of the selected section.

7567. The method of claim 7563, further comprising allowing thermal fractures to form in the formation, wherein the thermal fractures increase the permeability of the selected section.

7568. The method of claim 7563, further comprising pyrolyzing at least a portion of the mobilized liquid hydrocarbons in the selected section of the formation.

7569. The method of claim 7563, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least two heaters pyrolyzes at least some kerogen within the selected section of the formation.

7570. The method of claim 7563, wherein an average spacing between the one or more heaters is greater than about 20 m.

7571. The method of claim 7563, wherein the mixture is produced through one or more production wells, and wherein an average spacing between the one or more production wells is greater than about 60 m.

7572. The method of claim 7563, wherein the mixture is produced through one or more production wells, and wherein an average spacing between production wells is greater than about 80 m.

7573. The method of claim 7563, wherein the one or more heaters are placed horizontally within the formation.

7574. The method of claim 7563, wherein the mixture is produced through one or more production wells, wherein the one or more production wells are placed horizontally within the formation.

7575. The method of claim 7563, wherein the one or more heaters comprise a length of at least about 1000 m.

7576. The method of claim 7563, wherein the mixture is produced through one or more production wells, and wherein the one or more production wells are placed vertically within the formation.

7577. The method of claim 7563, wherein at least a portion of the mixture produced from the formation comprises CO₂, and wherein the produced CO₂ is used for enhanced oil recovery.

7578. The method of claim 7563, wherein the liquid hydrocarbons have an API gravity of at least about 28°

.

7579. The method of claim 7563, wherein the liquid hydrocarbons have an API gravity between about 10°

and about 20°

.

7580. The method of claim 7563, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

7581. The method of claim 7563, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7582. The method of claim 7563, wherein the one or more of the heaters comprise heaters.

7583. A method of producing a soluble compound from a soluble compound containing formation, comprising:

providing heat from one or more heaters to at least a portion of a hydrocarbon containing layer;

producing a mixture comprising hydrocarbons from the formation;

using heat from the formation, heat from the mixture produced from the formation, or a component from the mixture produced from the formation to adjust a quality of a first fluid;

providing the first fluid to a soluble compound containing formation; and

producing a second fluid comprising a soluble compound from the soluble compound containing formation.

7584. The method of claim 7583, further comprising pyrolyzing at least some hydrocarbons in the hydrocarbon containing layer.

7585. The method of claim 7583, further comprising dissolving the soluble compound in the soluble compound containing formation.

7586. The method of claim 7583, wherein the soluble compound comprises a phosphate.

7587. The method of claim 7583, wherein the soluble compound comprises alumina.

7588. The method of claim 7583, wherein the soluble compound comprises a metal.

7589. The method of claim 7583, wherein the soluble compound comprises a carbonate.

7590. The method of claim 7583, further comprising separating at least a portion of the soluble compound from the second fluid.

7591. The method of claim 7583, further comprising separating at least a portion of the soluble compound from the second fluid, and then recycling a portion of the second fluid into the soluble compound containing formation.

7592. The method of claim 7583, wherein heat is provided from the heated formation, or from the mixture produced from the formation, in the form of hot water or steam.

7593. The method of claim 7583, wherein the quality of the first fluid that is adjusted is pH.

7594. The method of claim 7583, wherein the quality of the first fluid that is adjusted is temperature.

7595. The method of claim 7583, further comprising adding a dissolving compound to the first fluid that facilitates dissolution of the soluble compound in the soluble containing formation.

7596. The method of claim 7583, wherein CO₂ produced from the hydrocarbon containing layer is used to adjust acidity of the solution.

7597. The method of claim 7583, wherein the soluble compound containing formation is at a different depth than the portion of the hydrocarbon containing layer.

7598. The method of claim 7583, wherein heat from the portion of the hydrocarbon containing layer migrates and heats at least a portion of the soluble compound containing formation.

7599. The method of claim 7583, wherein the soluble compound containing formation is at a different location than the portion of the hydrocarbon containing layer.

7600. The method of claim 7583, further comprising using openings for providing the heaters, and further comprising using at least a portion of these openings to provide the first fluid to the soluble compound containing formation.

7601. The method of claim 7583, further comprising providing the solution to the soluble compound containing formation in one or more openings that were previously used to (a) provide heat to the hydrocarbon containing layer, or (b) produce the mixture from the hydrocarbon containing layer.

7602. The method of claim 7583, further comprising providing heat to the hydrocarbon containing layer, or producing the mixture from the hydrocarbon containing layer, using one or more openings that were previously used to provide a solution to a soluble compound containing formation.

7603. The method of claim 7583, further comprising:

separating at least a portion of the soluble compound from the second fluid;

providing heat to at least the portion of the soluble compound; and

wherein the provided heat is generated in part using one or more products of an in situ conversion process.

7604. The method of claim 7583, further comprising producing the second fluid when a partial pressure of hydrogen in the portion of the hydrocarbon containing layer is at least about 0.5 bars absolute.

7605. The method of claim 7583, wherein the heat provided from at least one heater is transferred to at least a part of the hydrocarbon containing layer substantially by conduction.

7606. The method of claim 7583, wherein one or more of the heaters comprise heaters.

7607. The method of claim 7583, wherein the soluble compound containing formation comprises nahcolite.

7608. The method of claim 7583, wherein greater than about 10% by weight of the soluble compound containing formation comprises nahcolite.

7609. The method of claim 7583, wherein the soluble compound containing formation comprises dawsonite.

7610. The method of claim 7583, wherein greater than about 2% by weight of the soluble compound containing formation comprises dawsonite.

7611. The method of claim 7583, wherein the first fluid comprises steam.

7612. The method of claim 7583, wherein the first fluid comprises steam, and further comprising providing heat to the soluble compound containing formation by injecting the steam into the formation.

7613. The method of claim 7583, wherein the hydrocarbon containing layer comprises oil shale.

7614. The method of claim 7583, wherein the soluble compound containing formation is heated and then the first fluid is provided to the formation.

7615. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat to at least a portion of the formation;

allowing the heat to transfer from at least the portion to a selected section of the formation such that dissociation of carbonate minerals is inhibited;

injecting a first fluid into the selected section;

producing a second fluid from the formation; and

conducting an in situ conversion process in the selected section.

7616. The method of claim 7615, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

7617. The method of claim 7615, wherein the heat is provided from at least one heater, and wherein the heat is transferred to at least the portion of the formation substantially by conduction.

7618. The method of claim 7615, wherein the in situ conversion process comprises:

providing additional heat to a least a portion of the formation;

pyrolyzing at least some hydrocarbons in the portion; and

producing a mixture from the formation.

7619. The method of claim 7615, wherein the selected section comprises nahcolite.

7620. The method of claim 7615, wherein the selected section comprises dawsonite.

7621. The method of claim 7615, wherein the selected section comprises trona.

7622. The method of claim 7615, wherein the selected section comprises gaylussite.

7623. The method of claim 7615, wherein the selected section comprises carbonates.

7624. The method of claim 7615, wherein the selected section comprises carbonate phosphates.

7625. The method of claim 7615, wherein the selected section comprises carbonate chlorides.

7626. The method of claim 7615, wherein the selected section comprises silicates.

7627. The method of claim 7615, wherein the selected section comprises borosilicates.

7628. The method of claim 7615, wherein the selected section comprises halides.

7629. The method of claim 7615, wherein the first fluid comprises a pH greater than about 7.

7630. The method of claim 7615, wherein the first fluid comprises a temperature less than about 110°

C.

7631. The method of claim 7615, wherein the portion has previously undergone an in situ conversion process prior to the injection of the first fluid.

7632. The method of claim 7615, wherein the second fluid comprises hydrocarbons.

7633. The method of claim 7615, wherein the second fluid comprises hydrocarbons, and further comprising:

fragmenting at least some of the portion prior to providing the first fluid;

generating hydrocarbons; and

providing at least some of the second fluid to a surface treatment unit, wherein the second fluid comprises at least some of the generated hydrocarbons.

7634. The method of claim 7615, further comprising removing mass from the selected section in the second fluid.

7635. The method of claim 7615, further comprising removing mass from the selected section in the second fluid such that a permeability of the selected section increases.

7636. The method of claim 7615, further comprising removing mass from the selected section in the second fluid and decreasing a heat transfer time in the selected section.

7637. The method of claim 7615, further comprising controlling the heat such that the selected section has a temperature of above about 120°

C.

7638. The method of claim 7615, wherein the selected section comprises nahcolite, and further comprising controlling the heat such that the selected section has a temperature less than about a dissociation temperature of nahcolite.

7639. The method of claim 7615, wherein the second fluid comprises soda ash, and further comprising removing at least a portion of the soda ash from the second fluid as sodium carbonate.

7640. The method of claim 7615, wherein the in situ conversion process comprises pyrolyzing hydrocarbon containing material in the selected section.

7641. The method of claim 7615, wherein the second fluid comprises nahcolite, and further comprising:

separating at least a portion of the nahcolite from the second fluid;

providing heat to at least some of the separated nahcolite to form a sodium carbonate solution;

providing at least some of the sodium carbonate solution to at least the portion of the formation; and

producing a third fluid comprising alumina from the formation.

7642. The method of claim 7615, further comprising providing a barrier to at least the portion of the formation to inhibit migration of fluids into or out of the portion.

7643. The method of claim 7615, further comprising controlling the heat such that a temperature within the selected section of the portion is less than about 100°

C.

7644. The method of claim 7615, further comprising:

providing additional heat from the one or more heaters to at least the portion of the formation;

allowing the additional heat to transfer from at least the portion to the selected section of the formation;

pyrolyzing at least some hydrocarbons within the selected section of the formation;

producing a mixture from the formation;

reducing a temperature of the selected section of the formation

injecting a third fluid into the selected section; and

producing a fourth fluid from the formation.

7645. The method of claim 7644, wherein the third fluid comprises water.

7646. The method of claim 7644, wherein the third fluid comprises steam.

7647. The method of claim 7644, wherein the fourth fluid comprises a metal.

7648. The method of claim 7644, wherein the fourth fluid comprises a mineral.

7649. The method of claim 7644, wherein the fourth fluid comprises aluminum.

7650. The method of claim 7644, wherein the fourth fluid comprises a metal, and further comprising producing the metal from the second fluid.

7651. The method of claim 7644, further comprising producing a non-hydrocarbon material from the fourth fluid.

7652. The method of claim 7615, wherein the first fluid comprises steam.

7653. The method of claim 7615, wherein the second fluid comprises a metal.

7654. The method of claim 7615, wherein the second fluid comprises a mineral.

7655. The method of claim 7615, wherein the second fluid comprises aluminum.

7656. The method of claim 7615, wherein the second fluid comprises a metal, and further comprising separating the metal from the second fluid.

7657. The method of claim 7615, further comprising producing a non-hydrocarbon material from the second fluid.

7658. The method of claim 7615, wherein greater than about 10% by weight of the selected section comprises nahcolite.

7659. The method of claim 7615, wherein greater than about 2% by weight of the selected section comprises dawsonite.

7660. The method of claim 7615, wherein the provided heat comprises waste heat from another portion of the formation.

7661. The method of claim 7615, wherein the first fluid comprises steam, and further comprising providing heat to the formation by injecting the steam into the formation.

7662. The method of claim 7615, further comprising providing heat to the formation by injecting the -first fluid into the formation.

7663. The method of claim 7615, further comprising providing heat to the-formation by injecting the first fluid into the formation, wherein the first fluid is at a temperature above about 90°

C.

7664. The method of claim 7615, further comprising controlling a temperature of the selected section while injecting the first fluid, wherein the temperature is less than about a temperature at which nahcolite will dissociate.

7665. The method of claim 7615, wherein a temperature within the selected section is less than about 90°

C. prior to injecting the first fluid to the formation.

7666. The method of claim 7615, wherein the hydrocarbon containing formation comprises oil shale.

7667. The method of claim 7615, further comprising providing a barrier substantially surrounding the selected section such that the barrier inhibits the flow of water into the formation.

7668. A method of treating a hydrocarbon containing formation in situ, comprising:

injecting a first fluid into the selected section;

producing a second fluid from the formation;

providing heat from one or more heaters to at least a portion of the formation, wherein the heat is provided after production of the second fluid has begun;

allowing the heat to transfer from at least a portion of the formation;

pyrolyzing at least some hydrocarbons within the selected section; and

producing a mixture from the formation.

7669. The method of claim 7668, wherein the selected section comprises nahcolite.

7670. The method of claim 7668, wherein the selected section comprises dawsonite.

7671. The method of claim 7668, wherein the selected section comprises trona.

7672. The method of claim 7668, wherein the selected section comprises gaylussite.

7673. The method of claim 7668, wherein the selected section comprises carbonates.

7674. The method of claim 7668, wherein the selected section comprises carbonate phosphates.

7675. The method of claim 7668, wherein the selected section comprises carbonate chlorides.

7676. The method of claim 7668, wherein the selected section comprises silicates.

7677. The method of claim 7668, wherein the selected section comprises borosilicates.

7678. The method of claim 7668, wherein the selected section comprises halides.

7679. The method of claim 7668, wherein the first fluid comprises a pH greater than about 7.

7680. The method of claim 7668, wherein the first fluid comprises a temperature less than about 110°

C.

7681. The method of claim 7668, wherein the second fluid comprises hydrocarbons.

7682. The method of claim 7668, wherein the second fluid comprises hydrocarbons, and further comprising:

fragmenting at least some of the portion prior to providing the first fluid;

generating hydrocarbons; and

providing at least some of the second fluid to a surface treatment unit, wherein the second fluid comprises at least some of the generated hydrocarbons.

7683. The method of claim 7668, further comprising removing mass from the selected section in the second fluid.

7684. The method of claim 7668, further comprising removing mass from the selected section in the second fluid such that a permeability of the selected section increases.

7685. The method of claim 7668, further comprising removing mass from the selected section in the second fluid and decreasing a heat transfer time in the selected section.

7686. The method of claim 7668, further comprising controlling the heat such that the selected section has a temperature of above about 270°

C.

7687. The method of claim 7668, wherein the second fluid comprises soda ash, and further comprising removing at least a portion of the soda ash from the second fluid as sodium carbonate.

7688. The method of claim 7668, wherein the second fluid comprises nahcolite, and further comprising:

separating at least a portion of the nahcolite from the second fluid;

providing heat to at least some of the separated nahcolite to form a sodium carbonate solution;

providing at least some of the sodium carbonate solution to at least the portion of the formation; and

producing a third fluid comprising alumina from the formation.

7689. The method of claim 7668, further comprising providing a barrier to at least the portion of the formation to inhibit migration of fluids into or out of the portion.

7690. The method of claim 7668, wherein the first fluid comprises steam.

7691. The method of claim 7668, wherein the second fluid comprises a metal.

7692. The method of claim 7668, wherein the second fluid comprises a mineral.

7693. The method of claim 7668, wherein the second fluid comprises aluminum.

7694. The method of claim 7668, wherein the second fluid comprises a metal, and further comprising separating the metal from the second fluid.

7695. The method of claim 7668, further comprising producing a non-hydrocarbon material from the second fluid.

7696. The method of claim 7668, wherein greater than about 10% by weight of the selected section comprises nahcolite.

7697. The method of claim 7668, wherein greater than about 2% by weight of the selected section comprises dawsonite.

7698. The method of claim 7668, wherein at least some of the provided heat comprises waste heat from another portion of the formation.

7699. The method of claim 7668, wherein the first fluid comprises steam, and further comprising providing heat to the formation by injecting the steam into the formation.

7700. The method of claim 7668, further comprising providing heat to the formation by injecting the first fluid into the formation.

7701. The method of claim 7668, further comprising providing heat to the formation by injecting the first fluid into the formation, wherein the first fluid is at a temperature above about 90°

C.

7702. The method of claim 7668, further comprising controlling a temperature of the selected section while injecting the first fluid, wherein the temperature is less than about a temperature at which nahcolite will dissociate.

7703. The method of claim 7668, wherein the hydrocarbon containing formation comprises oil shale.

7704. The method of claim 7668, further comprising providing a barrier substantially surrounding the selected section such that the barrier inhibits the flow of water into the formation.

7705. The method of claim 7668, wherein the mixture is produced from the formation when a partial pressure of hydrogen in at least a portion the formation is at least about 0.5 bars absolute.

7706. The method of claim 7668, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7707. The method of claim 7668, wherein the one or more of the heaters comprise heaters.

7708. A method of solution mining alumina from an in situ hydrocarbon containing formation, comprising:

providing heat from one or more heaters to a least a portion of the formation;

pyrolyzing at least some hydrocarbons in the portion; and

producing a mixture from the formation

providing a brine solution to a portion of the formation; and

producing a mixture comprising alumina from the formation.

7709. The method of claim 7708, wherein the selected section comprises dawsonite.

7710. The method of claim 7708, further comprising:

separating at least a portion of the alumina from the mixture; and

providing heat to at least the portion of the alumina to generate aluminum.

7711. The method of claim 7708, further comprising:

separating at least a portion of the alumina from the mixture;

providing heat to at least the portion of the alumina to generate aluminum; and

wherein the provided heat is generated in part using one or more products of an in situ conversion process.

7712. The method of claim 7708, further comprising producing the mixture when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

7713. The method of claim 7708, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7714. The method of claim 7708, wherein one or more of the heaters comprise heaters.

7715. A method of treating a hydrocarbon containing formation in situ, comprising:

allowing a temperature of a portion of the formation to decrease, wherein the portion has previously undergone an in situ conversion process;

injecting a first fluid into the selected section; and

producing a second fluid from the formation.

7716. The method of claim 7715, wherein the in situ conversion process comprises:

providing heat to a least a portion of the formation;

pyrolyzing at least some hydrocarbons in the portion; and

producing a mixture from the formation.

7717. The method of claim 7715, wherein the first fluid comprises water.

7718. The method of claim 7715, wherein the second fluid comprises a metal.

7719. The method of claim 7715, wherein the second fluid comprises a mineral.

7720. The method of claim 7715, wherein the second fluid comprises aluminum.

7721. The method of claim 7715, wherein the second fluid comprises a metal,and further comprising producing the metal from the second fluid.

7722. The method of claim 7715, further comprising producing a non-hydrocarbon material from the second fluid.

7723. The method of claim 7715, wherein the selected section comprises nahcolite.

7724. The method of claim 7715, wherein greater than about 10% by weight of the selected section comprises nahcolite.

7725. The method of claim 7715, wherein the selected section comprises dawsonite.

7726. The method of claim 7715, wherein greater than about 2% by weight of the selected section comprises dawsonite.

7727. The method of claim 7715, wherein the provided heat comprises waste heat from another portion of the formation.

7728. The method of claim 7715, wherein the first fluid comprises steam.

7729. The method of claim 7715, wherein the first fluid comprises steam, and further comprising providing heat to the formation by injecting the steam into the formation.

7730. The method of claim 7715, further comprising providing heat to the formation by injecting the first fluid into the formation.

7731. The method of claim 7715, further comprising providing heat to the formation by injecting the first fluid into the formation, wherein the first fluid is at a temperature above about 90°

C.

7732. The method of claim 7715, wherein the reduced temperature of the selected section is less than about 90°

C.

7733. The method of claim 7715, wherein an average richness of at least the portion of the selected section is greater than about 0.10 liters per kilogram.

7734. The method of claim 7715, wherein the hydrocarbon containing formation comprises oil shale.

7735. A method for treating a relatively permeable formation in situ, comprising:

providing heat from one or more heaters to a first section of the formation such that the heat provided to the first section pyrolyzes at least some hydrocarbons within the first section;

providing heat from one or more heaters to a second section of the formation such that the heat provided to the second section pyrolyzes at least some hydrocarbons within the second section;

inducing at least a portion of the hydrocarbons from the second section to flow into the first section; and

producing a mixture from the first section, wherein the produced mixture comprises at least some pyrolyzed hydrocarbons from the second section.

7736. The method of claim 7735, wherein a portion of the first section comprises a first permeability, wherein a portion of the second section comprises a second permeability, and wherein the first permeability is greater than about the second permeability.

7737. The method of claim 7735, wherein a portion of the first section comprises a first permeability, wherein a portion of the second section comprises a second permeability, and wherein the first permeability is less than about the second permeability.

7738. The method of claim 7735, wherein the second section is substantially adjacent to the first section.

7739. The method of claim 7735, further comprising providing heat to a third section of the formation such that the heat provided to the third section pyrolyzes at least some hydrocarbons in the third section and inducing a portion of the hydrocarbons from the third section to flow into the first section.

7740. The method of claim 7739, wherein the third section is substantially adjacent to the first section.

7741. The method of claim 7735, further comprising:

providing heat from one or more heaters to a third section of the formation such that the heat provided to the third section pyrolyzes at least some hydrocarbons in the third section; and

inducing a portion of the hydrocarbons from the third section to flow into the first section through the second section.

7742. The method of claim 7741, wherein the third section is substantially adjacent to the second section.

7743. The method of claim 7735, further comprising maintaining a pressure in the formation below about 150 bars absolute.

7744. The method of claim 7735, further comprising inhibiting production of the produced mixture until at least some hydrocarbons in the formation have been pyrolyzed.

7745. The method of claim 7735, further comprising producing at least some hydrocarbons from the first section before providing heat to the second section.

7746. The method of claim 7735, further comprising producing at least some hydrocarbons from the first section before a temperature in the second section reaches a pyrolysis temperature.

7747. The method of claim 7735, further comprising maintaining a pressure within the formation below a selected pressure by producing at least some hydrocarbons from the formation.

7748. The method of claim 7735, further comprising producing the produced mixture through at least one production well in or proximate the first section.

7749. The method of claim 7735, further comprising producing at least some hydrocarbons through at least one production well in or proximate the second section.

7750. The method of claim 7735, further comprising controlling the heat provided to the first section and the second section such that conversion of heavy hydrocarbons into light hydrocarbons within the formation is controlled.

7751. The method of claim 7750, wherein controlling the heat provided to the first section and the second section comprises adjusting heat output of at least one of the heaters that heats the first section.

7752. The method of claim 7750, wherein controlling the heat provided to the first section and the second section comprises adjusting heat output of at least one of the heaters that heats the second section.

7753. The method of claim 7735, wherein one or more heaters provide heat to the first section of the formation and the second section of the formation.

7754. The method of claim 7735, wherein a first set of one or more heaters provides heat to the first section and a second set of one or more heaters provides heat to the second section.

7755. The method of claim 7735, further comprising controlling the heat provided to the first section and the second section to produce a desired characteristic in the produced mixture.

7756. The method of claim 7755, wherein controlling the heat provided to the first section and the second section comprises adjusting heat output of at least one of the heaters that heats the first section.

7757. The method of claim 7755, wherein controlling the heat provided to the first section and the second section comprises adjusting heat output of at least one of the heaters that heats the first section.

7758. The method of claim 7755, wherein the desired characteristic in the produced mixture comprises an API gravity of the produced mixture.

7759. The method of claim 7755, wherein the desired characteristic in the produced mixture comprises a production rate of the produced mixture.

7760. The method of claim 7755, wherein the desired characteristic in the produced mixture comprises a weight percentage of light hydrocarbons in the produced mixture.

7761. The method of claim 7735, wherein the produced mixture comprises an API gravity of greater than about 20°

.

7762. The method of claim 7735, wherein the produced mixture comprises an acid number less than about 1.

7763. The method of claim 7735, wherein greater than about 50% by weight of the initial mass of hydrocarbons in the formation is produced.

7764. The method of claim 7735, wherein at least a portion of the first section is above a pyrolysis temperature of the hydrocarbons.

7765. The method of claim 7764, wherein the pyrolysis temperature is at least about 250°

C.

7766. The method of claim 7735, wherein the heaters that heat the first section comprise a spacing between heated portions of the heaters of less than about 25 m.

7767. The method of claim 7735, further comprising producing the mixture when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

7768. The method of claim 7735, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7769. The method of claim 7735, wherein one or more of the heaters comprise heaters.

7770. The method of claim 7735, wherein a ratio of energy output of the produced mixture to energy input into the formation is at least about 5.

7771. A method for treating a relatively permeable formation in situ, comprising:

providing heat from one or more heaters to a first section of the formation such that the heat provided to the first section pyrolyzes at least some hydrocarbons within the first section;

providing heat from one or more heaters to a second section of the formation such that the heat provided to the second section pyrolyzes at least some hydrocarbons within the second section;

inducing at least a portion of the hydrocarbons from the second section to flow into the first section;

inhibiting production of a mixture until at least some hydrocarbons in the formation have been pyrolyzed; and

producing the mixture from the first section, wherein the produced mixture comprises at least some pyrolyzed hydrocarbons from the second section.

7772. A method for treating a relatively permeable formation in situ, comprising:

providing heat from one or more heaters to a first section of the formation such that the heat provided to the first section reduces the viscosity of at least some heavy hydrocarbons within the first section;

providing heat from one or more heaters to a second section of the formation such that the heat provided to the second section reduces the viscosity of at least some heavy hydrocarbons within the second section;

inducing a portion of the heavy hydrocarbons from the second section to flow into the first section;

pyrolyzing at least some of the heavy hydrocarbons within the first section; and

producing a mixture from the first section, wherein the produced mixture comprises at least some pyrolyzed hydrocarbons.

7773. The method of claim 7772, wherein the second section is substantially adjacent to the first section.

7774. The method of claim 7772, further comprising producing a mixture from the first section of the formation, wherein the mixture comprises at least some heavy hydrocarbons.

7775. The method of claim 7772, further comprising producing the mixture from the first section through a production well in or proximate the first section and pyrolyzing at least some of the heavy hydrocarbons within the production well.

7776. The method of claim 7772, further comprising pyrolyzing at least some hydrocarbons within the second section.

7777. The method of claim 7772, further comprising providing heat to a third section of the formation such that the heat provided to the third section reduces the viscosity of at least some heavy hydrocarbons in the third section, and inducing a portion of the heavy hydrocarbons from the third section to flow into the first section.

7778. The method of claim 7777, wherein the third section is substantially adjacent to the first section.

7779. The method of claim 7772, further comprising:

providing heat from one or more heaters to a third section of the formation such that the heat provided to the third section reduces the viscosity of at least some heavy hydrocarbons in the third section;

inducing a portion of the heavy hydrocarbons from the third section to flow into the second section;

pyrolyzing at least some of the heavy hydrocarbons within the second section; and

producing a mixture from the second section, wherein the produced mixture comprises at least some pyrolyzed hydrocarbons.

7780. The method of claim 7779, wherein the third section is substantially adjacent to the second section.

7781. The method of claim 7772, further comprising:

providing heat from one or more heaters to a third section of the formation such that the heat provided to the third section reduces the viscosity of at least some heavy hydrocarbons in the third section; and

inducing a portion of the heavy hydrocarbons from the third section to flow into the first section through the second section.

7782. The method of claim 7781, wherein the third section is substantially adjacent to the second section.

7783. The method of claim 7772, wherein one or more heaters provide heat to the first section of the formation and the second section of the formation.

7784. The method of claim 7772, wherein a first set of one or more heaters provides heat to the first section and a second set of one or more heaters provides heat to the second section.

7785. The method of claim 7772, further comprising controlling the heat provided to the first section and the second section such that conversion of heavy hydrocarbons into light hydrocarbons within the first section is controlled.

7786. The method of claim 7785, wherein controlling the heat provided to the first section and the second section comprises adjusting heat output of at least one of the heaters that heats the first section.

7787. The method of claim 7785, wherein controlling the heat provided to the first section and the second section comprises adjusting heat output of at least one of the heaters that heats the second section.

7788. The method of claim 7772, further comprising controlling the heat provided to the first section and the second section to produce a desired characteristic in the produced mixture.

7789. The method of claim 7788, wherein controlling the heat provided to the first section and the second section comprises adjusting heat output of at least one of the heaters that heats the first section.

7790. The method of claim 7788, wherein controlling the heat provided to the first section and the second section comprises adjusting heat output of at least one of the heaters that heats the first section.

7791. The method of claim 7788, wherein the desired characteristic in the produced mixture comprises an API gravity of the produced mixture.

7792. The method of claim 7788, wherein the desired characteristic in the produced mixture comprises a weight percentage of light hydrocarbons in the produced mixture.

7793. The method of claim 7772, further comprising producing at least about 70% of an initial volume in place from the formation.

7794. The method of claim 7772, wherein the produced mixture comprises an API gravity of greater than about 20°

.

7795. The method of claim 7772, wherein the produced mixture comprises an acid number less than about 1.

7796. The method of claim 7772, wherein at least a portion of the first section is above a pyrolysis temperature of the hydrocarbons.

7797. The method of claim 7796, wherein the pyrolysis temperature is at least about 250°

C.

7798. The method of claim 7772, wherein a spacing between heated sections of at least two heaters is less than about 25 m.

7799. The method of claim 7772, further comprising producing the mixture when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

7800. The method of claim 7772, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7801. The method of claim 7772, wherein one or more of the heaters comprise heaters.

7802. The method of claim 7772, wherein a ratio of energy output of the produced mixture to energy input into the formation is at least about 5.

7803. A method for treating a relatively permeable formation in situ, comprising:

providing heat to at least a portion of the formation;

producing heavy hydrocarbons from a first section of the relatively permeable formation;

inducing heavy hydrocarbons from a second section of the formation to flow into the first section of the formation;

producing a portion of the second section heavy hydrocarbons from the first section of the formation;

inducing heavy hydrocarbons from a third section of the formation to flow into the second section of the formation; and

producing a portion of the third section heavy hydrocarbons from the second section of the formation or the first section of the formation.

7804. The method of claim 7803, wherein greater than 50% by weight of the initial mass of hydrocarbons in a portion of the formation selected for treatment are produced

7805. The method of claim 7803, further comprising pyrolyzing at least some of the second section heavy hydrocarbons in the first section.

7806. The method of claim 7803, further comprising pyrolyzing at least some of the third section heavy hydrocarbons in the second section or the first section.

7807. The method of claim 7803, further comprising producing at least about 70% of an initial volume in place from the formation.

7808. The method of claim 7803, further comprising producing hydrocarbons when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

7809. The method of claim 7803, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7810. The method of claim 7803, wherein one or more of the heaters comprise heaters.

7811. A method for treating a relatively permeable formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the relatively permeable formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat reduces the viscosity of at least some hydrocarbons within the selected section;

providing a gas to the selected section of the formation, wherein the gas produces a flow of at least some hydrocarbons within the selected section; and

producing a mixture from the selected section.

7812. The method of claim 7811, further comprising controlling a pressure within the selected section such that the pressure is maintained below about 150 bars absolute.

7813. The method of claim 7811, further comprising controlling a temperature within the selected section to maintain the temperature within the selected section below a pyrolysis temperature of the hydrocarbons.

7814. The method of claim 7813, further comprising maintaining an average temperature within the selected section above about 50°

C. and below about 210°

C.

7815. The method of claim 7811, wherein providing the gas to the selected section comprises injecting the gas such that the gas sweeps hydrocarbons within the selected section, and wherein greater than about 50% by weight of the initial mass of hydrocarbons is produced from the selected section.

7816. The method of claim 7811, further comprising producing at least about 70% of an initial volume in place from the selected section.

7817. The method of claim 7811, wherein a ratio of energy output of the produced mixture to energy input into the formation is at least about 5.

7818. The method of claim 7811, wherein a ratio of energy output of the produced mixture to energy input into the formation is at least about 5, and wherein the produced mixture comprises an API gravity of at least about 15.

7819. The method of claim 7811, further comprising providing the gas through one or more injection wells in the selected section.

7820. The method of claim 7811, further comprising providing the gas through one or more injection wells in the selected section and controlling a pressure within the selected section by controlling an injection rate into at least one injection well.

7821. The method of claim 7811, further comprising providing the gas through one or more injection wells in the formation and controlling a pressure within the selected section by controlling a location for injecting the gas within the formation.

7822. The method of claim 7811, further comprising producing the mixture through one or more production wells in or proximate the formation.

7823. The method of claim 7811, further comprising controlling a pressure within the selected section through one or more production wells in or proximate the formation.

7824. The method of claim 7811, further comprising controlling a temperature within the selected section while controlling a pressure within the selected section.

7825. The method of claim 7811, further comprising creating a path for flow of hydrocarbons along a length of at least one heater in the selected section.

7826. The method of claim 7825, wherein the path along the length of at least one heater extends between an injection well and a production well.

7827. The method of claim 7825, wherein a heater is turned off after the path for flow along the heater is created.

7828. The method of claim 7811, wherein the gas increases a flow of hydrocarbons within the formation.

7829. The method of claim 7811, further comprising increasing a pressure in the selected section with the provided gas.

7830. The method of claim 7811, wherein a spacing between heated sections of at least two sources is less than about 50 m and greater than about 5 m.

7831. The method of claim 7811, wherein the gas comprises carbon dioxide.

7832. The method of claim 7811, wherein the gas comprises nitrogen.

7833. The method of claim 7811, wherein the gas comprises steam.

7834. The method of claim 7811, wherein the gas comprises water, and wherein the water forms steam in the formation.

7835. The method of claim 7811, wherein the gas comprises methane.

7836. The method of claim 7811, wherein the gas comprises gas produced from the formation.

7837. The method of claim 7811, further comprising providing the gas through at least one injection well placed substantially vertically in the formation, and producing the mixture through a heater placed substantially horizontally in the formation.

7838. The method of claim 7837, further comprising selectively limiting a temperature proximate a selected portion of a wellbore of the heater to inhibit coke formation at or near the selected portion, and producing the mixture through perforations in the selected portion of the wellbore.

7839. The method of claim 7811, further comprising allowing heat to transfer to the selected section such that the provided heat pyrolyzes at least some hydrocarbons within the selected section.

7840. The method of claim 7811, further comprising controlling the transfer of heat from the one or more heaters and controlling the flow of provided gas such that the flow of hydrocarbons within the selected section is controlled.

7841. The method of claim 7811, further comprising producing the mixture when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

7842. The method of claim 7811, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7843. The method of claim 7811, wherein one or more of the heaters comprise heaters.

7844. The method of claim 7811, wherein the produced mixture comprises an acid number less than about 1.

7845. A method for treating a relatively permeable formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the relatively permeable formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat reduces the viscosity of at least some hydrocarbons within the selected section;

providing a gas to the selected section of the formation, wherein the gas produces a flow of at least some hydrocarbons within the selected section;

controlling a pressure within the selected section such that the pressure is maintained below about 150 bars absolute; and

producing a mixture from the selected section.

7846. A method for treating a relatively permeable formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the relatively permeable formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat pyrolyzes at least some hydrocarbons within the selected section;

producing a mixture of hydrocarbons from the selected section; and

controlling production of the mixture to adjust the time that at least some hydrocarbons are exposed to pyrolysis temperatures in the formation in order to produce hydrocarbons of a selected quality in the mixture.

7847. The method of claim 7846, further comprising inhibiting production of hydrocarbons from the formation until at least some hydrocarbons have been pyrolyzed.

7848. The method of claim 7846, wherein the selected quality comprises a selected minimum API gravity.

7849. The method of claim 7846, wherein the selected quality comprises an API gravity of at least about 20°

.

7850. The method of claim 7846, wherein the selected quality comprises a selected maximum weight percentage of heavy hydrocarbons.

7851. The method of claim 7846, wherein the selected quality comprises a mean carbon number that is less than 12.

7852. The method of claim 7846, wherein the produced mixture comprises an acid number less than about 1.

7853. The method of claim 7846, further comprising sampling a test stream of the produced mixture to determine the selected quality of the produced mixture.

7854. The method of claim 7846, further comprising determining the time that at least some hydrocarbons in the produced mixture are subjected to pyrolysis temperatures using laboratory treatment of formation samples.

7855. The method of claim 7846, further comprising determining the time that at least some hydrocarbons in the produced mixture are subjected to pyrolysis temperatures using a computer simulation of treatment of the formation.

7856. The method of claim 7846, further comprising controlling a pressure within the selected section such that the pressure is maintained below a lithostatic pressure of the formation.

7857. The method of claim 7846, further comprising controlling a pressure within the selected section such that the pressure is maintained below a hydrostatic pressure of the formation.

7858. The method of claim 7846, further comprising controlling a pressure within the selected section such that the pressure is maintained below about 150 bars absolute.

7859. The method of claim 7846, further comprising controlling a pressure within the selected section through one or more production wells.

7860. The method of claim 7846, further comprising controlling a pressure within the selected section through one or more pressure release wells.

7861. The method of claim 7846, further comprising controlling a pressure within the selected section by producing at least some hydrocarbons from the selected section.

7862. The method of claim 7846, further comprising producing the mixture when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

7863. The method of claim 7846, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7864. The method of claim 7846, wherein one or more of the heaters comprise heaters.

7865. The method of claim 7846, wherein a ratio of energy output of the produced mixture to energy input into the formation is at least about 5.

7866. A method for treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat pyrolyzes at least some hydrocarbons within the selected section;

selectively limiting a temperature proximate a selected portion of a heater

wellbore to inhibit coke formation at or near the selected portion; and

producing at least some hydrocarbons through the selected portion of the heater wellbore.

7867. The method of claim 7866, further comprising generating water in the selected portion to inhibit coke formation at or near the selected portion of the heater wellbore.

7868. The method of claim 7866, wherein the heater wellbore is placed substantially horizontally within the selected section.

7869. The method of claim 7866, wherein selectively limiting the temperature comprises providing less heat at the selected portion of the heater wellbore than other portions of the heater wellbore in the selected section.

7870. The method of claim 7866, wherein selectively limiting the temperature comprises maintaining the temperature proximate the selected portion below pyrolysis temperatures.

7871. The method of claim 7866, further comprising producing a mixture from the selected section through a production well.

7872. The method of claim 7866, further comprising providing at least some heat to an overburden section of the heater wellbore to maintain the produced hydrocarbons in a vapor phase.

7873. The method of claim 7866, further comprising maintaining a pressure in the selected section below about 150 bars absolute.

7874. The method of claim 7866, further comprising producing hydrocarbons when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

7875. The method of claim 7866, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7876. The method of claim 7866, wherein one or more of the heaters comprise heaters.

7877. The method of claim 7866, wherein a ratio of energy output of the produced mixture to energy input into the formation is at least about 5.

7878. The method of claim 7866, wherein the produced mixture comprises an acid number less than about 1.

7879. A method for treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat pyrolyzes at least some hydrocarbons within the selected section;

controlling operating conditions at a production well to inhibit coking in or proximate the production well; and

producing a mixture from the selected section through the production well.

7880. The method of claim 7879, wherein controlling the operating conditions at the production well comprises controlling heat output from at least one heater proximate the production well.

7881. The method of claim 7879, wherein controlling the operating conditions at the production well comprises reducing or turning off heat provided from at least one of the heaters for at least part of a time in which the mixture is produced through the production well.

7882. The method of claim 7879, wherein controlling the operating conditions at the production well comprises increasing or turning on heat provided from at least one of the heaters to maintain a desired quality in the produced mixture.

7883. The method of claim 7879, wherein controlling the operating conditions at the production well comprises producing the mixture at a location sufficiently spaced from at least one heater such that coking is inhibited at the production well.

7884. The method of claim 7879, further comprising adding steam to the selected section to inhibit coking at the production well.

7885. The method of claim 7879, further comprising producing the mixture when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

7886. The method of claim 7879, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7887. The method of claim 7879, wherein one or more of the heaters comprise heaters.

7888. The method of claim 7879, wherein a ratio of energy output of the produced mixture to energy input into the formation is at least about 5.

7889. The method of claim 7879, wherein the produced mixture comprises an acid number less than about 1.

7890. A method for treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the hydrocarbon containing formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat pyrolyzes at least some hydrocarbons within the selected section;

producing a mixture from the selected section; and

controlling a quality of the produced mixture by varying a location for producing the mixture.

7891. The method of claim 7890, wherein varying the location for producing the mixture comprises varying a production location within a production well in or proximate the selected section.

7892. The method of claim 7891, wherein varying the production location within the production well comprises varying a packing height within the production well.

7893. The method of claim 7891, wherein varying the production location within the production well comprises varying a location of perforations used to produce the mixture within the production well.

7894. The method of claim 7890, wherein varying the location for producing the mixture comprises varying a production location along a length of a production wellbore placed in the formation.

7895. The method of claim 7890, wherein varying the location for producing the mixture comprises varying a location of a production well within the formation.

7896. The method of claim 7890, wherein varying the location for producing the mixture comprises varying a number of production wells in the formation.

7897. The method of claim 7890, wherein varying the location for producing the mixture comprises varying a distance between a production well and one or more heaters.

7898. The method of claim 7890, further comprising increasing the quality of the produced mixture by producing the mixture from an upper portion of the selected section.

7899. The method of claim 7890, further comprising increasing a total mass recovery from the selected section by producing the mixture from a lower portion of the selected section.

7900. The method of claim 7890, further comprising selecting the location for production based on a price characteristic for produced hydrocarbons.

7901. The method of claim 7900, wherein the price characteristic is determined by multiplying a production rate of the produced mixture at a selected API gravity from the selected section by a price obtainable for selling the produced mixture with the selected API gravity.

7902. The method of claim 7900, further comprising adjusting the location for production based on a change in the price characteristic.

7903. The method of claim 7890, wherein the quality of the produced mixture comprises an API gravity of the produced mixture.

7904. The method of claim 7890, wherein the produced mixture comprises an acid number less than about 1.

7905. The method of claim 7890, further comprising controlling the quality of the produced mixture by controlling the heat provided from at least one heater.

7906. The method of claim 7890, further comprising controlling the quality of the produced mixture such that the produced mixture comprises a selected minimum API gravity.

7907. The method of claim 7890, further comprising producing the mixture when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

7908. The method of claim 7890, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7909. The method of claim 7890, wherein one or more of the heaters comprise heaters.

7910. The method of claim 7890, wherein a ratio of energy output of the produced mixture to energy input into the formation is at least about 5.

7911. A method for treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the relatively permeable formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat pyrolyzes at least some hydrocarbons within the selected section;

producing a first mixture from a first portion of the selected section; and

producing a second mixture from a second portion of the selected section.

7912. The method of claim 7911, further comprising producing a third mixture from a third portion of the selected section.

7913. The method of claim 7911, further comprising producing a third mixture from a third portion of the selected section, wherein the first portion is substantially above the second portion, wherein the second portion is substantially above the third portion, and wherein the first mixture is produced, then the second mixture, and then the third mixture.

7914. The method of claim 7911, wherein the first portion is substantially above the second portion.

7915. The method of claim 7911, wherein the first portion is substantially below the second portion.

7916. The method of claim 7911, wherein the first portion is substantially adjacent to the second portion.

7917. The method of claim 7911, wherein the first mixture comprises an API gravity greater than about 200.

7918. The method of claim 7911, wherein the second mixture comprises an API gravity greater than about 200.

7919. The method of claim 7911, wherein the first mixture comprises an acid number less than about 1.

7920. The method of claim 7911, wherein the second mixture comprises an acid number less than about 1.

7921. The method of claim 7911, wherein the first portion comprises about an upper one-third of the formation.

7922. The method of claim 7911, wherein the second portion comprises about a lower one-third of the formation.

7923. The method of claim 7911, wherein the first mixture is produced before the second mixture is produced.

7924. The method of claim 7911, further comprising producing the first or the second mixture when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

7925. The method of claim 7911, wherein the heat provided from-at least one heater is transferred to at least a portion of the formation substantially by conduction.

7926. The method of claim 7911, wherein one or more of the heaters comprise heaters.

7927. The method of claim 7911, wherein a ratio of energy output of the first or the second produced mixture to energy input into the formation is at least about 5.

7928. A method for treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters to a selected section of the formation such that the heat provided to the selected section pyrolyzes at least some hydrocarbons within a lower portion of the formation; and

producing a mixture from an upper portion of the formation, wherein the produced mixture comprises at least some pyrolyzed hydrocarbons from the lower portion.

7929. The method of claim 7928, wherein the produced mixture comprises an API gravity greater than about 15°

.

7930. The method of claim 7928, wherein the produced mixture comprises an acid number less than about 1.

7931. The method of claim 7928, wherein the upper portion comprises about an upper one-half of the formation.

7932. The method of claim 7928, wherein the lower portion comprises about a lower one-half of the formation.

7933. The method of claim 7928, further comprising producing the mixture of hydrocarbons as a vapor.

7934. The method of claim 7928, further comprising providing heat from one or more heaters to a selected section of the formation such that the heat provided to the selected section reduces the viscosity of at least some hydrocarbons within the selected section.

7935. The method of claim 7928, further comprising inducing at least a portion of the hydrocarbons from the lower portion to flow into the upper portion.

7936. The method of claim 7928, wherein the upper portion and the lower portion are within the selected section.

7937. The method of claim 7928, further comprising producing the mixture when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

7938. The method of claim 7928, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7939. The method of claim 7928, wherein one or more of the heaters comprise heaters.

7940. The method of claim 7928, wherein a ratio of energy output of the produced mixture to energy input into the formation is at least about 5.

7941. A method for treating a relatively permeable formation in situ, comprising:

providing heat from one or more heaters to at least a portion of a relatively permeable formation;

allowing heat to transfer from one or more heaters to a first selected section of a relatively permeable formation such that the heat reduces the viscosity of at least some hydrocarbons within the first selected section;

producing a first mixture from the first selected section;

allowing heat to transfer from one or more heaters to a second selected section of a relatively permeable formation such that the heat pyrolyzes at least some hydrocarbons within the second selected section;

producing a second mixture from the second selected section; and

blending at least a portion of the first mixture with at least a portion of the second mixture to produce a third mixture comprising a selected property.

7942. The method of claim 7941, wherein the selected property of the third mixture comprises an API gravity.

7943. The method of claim 7941, wherein the selected property of the third mixture comprises an API gravity of at least about 10°

.

7944. The method of claim 7941, wherein the selected property of the third mixture comprises a selected viscosity.

7945. The method of claim 7941, wherein the selected property of the third mixture comprises a viscosity less than about 7500 cs.

7946. The method of claim 7941, wherein the selected property of the third mixture comprises a density.

7947. The method of claim 7941, wherein the selected property of the third mixture comprises a density less than about 1 g/cm³.

7948. The method of claim 7941, wherein the selected property of the third mixture comprises an asphaltene to saturated hydrocarbon ratio of less than about 1.

7949. The method of claim 7941, wherein the selected property of the third mixture comprises an aromatic hydrocarbon to saturated hydrocarbon ratio of less than about 4.

7950. The method of claim 7941, wherein asphaltenes are substantially stable in the third mixture at ambient temperature.

7951. The method of claim 7941, wherein the third mixture is transportable.

7952. The method of claim 7941, wherein the third mixture is transportable through a pipeline.

7953. The method of claim 7941, wherein the first mixture comprises an API gravity less than about 15°

.

7954. The method of claim 7941, wherein the second mixture comprises an API gravity greater than about 25°

.

7955. The method of claim 7941, wherein the second mixture comprises an acid number less than about 1.

7956. The method of claim 7941, further comprising selecting a ratio of the first mixture to the second mixture such that at least about 50% by weight of the initial mass of hydrocarbons in a selected portion of the formation is produced.

7957. The method of claim 7941, wherein the third mixture comprises less than about 50% by weight of the second mixture.

7958. The method of claim 7941, wherein the first selected section comprises a depth of at least about 500 m below the surface of a relatively permeable formation.

7959. The method of claim 7941, wherein the second selected section comprises a depth less than about 500 m below the surface of a relatively permeable formation.

7960. The method of claim 7941, wherein the first selected section and the second selected section are located in different relatively permeable formations.

7961. The method of claim 7941, wherein the first selected section and the second selected section are located in different relatively permeable formations, and wherein the different relatively permeable formation are vertically displaced.

7962. The method of claim 7941, wherein the first selected section and the second selected section are vertically displaced within a single relatively permeable formation.

7963. The method of claim 7941, wherein the first selected section and the second selected section are substantially adjacent within a single relatively permeable formation.

7964. The method of claim 7941, wherein blending comprises injecting at least a portion of the second mixture into the first selected section such that the second mixture blends with at least a portion of the first mixture to produce the third mixture in the first selected section.

7965. The method of claim 7941, wherein blending comprises injecting at least a portion of the second mixture into a production well in the first selected section such that the second mixture blends with at least a portion of the first mixture to produce the third mixture in the production well.

7966. The method of claim 7941, further comprising producing a mixture when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

7967. The method of claim 7941, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7968. The method of claim 7941, wherein one or more of the heaters comprise heaters.

7969. The method of claim 7941, wherein a ratio of energy output of the first or the second produced mixture to energy input into the formation is at least about 5.

7970. A method for treating a relatively permeable formation in situ to produce a blending agent, comprising:

providing heat from one or more heaters to at least a portion of the relatively permeable formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat pyrolyzes at least some hydrocarbons within the selected section;

producing a blending agent from the selected section; and

wherein at least a portion of the blending agent is adapted to blend with a liquid to produce a mixture with a selected property.

7971. The method of claim 7970, wherein the liquid comprises at least some heavy hydrocarbons.

7972. The method of claim 7970, wherein the liquid comprises an API gravity below about 15°

.

7973. The method of claim 7970, wherein the liquid is viscous, and wherein a mixture produced by blending at least a portion of the blending agent with the liquid is less viscous than the liquid.

7974. The method of claim 7970, wherein the selected property of the mixture comprises an API gravity.

7975. The method of claim 7970, wherein the selected property of the mixture comprises an API gravity of at least about 10°

.

7976. The method of claim 7970, wherein the selected property of the mixture comprises a selected viscosity.

7977. The method of claim 7970, wherein the selected property of the mixture comprises a viscosity less than about 7500 cs.

7978. The method of claim 7970, wherein the selected property of the mixture comprises a density.

7979. The method of claim 7970, wherein the selected property of the mixture comprises a density less than about 1 g/cm³.

7980. The method of claim 7970, wherein the selected property of the mixture comprises an asphaltene to saturated hydrocarbon ratio of less than about 1.

7981. The method of claim 7970, wherein the selected property of the mixture comprises an aromatic hydrocarbon to saturated hydrocarbon ratio of less than about 4.

7982. The method of claim 7970, wherein asphaltenes are substantially stable in the mixture at ambient temperature.

7983. The method of claim 7970, wherein the mixture is transportable.

7984. The method of claim 7970, wherein the mixture is transportable through a pipeline.

7985. The method of claim 7970, wherein the liquid has a viscosity sufficiently high to inhibit economical transport of the liquid over 100 km via a pipeline but the mixture has a reduced viscosity that allows economical transport of the mixture over 100 km via a pipeline.

7986. The method of claim 7970, further comprising producing the liquid from a second section of a relatively permeable formation and blending the liquid with the blending agent to produce the mixture.

7987. The method of claim 7970, further comprising producing the liquid from a second section of a relatively permeable formation and blending the liquid with the blending agent to produce the mixture, wherein the mixture comprises less than about 50% by weight of the blending agent.

7988. The method of claim 7970, further comprising injecting the blending agent into a second section of a relatively permeable formation such that the blending agent blends with the liquid in the second section to produce the mixture.

7989. The method of claim 7970, further comprising injecting the blending agent into a production well in a second section of a relatively permeable formation such that the blending agent blends with the liquid in the production well to produce the mixture.

7990. The method of claim 7970, further comprising producing the blending agent when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

7991. The method of claim 7970, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

7992. The method of claim 7970, wherein one or more of the heaters comprise heaters.

7993. The method of claim 7970, wherein a ratio of energy output of the blending agent to energy input into the formation is at least about 5.

7994. The method of claim 7970, wherein the blending agent comprises an acid number less than about 1.

7995. A blending agent produced by a method, comprising:

providing heat from one or more heaters to at least a portion of a relatively permeable formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat pyrolyzes at least some hydrocarbons within the selected section; and

producing the blending agent from the selected section;

wherein at least a portion of the blending agent is adapted to blend with a liquid to produce a mixture with a selected property.

7996. The blending agent of claim 7995, wherein the blending agent comprises an API gravity of at least about 20°

.

7997. The blending agent of claim 7995, wherein the blending agent comprises an acid number less than about 1.

7998. The blending agent of claim 7995, wherein the blending agent comprises an asphaltene weight percentage less than about 0.5%.

7999. The blending agent of claim 7995, wherein the blending agent comprises a combined nitrogen, oxygen, and sulfur weight percentage less than about 5%.

8000. The blending agent of claim 7995, wherein asphaltenes are substantially stable in the mixture at ambient temperature.

8001. The blending agent of claim 7995, wherein the method further comprises producing the blending agent when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

8002. The blending agent of claim 7995, wherein the method further comprises the heat provided from at least one heater transferring to at least a portion of the formation substantially by conduction.

8003. The blending agent of claim 7995, wherein the method further comprises one or more of the heaters comprising heaters.

8004. The blending agent of claim 7995, wherein the method further comprises a ratio of energy output of the blending agent to energy input into the formation being at least about 5.

8005. A method for treating a relatively permeable formation in situ, comprising:

producing a first mixture from a first selected section of a relatively permeable formation, wherein the first mixture comprises heavy hydrocarbons;

providing heat from one or more heaters to a second selected section of the relatively permeable formation such that the heat pyrolyzes at least some hydrocarbons within the second selected section;

producing a second mixture from the second selected section; and

blending at least a portion of the first mixture with at least a portion of the second mixture to produce a third mixture comprising a selected property.

8006. The method of claim 8005, further comprising cold producing the first mixture from the first selected section.

8007. The method of claim 8005, wherein producing the first mixture from the first selected section comprises producing the first mixture through a production well in or proximate the formation.

8008. The method of claim 8005, wherein the selected property of the third mixture comprises an API gravity.

8009. The method of claim 8005, wherein the selected property of the third mixture comprises a selected viscosity.

8010. The method of claim 8005, wherein the selected property of the third mixture comprises a density.

8011. The method of claim 8005, wherein the selected property of the third mixture comprises an asphaltene to saturated hydrocarbon ratio of less than about 1.

8012. The method of claim 8005, wherein the selected property of the third mixture comprises an aromatic hydrocarbon to saturated hydrocarbon ratio of less than about 4.

8013. The method of claim 8005, wherein asphaltenes are substantially stable in the third mixture at ambient temperature.

8014. The method of claim 8005, wherein the third mixture is transportable.

8015. The method of claim 8005, wherein the third mixture is transportable through a pipeline.

8016. The method of claim 8005, wherein the liquid has a viscosity sufficiently high to inhibit economical transport of the liquid over 100 km via a pipeline but the mixture has a reduced viscosity that allows economical transport of the mixture over 100 km via a pipeline.

8017. The method of claim 8005, wherein the first mixture comprises an API gravity less than about 15°

.

8018. The method of claim 8005, wherein the second mixture comprises an API gravity greater than about 25°

.

8019. The method of claim 8005, wherein the second mixture comprises an acid number less than about 1.

8020. The method of claim 8005, wherein the third mixture comprises less than about 50% by weight of the second mixture.

8021. The method of claim 8005, wherein the first selected section comprises a depth of at least about 500 m below the surface of a relatively permeable formation.

8022. The method of claim 8005, wherein the second selected section comprises a depth less than about 500 m below the surface of a relatively permeable formation.

8023. The method of claim 8005, further comprising producing a mixture when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

8024. The method of claim 8005, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

8025. The method of claim 8005, wherein one or more of the heaters comprise heaters.

8026. The method of claim 8005, wherein a ratio of energy output of the second mixture to energy input into the formation is at least about 5.

8027. A method for treating a relatively permeable formation in situ, comprising:

providing heat from one or more heaters to a selected section of a relatively permeable formation such that the heat pyrolyzes at least some hydrocarbons within the selected section;

producing a blending agent from the selected section; and

injecting at least a portion of the blending agent into a second section of a relatively permeable formation to produce a mixture having a selected property, wherein the second section comprises at least some heavy hydrocarbons.

8028. The method of claim 8027, wherein the selected property of the mixture comprises an API gravity.

8029. The method of claim 8027, wherein the selected property of the mixture comprises an API gravity of at least about 10°

.

8030. The method of claim 8027, wherein the selected property of the mixture comprises a selected viscosity.

8031. The method of claim 8027, wherein the selected property of the mixture comprises a viscosity less than about 7500 cs.

8032. The method of claim 8027, wherein the selected property of the mixture comprises a density.

8033. The method of claim 8027, wherein the selected property of the mixture comprises a density less than about 1 g/cm³.

8034. The method of claim 8027, wherein the selected property of the mixture comprises an asphaltene to saturated hydrocarbon ratio of less than about 1.

8035. The method of claim 8027, wherein the selected property of the mixture comprises an aromatic hydrocarbon to saturated hydrocarbon ratio of less than about 4.

8036. The method of claim 8027, wherein asphaltenes are substantially stable in the mixture at ambient temperature.

8037. The method of claim 8027, wherein the mixture is transportable.

8038. The method of claim 8027, wherein the mixture is transportable through a pipeline.

8039. The method of claim 8027, wherein second section comprises heavy hydrocarbons having an API gravity less than about 15°

.

8040. The method of claim 8027, wherein the blending agent comprises an API gravity greater than about 25°

.

8041. The method of claim 8027, wherein the blending agent comprises an acid number less than about 1.

8042. The method of claim 8027, wherein the mixture comprises less than about 50% by weight of the blending agent.

8043. The method of claim 8027, wherein the selected section comprises a depth of at least about 500 m below the surface of a relatively permeable formation.

8044. The method of claim 8027, wherein the second section comprises a depth less than about 500 m below the surface of a relatively permeable formation.

8045. The method of claim 8027, wherein the selected section and the second section are located in different relatively permeable formations.

8046. The method of claim 8027, wherein the selected section and the second section are located in different relatively permeable formations, and wherein the different relatively permeable formation are vertically displaced.

8047. The method of claim 8027, wherein the selected section and the second section are vertically displaced within a single relatively permeable formation.

8048. The method of claim 8027, wherein the selected section and the second section are substantially adjacent within a single relatively permeable formation.

8049. The method of claim 8027, wherein the blending agent is injected into a production well in the second section, and wherein the mixture is produced in the production well.

8050. The method of claim 8027, further comprising producing the mixture from the second section.

8051. The method of claim 8027, further comprising producing the blending agent when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

8052. The method of claim 8027, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

8053. The method of claim 8027, wherein one or more of the heaters comprise heaters.

8054. The method of claim 8027, wherein a ratio of energy output of the produced mixture to energy input into the formation is at least about 5.

8055. A method for treating a relatively permeable formation in situ, comprising:

providing heat from one or more heaters to at least a portion of the relatively permeable formation;

allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat reduces the viscosity of at least some hydrocarbons within the selected section;

producing the mixture from the selected section; and

adjusting a parameter for producing the desired mixture based on at least one price characteristic of the desired mixture.

8056. The method of claim 8055, further comprising allowing the heat to transfer from the one or more heaters to a selected section of the formation such that the heat pyrolyzes at least some hydrocarbons within the selected section.

8057. The method of claim 8055, wherein adjusting the parameter comprises selecting a location in the selected section for production of the mixture based on at least one price characteristic of the mixture.

8058. The method of claim 8055, wherein adjusting the parameter comprises selecting a production location in the selected section to produce a selected API gravity in the produced mixture.

8059. The method of claim 8055, wherein at least one price characteristic is determined by multiplying a production rate of the produced mixture at a selected API gravity from the selected section by a price obtainable for selling the produced mixture with the selected API gravity.

8060. The method of claim 8055, wherein adjusting the parameter comprises controlling at least one operating condition in the selected section.

8061. The method of claim 8060, wherein controlling at least one operating condition comprises controlling heat output from at least one of the heaters.

8062. The method of claim 8061, wherein controlling the heat output from at least one of the heaters controls a heating rate in the selected section.

8063. The method of claim 8060, wherein controlling at least one operating condition comprises controlling a pressure in the selected section.

8064. The method of claim 8055, wherein at least one price characteristic comprises a characteristic based on a selling price for sulfur produced from the formation.

8065. The method of claim 8055, wherein at least one price characteristic comprises a characteristic based on a selling price for metal produced from the formation.

8066. The method of claim 8055, wherein at least one price characteristic comprises a characteristic based on a ratio of paraffins to aromatics in the mixture.

8067. The method of claim 8055, further comprising producing the mixture when a partial pressure of hydrogen in the formation is at least about 0.5 bars absolute.

8068. The method of claim 8055, wherein the heat provided from at least one heater is transferred to at least a portion of the formation substantially by conduction.

8069. The method of claim 8055, wherein one or more of the heaters comprise heaters.

8070. The method of claim 8055, wherein a ratio of energy output of the produced mixture to energy input into the formation is at least about 5.

8071. The method of claim 8055, wherein the produced mixture comprises an acid number less than about 1.

8072. A method for forming at least one opening in a geological formation, comprising:

forming a portion of an opening in the formation;

providing an acoustic wave to at least a portion of the formation, wherein the acoustic wave is configured to propagate between at least one geological discontinuity of the formation and at least a portion of the opening;

sensing at least one reflection of the acoustic wave in at least a portion of the opening;

using the sensed reflection to assess an approximate location of at least a portion of the opening in the formation; and

forming an additional portion of the opening based on, at least in part, the assessed approximate location of at least a portion of the opening.

8073. The method of claim 8072, further comprising using the sensed reflection to maintain an approximate desired location of the opening between an overburden of the formation and an underburden of the formation.

8074. The method of claim 8072, wherein at least one geological discontinuity comprises a boundary of the formation.

8075. The method of claim 8072, further comprising using the sensed reflection to maintain the location of the opening at approximately midway between an overburden of the formation and an underburden of the formation.

8076. The method of claim 8072, further comprising producing the acoustic wave using a monopole or dipole source.

8077. The method of claim 8072, further comprising sensing the reflection of the acoustic wave using one or more sensors in at least a portion of the opening.

8078. The method of claim 8072, further comprising producing the acoustic wave using a source for producing the acoustic wave in at least a portion of the opening.

8079. The method of claim 8072, further comprising producing the acoustic wave using a source for producing the acoustic wave in at least a portion of the opening, and sensing the acoustic wave using one or more sensors in at least a portion of the opening.

8080. The method of claim 8072, further comprising sensing the reflection of the acoustic wave during formation of at least a portion of the opening in the formation.

8081. The method of claim 8072, further comprising using a calculated or assessed acoustic velocity in the formation when using the sensed reflection to assess the location of the opening in the formation.

8082. The method of claim 8072, further comprising propagating an acoustic wave between an overburden of the formation and the opening.

8083. The method of claim 8072, further comprising propagating an acoustic wave between an underburden of the formation and the opening.

8084. The method of claim 8072, further comprising propagating an acoustic wave between an overburden of the formation and the opening, and an underburden of the formation and the opening.

8085. The method of claim 8072, further comprising using information from the sensed acoustic wave to, at least in part, guide a drilling system in forming the opening.

8086. The method of claim 8072, further comprising substantially simultaneously providing acoustic waves, sensing reflected acoustic waves, and using information from the sensed acoustic waves to, at least in part, guide a drilling system in forming the opening.

8087. The method of claim 8072, further comprising using information from the sensed acoustic wave to, at least in part, substantially simultaneously guide a drilling system in forming the opening.

8088. The method of claim 8072, further comprising using information from the sensed acoustic wave to assess a location of at least a part of the opening, and then using such assessed location to, at least in part, guide a drilling system in forming the opening.

8089. The method of claim 8072, further comprising using information from the sensed acoustic waves to assess locations of parts of the opening, and then using such assessed locations to, at least in part, guide a drilling system in forming the opening.

8090. The method of claim 8072, wherein a first opening is formed using the sensed acoustic wave, and further comprising forming one or more additional openings by using magnetic tracking to form one or more additional openings at a selected approximate distance from the first opening.

8091. The method of claim 8072, further comprising assessing an approximate orientation of the opening with an inclinometer.

8092. The method of claim 8072, further comprising assessing an approximate location of the opening relative to a second opening in the formation by detecting one or more magnetic fields produced from the second opening.

8093. The method of claim 8072, further comprising assessing an approximate location of the opening relative to a second opening in the formation by detecting one or more magnetic fields produced from the second opening with a magnetometer.

8094. The method of claim 8072, further comprising assessing an approximate location of the opening relative to a second opening in the formation by detecting one or more magnetic fields produced from the second opening so that the opening is formed at an approximate desired distance from the second opening.

8095. The method of claim 8072, wherein the formation comprising hydrocarbons, and further comprising heating at least a portion of the formation, and pyrolyzing at least some hydrocarbons in the formation.

8096. The method of claim 8072, further comprising heating at least a portion of the formation, and controlling a pressure and a temperature within at least a part of the formation, wherein the pressure is controlled as a function of temperature, and/or the temperature is controlled as a function of pressure.

8097. The method of claim 8072, further comprising heating at least a portion of the formation, and producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8098. The method of claim 8072, further comprising heating at least a portion of the formation, controlling a pressure within at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8099. The method of claim 8072, further comprising heating at least a portion of the formation, and controlling formation conditions such that a produced mixture comprises a partial pressure of H₂ within the mixture greater than about 0.5 bars.

8100. The method of claim 8072, further comprising heating at least a portion of the formation, and altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

8101. The method of claim 8072, further comprising heating at least a portion of the formation to a minimum pyrolysis temperature of about 270°

C.

8102. A method for heating a hydrocarbon containing formation, comprising:

providing heat to the formation from one or more heaters in one or more openings in the formation, wherein at least one of the openings has been formed by;

forming a portion of an opening in the formation;

providing an acoustic wave to at least a portion of the formation, wherein the acoustic wave is configured to propagate between at least one geological discontinuity of the formation and at least a portion of the opening;

sensing at least one reflection of the acoustic wave in at least a portion of the opening; and

using the sensed reflection to assess an approximate location of at least a portion of the opening in the formation.

8103. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, the assessed approximate location of at least a portion of the opening.

8104. The method of claim 8102, wherein at least one portion of an opening has been formed using the sensed reflection to maintain an approximate desired location of the opening between an overburden of the formation and an underburden of the formation.

8105. The method of claim 8102, wherein at least one geological discontinuity comprises a boundary of the formation.

8106. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, using the sensed reflection to maintain the location of the opening at approximately midway between an overburden of the formation and an underburden of the formation.

8107. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, producing the acoustic wave using a monopole or dipole source.

8108. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, sensing the reflection of the acoustic wave using one or more sensors in at least a portion of the opening.

8109. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, producing the acoustic wave using a source for producing the acoustic wave in at least a portion of the opening.

8110. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, producing the acoustic wave using a source for producing the acoustic wave in at least a portion of the opening, and sensing the acoustic wave using one or more sensors in at least a portion of the opening.

8111. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, sensing the reflection of the acoustic wave during formation of at least a portion of the opening in the formation.

8112. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, using a calculated or assessed velocity in the formation when using the sensed reflection to assess the location of the opening in the formation.

8113. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, propagating an acoustic wave between an overburden of the formation and the opening.

8114. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, propagating an acoustic wave between an underburden of the formation and the opening.

8115. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, propagating an acoustic wave between an overburden of the formation and the opening, and an underburden of the formation and the opening.

8116. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, using information from the sensed acoustic wave to, at least in part, guide a drilling system in forming the opening.

8117. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, substantially simultaneously providing acoustic waves, sensing reflected acoustic waves, and using information from the sensed acoustic waves to, at least in part, guide a drilling system in forming the opening.

8118. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, using information from the sensed acoustic wave to, at least in part, substantially simultaneously guide a drilling system in forming the opening.

8119. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, using information from the sensed acoustic wave to assess a location of at least a part of the opening, and then using such assessed location to, at least in part, guide a drilling system in forming the opening.

8120. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, using information from the sensed acoustic waves to assess locations of parts of the opening, and then using such assessed locations to, at least in part, guide a drilling system in forming the opening.

8121. The method of claim 8102, wherein at least one portion of an opening has been formed based on, at least in part, using the sensed acoustic wave, and further comprising forming one or more additional openings by using magnetic tracking to form one or more additional openings at a selected approximate distance from the first opening.

8122. The method of claim 8102, further comprising assessing an approximate orientation of the opening with an inclinometer.

8123. The method of claim 8102, further comprising assessing an approximate location of the opening relative to a second opening in the formation by detecting one or more magnetic fields produced from the second opening.

8124. The method of claim 8102, further comprising assessing an approximate location of the opening relative to a second opening in the formation by detecting one or more magnetic fields produced from the second opening with a magnetometer.

8125. The method of claim 8102, further comprising assessing an approximate location of the opening relative to a second opening in the formation by detecting one or more magnetic fields produced from the second opening so that the opening is formed at an approximate desired distance from the second opening.

8126. The method of claim 8102, further comprising pyrolyzing at least some hydrocarbons in the formation.

8127. The method of claim 8102, further comprising controlling a pressure and a temperature within at least a part of the formation, wherein the pressure is controlled as a function of temperature, and/or the temperature is controlled as a function of pressure.

8128. The method of claim 8102, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8129. The method of claim 8102, further-comprising controlling a pressure within at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8130. The method of claim 8102, further comprising controlling formation conditions such that a produced mixture comprises a partial pressure of H₂ within the mixture greater than about 0.5 bars.

8131. The method of claim 8102, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25°

.

8132. The method of claim 8102, further comprising heating at least a portion of the formation to a minimum pyrolysis temperature of about 270°

C.

8133. A method for forming one or more openings in a hydrocarbon containing formation, comprising:

forming a first opening in the formation;

providing a plurality of magnets to the first opening, wherein the plurality of magnets is positioned along at least a portion of the first opening, and wherein the plurality of magnets produces a series of magnetic fields along at least the portion of the first opening; and

forming a second opening in the formation using one or more of the series of magnetic fields such that the second opening is spaced at an approximate desired distance from the first opening.

8134. The method of claim 8133, wherein the plurality of magnets comprises a magnetic string.

8135. The method of claim 8133, further comprising using magnetic tracking of one or more of the series of magnetic fields to space the second opening at an approximate desired distance from the first opening.

8136. The method of claim 8133, further comprising using a magnetometer in the second opening, and one or more of the magnetic fields, to space the second opening at an approximate desired distance from the first opening.

8137. The method of claim 8133, further comprising using a magnetometer and an inclinometer in the second opening, and one or more of the magnetic fields, to space the second opening at an approximate desired distance from the first opening.

8138. The method of claim 8133, wherein the plurality of magnets comprises magnets, and wherein the magnets comprise aluminum, cobalt, and nickel.

8139. The method of claim 8133, wherein the plurality of magnets is positioned in a casing.

8140. The method of claim 8133, wherein the plurality of magnets is positioned in a ferromagnetic casing.

8141. The method of claim 8133, wherein the plurality of magnets is positioned in a heater casing.

8142. The method of claim 8133, wherein the plurality of magnets is positioned in a perforated casing.

8143. The method of claim 8133, wherein at least a portion of the plurality of magnets is placed in a conduit.

8144. The method of claim 8133, wherein the plurality of magnets comprises at least two junctions of opposing poles of opposite polarity separated by a selected distance.

8145. The method of claim 8133, wherein the plurality of magnets comprises at least two junctions of opposing poles of opposite polarity separated by a selected distance, and wherein the selected distance is substantially similar to the desired distance between the first opening and the second opening.

8146. The method of claim 8133, wherein the plurality of magnets comprises at least two junctions of opposing poles of opposite polarity separated by a selected distance, and wherein the selected distance is greater than about 1 m and less than about 500 m.

8147. The method of claim 8133, wherein the plurality of magnets comprises at least two magnetic segments that are positioned such that opposing poles from each magnetic segment are substantially adjacent to one another, thereby forming a junction of opposing poles.

8148. The method of claim 8133, further comprising moving the plurality of magnets in the first opening to vary at least one magnetic field with time.

8149. The method of claim 8133, further comprising moving the plurality of magnets in the first opening to increase a length of the second opening.

8150. The method of claim 8133, further comprising forming a plurality of openings proximate to the first opening.

8151. The method of claim 8133, wherein the first opening is a substantially vertical opening, and wherein the second opening is a substantially horizontal opening that passes the first opening at a selected distance from the first opening and at a selected depth in the formation.

8152. The method of claim 8133, wherein the first opening comprises a non-ferromagnetic casing.

8153. The method of claim 8133, wherein the series of the magnetic fields comprises a first magnetic field and a second magnetic field and wherein a strength of the first magnetic field differs from a strength of the second magnetic field.

8154. The method of claim 8133, wherein the series of the magnetic fields comprises a first magnetic field and a second magnetic field and wherein a strength of the first magnetic field is about the same as a strength of the second magnetic field.

8155. The method of claim 8133, wherein the series of the magnetic fields comprises a pole strength between about 100 Gauss and about 2000 Gauss.

8156. The method of claim 8133, wherein the first opening comprises a center opening in a pattern of openings, the method further comprising forming a plurality of openings in the pattern of openings proximate to the first opening.

8157. The method of claim 8133, wherein the first opening comprises a center opening in a pattern of openings, the method further comprising forming a plurality of openings in the pattern of openings proximate to the first opening, and wherein each of the plurality of openings is spaced at an approximate desired distance from the first opening.

8158. The method of claim 8133, further comprising providing at least one heating mechanism in the first opening and at least one heating mechanism in the second opening such that the heating mechanisms can be used to provide heat to at least a portion of the formation.

8159. The method of claim 8133, wherein a deviation in the spacing between the second opening and the first opening is less than or equal to about ±

1 m.

8160. The method of claim 8133, wherein a deviation in the spacing between the second opening and the first opening is less than or equal to about ±

0.5 m.

8161. The method of claim 8133, further comprising measuring a magnetic field when the plurality of magnets is at a first position, moving the plurality of magnets, measuring a magnetic field when the plurality of magnets is at a second position, and wherein measurements at the two positions are used to calibrate for an effect of other magnetic fields.

8162. The method of claim 8161, wherein at least two positions comprise positions spaced apart by multiples of L/4, and wherein L is a distance between two junctions of opposing poles in the plurality of magnets.

8163. The method of claim 8133, wherein a measurement of the series of magnetic fields is taken at two positions separated by L12 of the plurality of magnets in the first opening to reduce an effect of fixed magnetic fields on a determination of distance between the first opening and the second opening, and wherein L is a distance between two junctions of opposing poles in the plurality of magnets.

8164. The method of claim 8133, wherein the plurality of magnets are positioned in a linear array.

8165. The method of claim 8133, wherein the plurality of magnets is configured so that the plurality of magnets produces a magnetic field when an electric current is applied to the magnets.

8166. The method of claim 8133, wherein at least one heater is placed in at least one opening in the formation, and wherein the heater can be used in a method comprising:

providing heat from the at least one heater to a portion of the formation;

pyrolyzing at least some hydrocarbons in the formation; and

producing a mixture from the formation, wherein the mixture comprises at least some pyrolyzed hydrocarbons.

8167. A method for forming one or more openings in a hydrocarbon containing formation, comprising:

forming a first opening in the formation;

providing a magnetic string to the first opening, wherein the magnetic string is positioned along at least a portion of the first opening, wherein the magnetic string produces two or more magnetic fields, wherein the magnetic string comprises two or more magnetic segments, and wherein at least two magnetic segments are positioned such that opposing poles from each magnetic segment are substantially adjacent to each other, thereby forming a junction of opposing poles; and

forming a second opening in the formation using one or more of the magnetic fields such that the second opening is spaced at an approximate desired distance from the first opening.

8168. The method of claim 8167, wherein at least one magnetic segment comprises a plurality of magnets.

8169. The method of claim 8167, further comprising using magnetic tracking of one or more of the series of magnetic fields to space the second opening at an approximate desired distance from the first opening.

8170. The method of claim 8167, further comprising using a magnetometer in the second opening, and one or more of the magnetic fields, to space the second opening at an approximate desired distance from the first opening.

8171. The method of claim 8167, further comprising using a magnetometer and an inclinometer in the second opening, and one or more of the magnetic fields, to space the second opening at an approximate desired distance from the first opening.

8172. The method of claim 8167, wherein at least one magnetic segment comprises a plurality of Alnico magnets.

8173. The method of claim 8167, wherein at least one magnetic segment comprises a plurality of magnets, and wherein the at least one magnetic segment has one effective north pole and one effective south pole.

8174. The method of claim 8167, wherein a distance between two junctions of opposing poles with opposite polarity is substantially similar to the desired distance between the first opening and the second opening.

8175. The method of claim 8167, wherein a distance between two junctions of opposing poles with opposite polarity is greater than about 1 m and less than about 500 m.

8176. The method of claim 8167, further comprising moving the magnetic string in the first opening.

8177. The method of claim 8167, further comprising moving the magnetic string in the first opening such that at least one of the magnetic fields varies with time.

8178. The method of claim 8167, further comprising moving the magnetic string in the first opening to increase a length of the second opening.

8179. The method of claim 8167, further comprising forming a plurality of openings proximate to the first opening.

8180. The method of claim 8167, wherein the first opening is a substantially vertical opening, and wherein the second opening is a substantially horizontal opening that passes the first opening at a selected distance from the first opening and at a selected depth in the formation.

8181. The method of claim 8167, wherein the first opening comprises a non-ferromagnetic casing.

8182. The method of claim 8167, wherein the magnetic fields comprise a series of magnetic fields, and wherein a strength of a first magnetic field differs from a strength of a second magnetic field.

8183. The method of claim 8167, wherein the magnetic fields comprise a series of magnetic fields, and wherein a strength of a first magnetic field is about the same as a strength of a second magnetic field.

8184. The method of claim 8167, wherein the first opening comprises a center opening in a pattern of openings, the method further comprising forming a plurality of openings in the pattern of openings proximate to the first opening.

8185. The method of claim 8167, wherein the first opening comprises a center opening in a pattern of openings, the method further comprising forming a plurality of openings in the pattern of openings proximate to the first opening, and wherein each of the plurality of openings is spaced at an approximate desired distance from the first opening.

8186. The method of claim 8167, further comprising providing at least one heating mechanism in the first opening and at least one heating mechanism in the second opening such that the heating mechanisms can be used to provide heat to at least a portion of the formation.

8187. The method of claim 8167, wherein the magnetic string is positioned in a conduit.

8188. The method of claim 8167, wherein the magnetic string is positioned in a conduit, and wherein the conduit comprises non-magnetic material.

8189. The method of claim 8167, wherein at least two magnetic segments comprising the junction of opposing poles are positioned in a section of conduit, wherein the section of conduit is coupled to at least one other section of conduit, and at least one other section of conduct comprises at least two magnetic segments comprising opposing poles to produce a junction of opposing poles, and wherein the junction of opposing poles of at least one other section of conduit comprises an opposite polarity of the junction of opposing poles of the section of conduit.

8190. The method of claim 8167, wherein the magnetic string is positioned in a casing.

8191. The method of claim 8167, wherein the magnetic string is positioned in a heater casing.

8192. The method of claim 8167, wherein the magnetic string is positioned in a ferromagnetic casing.

8193. The method of claim 8167, wherein the magnetic string is positioned in a linear array.

8194. The method of claim 8167, wherein a deviation in the spacing between the second opening and the first opening is less than or equal to about ±

1 m.

8195. The method of claim 8167, wherein a deviation in the spacing between the second opening and the first opening is less than or equal to about ±

0.5 m.

8196. The method of claim 8167, further comprising measuring a magnetic field when the magnetic string is at a first position, moving the magnetic string, measuring a magnetic field when the magnetic string is at a second position, and wherein measurements at the two positions are used to calibrate for an effect of other magnetic fields.

8197. The method of claim 8196, wherein the at least two positions comprise positions spaced apart by multiples of L/4, and wherein L is a distance between two junctions of opposing poles in the magnetic string.

8198. The method of claim 8167, wherein a measurement of the series of magnetic fields is taken at two positions separated by L12 of the magnetic string in the first opening to reduce an effect of fixed magnetic fields on a determination of distance between the first opening and the second opening, and wherein L is a distance between two junctions of opposing poles in the magnetic string.

8199. The method of claim 8167, wherein the magnetic string is configured so that the magnetic string produces a magnetic field when an electric current is applied to the magnetic string.

8200. The method of claim 8167, wherein at least one heater is placed in at least one opening in the formation, and wherein the heater can be used in a method comprising:

providing heat from the at least one heater to a portion of the formation;

pyrolyzing at least some hydrocarbons in the formation; and

producing a mixture from the formation, wherein the mixture comprises at least some pyrolyzed hydrocarbons.

8201. A system for drilling openings in a hydrocarbon containing formation, comprising:

a drilling apparatus;

a magnetic string comprising two or more magnetic segments positionable in a conduit, wherein each of the magnetic segments comprises a plurality of magnets; and

a sensor configurable to detect a magnetic field in the formation.

8202. The system of claim 8201, wherein the sensor is coupled to the drilling apparatus.

8203. The system of claim 8201, wherein the magnetic string further comprises one or more fasteners configurable to inhibit movement of the magnetic segments relative to the conduit.

8204. The system of claim 8201, wherein one or more magnetic segments are positioned such that opposing poles from each magnetic segment are substantially adjacent to each, thereby forming a junction of opposing poles.

8205. The system of claim 8201, wherein the magnetic string is positioned in a first opening in the formation and the drilling apparatus is positioned in a second opening in the formation, and wherein a distance between two junctions of opposing poles with opposite polarity in the magnetic string is substantially similar to the desired distance between the first opening and the second opening.

8206. The system of claim 8201, wherein the magnetic string is positionable in at least a portion of an opening in the formation.

8207. The system of claim 8201, wherein the magnetic string is positionable in at least a portion of an opening in the formation and wherein the magnetic string produces a magnetic field in a portion of the formation.

8208. The system of claim 8201, wherein the magnetic string produces a series of magnetic fields along at least a portion of an opening in the formation.

8209. The system of claim 8201, wherein the magnetic string is movable in an opening in the formation.

8210. The system of claim 8201, wherein the magnetic string is positioned in a first opening in the formation and the drilling apparatus is positioned in a second opening in the formation, and wherein a position of the magnetic string in the first opening can be adjusted to increase a length of the second opening.

8211. The system of claim 8201, wherein the conduit comprises non-ferromagnetic material.

8212. The system of claim 8201, wherein the magnetic string is positioned in an opening in the formation, and wherein the opening comprises a casing.

8213. The system of claim 8201, wherein the conduit comprises one or more sections, and wherein each section comprises two magnetic segments.

8214. The system of claim 8201, wherein the conduit comprises one or more sections, and wherein each section comprises two magnetic segments positioned such that the two magnetic segments form a junction of opposing poles approximately at the center of each section.

8215. The system of claim 8201, further comprising a magnetometer coupled to the drilling apparatus, the magnetometer being configured to sense a magnetic field formed by at least one of the magnetic segments.

8216. The system of claim 8201, further comprising a magnetometer and an inclinometer coupled to the drilling apparatus, the magnetometer being configured to sense a magnetic field formed by at least one of the magnetic segments.

8217. The system of claim 8201, further comprising a magnetometer coupled to the drilling apparatus, the magnetometer being configured to sense a magnetic field formed by at least one of the magnetic segments, wherein the system is configured to control the drilling apparatus based on, at least in part, sensed readings from the magnetometer.

8218. The system of claim 8201, further comprising a magnetometer and an inclinometer coupled to the drilling apparatus, the magnetometer being configured to sense a magnetic field formed by at least one of the magnetic segments, wherein the system is configured to control the drilling apparatus based on, at least in part, sensed readings from the magnetometer and the inclinometer.

8219. The system of claim 8201, wherein the magnetic string is positioned in a linear array.

8220. A method for forming more than one wellbore in a hydrocarbon containing formation, comprising:

forming a first wellbore in a formation;

placing a magnetic string in the first wellbore, wherein the magnetic string produces two or more magnetic fields in a portion of the formation;

forming a first set of one or more wellbores proximate to the first wellbore using, at least in part, one or more magnetic fields produced by the magnetic string;

moving the magnetic string from the first wellbore to a wellbore in the first set of one or more wellbores; and

forming a second set of one or more wellbores proximate to the wellbore with the magnetic string.

8221. The method of claim 8220, further comprising forming a third set of one or more wellbores proximate to a wellbore in the second set of one or more wellbores using, at least in part, the magnetic string, wherein the magnetic string has been moved to the wellbore in the second set of one or more wellbores.

8222. The method of claim 8220, further comprising using magnetic tracking of two or more magnetic fields to space a wellbore being formed at an approximate desired distance from the first wellbore.

8223. The method of claim 8220, further comprising using a magnetometer in a wellbore being formed, and at least one magnetic field, to space such wellbore being formed at an approximate desired distance from the first wellbore.

8224. The method of claim 8220, further comprising using a magnetometer and an inclinometer in a wellbore being formed, and at least one magnetic field, to space such wellbore being formed at an approximate desired distance from the first wellbore.

8225. The method of claim 8220, further comprising forming a third set of one or more wellbores proximate to a wellbore in the first set of one or more wellbores using the magnetic string, wherein the magnetic string has been moved to the wellbore in the first set of one or more wellbores, and wherein the wellbore is a different wellbore than the wellbore used to form the second set of one or more wellbores.

8226. The method of claim 8220, further comprising forming a pattern of wellbores in the hydrocarbon containing formation.

8227. The method of claim 8220, further comprising forming a triangular pattern of wellbores in the hydrocarbon containing formation.

8228. The method of claim 8220, further comprising forming a seven spot pattern of wellbores in the hydrocarbon containing formation.

8229. The method of claim 8220, wherein a deviation in a spacing between each of the formed wellbores is less than or equal to about ±

1 m.

8230. The method of claim 8220, wherein a deviation in a spacing between each of the formed wellbores is less than or equal to about ±

0.5 m.

8231. The method of claim 8220, further comprising placing a heating mechanism in a portion of at least one wellbore.

8232. The method of claim 8220, further comprising forming at least one production wellbore in the hydrocarbon containing formation.

8233. The method of claim 8220, wherein at least one heater is placed in at least one wellbore in the formation, and wherein the heater can be used in a method comprising:

providing heat from the at least one heater to a portion of the formation;

pyrolyzing at least some hydrocarbons in the formation; and

producing a mixture from the formation, wherein the mixture comprises at least some pyrolyzed hydrocarbons.

8234. A method for forming one or more openings below the earth'"'"'s surface, comprising:

forming a first opening in the earth'"'"'s surface;

providing at least one movable permanent longitudinal magnet in the first opening, wherein at least one movable permanent longitudinal magnet has a north pole and a south pole, and wherein a longitudinal axis of the magnet is substantially parallel or coaxial with a longitudinal axis of the portion of the first opening that is proximate to the at least one movable permanent longitudinal magnet; and

forming a second opening in the formation using one or more magnetic fields produced by the magnet such that the second opening is spaced at an approximate desired distance from the first opening.

8235. The method of claim 8234, wherein substantially parallel comprises within about 5% of parallel.

8236. The method of claim 8234, further comprising using magnetic tracking of one or more of the magnetic fields to space the second opening at an approximate desired distance from the first opening.

8237. The method of claim 8234, further comprising using a magnetometer in the second opening, and one or more of the magnetic fields, to space the second opening at an approximate desired distance from the first opening.

8238. The method of claim 8234, further comprising using a magnetometer and an inclinometer in the second opening, and one or more of the magnetic fields, to space the second opening at an approximate desired distance from the first opening.

8239. The method of claim 8234, wherein at least one movable permanent longitudinal magnet comprises aluminum, cobalt, and nickel.

8240. The method of claim 8234, wherein at least one movable permanent longitudinal magnet is positioned in a casing.

8241. The method of claim 8234, wherein at least one movable permanent longitudinal magnet is positioned in a ferromagnetic casing.

8242. The method of claim 8234, wherein at least one movable permanent longitudinal magnet is placed in a conduit.

8243. The method of claim 8234, wherein a length of at least one movable permanent longitudinal magnet is substantially similar to the desired distance between the first opening and the second opening.

8244. The method of claim 8234, further comprising moving at least one movable permanent longitudinal magnet in the first opening to vary at least one magnetic field with time.

8245. The method of claim 8234, further comprising moving at least one movable permanent longitudinal magnet in the first opening to increase a length of the second opening.

8246. The method of claim 8234, further comprising forming a plurality of openings proximate to the first opening.

8247. The method of claim 8234, wherein the first opening is a substantially vertical opening, and wherein the second opening is a substantially horizontal opening that passes the first opening at a selected distance from the first opening and at a selected depth in the formation.

8248. The method of claim 8234, wherein the first opening comprises a non-ferromagnetic casing.

8249. The method of claim 8234, wherein the magnetic fields comprise a first magnetic field and a second magnetic field and wherein a strength of the first magnetic field differs from a strength of the second magnetic field.

8250. The method of claim 8234, wherein the magnetic fields comprise a first magnetic field and a second magnetic field and wherein a strength of the first magnetic field is about the same as a strength of the second magnetic field.

8251. The method of claim 8234, wherein the magnetic fields comprise a pole strength between about 100 Gauss and 2000 Gauss.

8252. The method of claim 8234, wherein the first opening comprises a center opening in a pattern of openings, the method further comprising forming a plurality of openings in the pattern of openings proximate to the first opening.

8253. The method of claim 8234, wherein the first opening comprises a center opening in a pattern of openings, the method further comprising forming a plurality of openings in the pattern of openings proximate to the first opening, and wherein each of the plurality of openings is spaced at an approximate desired distance from the first opening.

8254. The method of claim 8234, further comprising providing at least one heating mechanism in the first opening and at least one heating mechanism in the second opening such that the heating mechanisms can be used to provide heat to at least a portion of the formation.

8255. The method of claim 8234, wherein a deviation in the spacing between the second opening and the first opening is less than or equal to about ±

1 m.

8256. The method of claim 8234, wherein a deviation in the spacing between the second opening and the first opening is less than or equal to about +0.5 m.

8257. The method of claim 8234, further comprising measuring a magnetic field when at least one movable permanent longitudinal magnet is at a first position, moving the at least one movable permanent longitudinal magnet, measuring a magnetic field when the at least one movable permanent longitudinal magnet is at a second position, and wherein measurements at the two positions are used to calibrate for an effect of other magnetic fields.

8258. The method of claim 8257, wherein at least two positions comprise positions spaced apart by multiples of L/4, and wherein L is a length of at least one movable permanent longitudinal magnet.

8259. The method of claim 8234, wherein a measurement of the magnetic fields is taken at two positions separated by L/2 along a length of at least one movable permanent longitudinal magnet in.the first opening to reduce an effect of fixed magnetic fields on a determination of distance between the first opening and the second opening, and wherein L is a length of at least one movable permanent longitudinal magnet.

8260. The method of claim 8234, wherein at least one movable permanent longitudinal magnet is positioned in a linear array.

8261. The method of claim 8234, wherein at least one heater is placed in at least one opening in the formation, and wherein the heater can be used in a method comprising:

providing heat from the at least one heater to a portion of the formation;

pyrolyzing at least some hydrocarbons in the formation; and

producing a mixture from the formation, wherein the mixture comprises at least some pyrolyzed hydrocarbons.

8262. A method for forming one or more openings below the earth'"'"'s surface, comprising:

forming a first opening below the earth'"'"'s surface;

providing a conduit in the first opening, wherein the conduit is positioned along at least a portion of the first opening;

providing an electric current to the conduit to produce a magnetic field along at least a portion of the conduit; and

forming a second opening below the earth'"'"'s surface using the magnetic field, wherein the magnetic field is used such that the second opening is spaced at an approximate desired distance from the first opening.

8263. The method of claim 8262, wherein the first opening and the second opening are formed in a hydrocarbon containing formation.

8264. The method of claim 8262, wherein the first opening comprises a first end at a first surface location and a second end at a second surface location.

8265. The method of claim 8262, further comprising using magnetic tracking of the magnetic field to space the second opening at an approximate desired distance from the first opening.

8266. The method of claim 8262, further comprising using a magnetometer in the second opening, and the magnetic field, to space the second opening at an approximate desired distance from the first opening.

8267. The method of claim 8262, further comprising using a magnetometer and an inclinometer in the second opening, and the magnetic field, to space the second opening at an approximate desired distance from the first opening.

8268. The method of claim 8262, wherein the conduit comprises a casing in the first opening.

8269. The method of claim 8262, wherein the conduit is configured to propagate the electric current and, in addition, serve as a barrier in the first opening, or serve to conduct one or more fluids in the first opening.

8270. The method of claim 8262, further comprising coupling an electrical conductor to a first end of the conduit, and coupling an electrical conductor to a second end of the conduit, wherein the electrical conductors are on or proximate the surface of the earth.

8271. The method of claim 8262, further comprising coupling a source of current to the conduit or to an electrical conductor, wherein the electrical conductor is coupled to a first end of the conduit, or to a second end of the conduit, and wherein the electrical conductor is on or proximate the surface of the earth.

8272. The method of claim 8262, wherein the first opening comprises a first end at a first surface location and a second end at a second surface location, and further comprising coupling an electrical conductor to a first end of the conduit, and coupling an electrical conductor to a second end of the conduit, and wherein the electrical conductors are on or proximate the surface of the earth.

8273. The method of claim 8262, wherein the first opening comprises a first end at a first surface location and a second end at a second surface location, and further comprising coupling a source of current to the conduit or to an electrical conductor, wherein the electrical conductor is coupled to a first end of the conduit, or to a second end of the conduit, wherein the electrical conductor is on or proximate the surface of the earth.

8274. The method of claim 8262, further comprising grounding the electrical current below the earth'"'"'s surface.

8275. The method of claim 8262, wherein the second opening comprises a first end at a first surface location and a second end at a second surface location.

8276. The method of claim 8262, wherein the electrical current is provided in a forward direction through the conduit for a first time period to produce a first magnetic field, and then the current is provided in a reverse direction through the conduit for a second time period to produce a second magnetic field, and wherein subtraction between the first and second magnetic fields reduces an effect from fixed magnetic fields.

8277. The method of claim 8262, wherein the electrical current is provided from a DC current source.

8278. The method of claim 8262, wherein an electro-insulating material is placed on at least a portion of the conduit.

8279. The method of claim 8262, wherein an electro-insulating material is placed on at least a portion of the conduit, and wherein the electro-insulating material is adapted to melt, vaporize, and/or oxidize when heated.

8280. The method of claim 8262, wherein the conduit is a heater conduit configured to provide or transfer heat to at least a portion of a hydrocarbon containing formation.

8281. The method of claim 8262, further comprising forming a plurality of openings in the vicinity of the first opening.

8282. The method of claim 8262, further comprising forming a third opening below the earth'"'"'s surface using the magnetic field such that the third opening is spaced at an approximate desired distance from the first opening or the second opening.

8283. The method of claim 8262, further comprising forming a third opening below the earth'"'"'s surface using the magnetic field such that the third opening is spaced at an approximate desired distance from the first opening, and wherein the desired distance between the first opening and the third opening is about 1.5 to 3 times the desired distance between the first opening and the second opening.

8284. The method of claim 8262, wherein the first opening is a center opening in a pattern of openings, the method further comprising forming a plurality of openings in the pattern of openings proximate to the first opening.

8285. The method of claim 8262, wherein the first opening is a center opening in a pattern of openings, the method further comprising forming a plurality of openings in the pattern of openings proximate to the first opening, and wherein each of the plurality of openings is spaced at an approximate desired distance from the first opening.

8286. The method of claim 8262, further comprising providing at least one heating mechanism in the first opening and at least one heating mechanism in the second opening such that the heating mechanisms can be used to provide heat to at least a portion of a hydrocarbon containing formation.

8287. The method of claim 8262, wherein a deviation in the spacing between the second opening and the first opening is less than or equal to about ±

1 m.

8288. The method of claim 8262, wherein a deviation in the spacing between the second opening and the first opening is less than or equal to about ±

0.5 m.

8289. The method of claim 8262, wherein at least one heater is placed in at least one opening in a hydrocarbon containing formation, and wherein the heater can be used in a method comprising:

providing heat from the at least one heater to a portion of the formation;

pyrolyzing at least some hydrocarbons in the formation; and

producing a mixture from the formation, wherein the mixture comprises at least some pyrolyzed hydrocarbons.

8290. A method for forming a wellbore and installing a heater in a hydrocarbon containing formation, comprising:

forming an opening in the formation, wherein the opening comprises a first end that contacts the earth'"'"'s surface at a first location and a second end that contacts the earth'"'"'s surface at a second location; and

placing a heater in or coupled to the opening, wherein the heater is configured to provide or transfer heat to at least a portion of the formation to pyrolyze at least some hydrocarbons in the formation.

8291. The method of claim 8290, wherein the opening comprises a portion that is formed substantially horizontally in a hydrocarbon layer of the formation.

8292. The method of claim 8290, further comprising forming the first end of the opening at an angle with respect to the earth'"'"'s surface, wherein the angle is between about 50 and about 20°

.

8293. The method of claim 8290, further comprising forming the second end of the opening at an angle with respect to the earth'"'"'s surface, wherein the angle is between about 5°

and about 20°

.

8294. The method of claim 8290, wherein the first end and the second end of the opening comprise portions of the opening located substantially in the overburden of the formation.

8295. The method of claim 8290, wherein the first end and the second end of the opening comprise portions of the opening located substantially in the overburden of the formation, the method further comprising placing reinforcing material in the portions of the opening in the overburden.

8296. The method of claim 8290, wherein forming the opening comprises drilling an opening from the first end of the opening towards the second end of the opening using machinery located at the first end of the opening.

8297. The method of claim 8290, further comprising reaming out the opening.

8298. The method of claim 8290, wherein the heater is placed in the opening by pulling the heater from the second end of the opening towards the first end of the opening with machinery located at the first end of the opening.

8299. The method of claim 8290, wherein the heater is coupled to a drill bit used to form the opening, and wherein the heater is placed in the opening by pulling the heater coupled to the drill bit from the second end of the opening towards the first end of the opening with machinery located at the first end of the opening.

8300. The method of claim 8290, wherein the heater is laid out on the surface of the formation before the heater is placed in the opening.

8301. The method of claim 8290, wherein the heater is unspooled on the surface of the formation as the heater is placed in the opening.

8302. The method of claim 8290, further comprising reaming out the opening while pulling a heater from the second end of the opening towards the first end of the opening with machinery located at the first end of the opening.

8303. The method of claim 8290, wherein the heater comprises at least one oxidizer located in the opening.

8304. The method of claim 8290, wherein the heater comprises at least one oxidizer located on the surface, and coupled to the opening.

8305. The method of claim 8290, further comprising forming a second opening in the formation using, at least in part, a magnetic field produced in the opening in the formation, wherein the second opening comprises a first end that contacts the earth'"'"'s surface at a first location and a second end that contacts the earth'"'"'s surface at a second location.

8306. A method of treating a hydrocarbon containing formation in situ, comprising:

providing heat from one or more heaters placed in, or coupled to, one or more openings in the formation to at least one part of the formation, wherein at least one opening comprises a first end that contacts the earth'"'"'s surface at a first location and a second end that contacts the earth'"'"'s surface at a second location;

allowing the heat to transfer from the one or more heaters to a part of the formation to substantially pyrolyze at least a portion of the formation; and

producing a mixture from the formation, wherein the mixture comprises at least some pyrolyzation products.

8307. The method of claim 8306, wherein at least one opening has been formed by drilling the opening from the first end of the opening towards the second end of the opening using machinery located at the first end of the opening.

8308. The method of claim 8306, wherein at least one heater is placed in at least one opening by pulling the heater from the second end of the opening towards the first end of the opening with machinery located at the first end of the opening.

8309. The method of claim 8306, wherein at least one heater is coupled to a drill bit used to form at least one opening, and wherein the at least one heater is placed in the at least one opening by pulling the heater coupled to the drill bit from the second end of the opening towards the first end of the opening with machinery located at the first end of the opening.

8310. The method of claim 8306, wherein at least one opening comprises a portion that is formed substantially horizontally in a hydrocarbon layer of the formation.

8311. The method of claim 8306, wherein the first end of the opening is formed at an angle with respect to the earth'"'"'s surface, and wherein the angle is between about 5°

and about 20°

.

8312. The method of claim 8306, wherein the second end of the opening is formed at an angle with respect to the earth'"'"'s surface, and wherein the angle is between about 5°

and about 20°

.

8313. The method of claim 8306, further comprising maintaining a temperature in at least a portion of the formation in a pyrolysis temperature range with a lower pyrolysis temperature of about 250°

C. and an upper pyrolysis temperature of about 400°

C.

8314. The method of claim 8306, further comprising heating at least a part of the formation to substantially pyrolyze at least a majority of the hydrocarbons in the formation in a selected section of the formation.

8315. The method of claim 8306, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

8316. The method of claim 8306, wherein allowing the heat to transfer from the one or more heaters to the part of the formation comprises transferring heat substantially by conduction.

8317. The method of claim 8306, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8318. The method of claim 8306, further comprising controlling a pressure in at least a majority of a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8319. The method of claim 8306, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H₂ in the mixture greater than about 0.5 bars.

8320. A system configurable to heat a hydrocarbon containing formation, comprising:

a container configurable to be placed in an opening in the formation, wherein the container is configurable to be pressurized to inhibit deformation of the container during use;

a conductor configurable such that at least a portion of the conductor can be placed in the container, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use; and

wherein the system is configurable to allow heat to transfer from the conductor to a section of the formation during use.

8321. The system of claim 8320, further comprising a lead-in conductor configurable to be electrically coupled to the conductor during use, wherein the lead-in conductor is further configurable to be at least partially placed in the formation overburden.

8322. The system of claim 8320, further comprising a lead-in conductor configurable to be electrically coupled to the conductor during use, wherein the lead-in conductor is further configurable supply electrical power to the conductor during use.

8323. The system of claim 8320, further comprising a lead-in conductor configurable to be electrically coupled to the conductor during use, and a feedthrough configurable to allow the lead-in conductor to pass through the container.

8324. The system of claim 8320, further comprising a lead-in conductor configurable to be electrically coupled to the conductor during use, wherein the lead-in conductor is at least partially insulated and comprises copper.

8325. The system of claim 8320, further comprising a seal on the container configurable to enclose at least a portion of the conductor in the container, wherein the seal is further configurable to maintain a pressure in the container.

8326. The system of claim 8320, further comprising a lead-out conductor configurable to be coupled to the container.

8327. The system of claim 8320, further comprising a lead-out conductor configurable to be coupled to the container, wherein the lead-out conductor comprises an insulated copper conductor.

8328. The system of claim 8320, wherein the system is further configurable to pyrolyze at least some hydrocarbons in the heated section of the formation during use.

8329. The system of claim 8320, wherein the container comprises a conduit.

8330. The system of claim 8320, wherein the system is configured to heat a hydrocarbon containing formation, the system comprising:

a container placed in an opening in the formation, wherein the conduit is pressurized to inhibit deformation of the container during use;

a conductor at least partially in the container, wherein the conductor is further configured to provide heat to at least a portion of the formation during use; and

wherein the system is configured to allow heat to transfer from the conductor to a section of the formation during use.

8331. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to a conductor to provide heat to at least a portion of the formation, wherein the conductor is at least partially placed in a container, wherein the container is in an opening in the formation, and wherein the container is pressurized to inhibit deformation of the container;

allowing the heat to transfer from the conductor to at least a part of the formation.

8332. The method of claim 8331, wherein a lead-in conductor is electrically coupled to the conductor, and wherein the lead-in conductor is at least partially in the formation overburden.

8333. The method of claim 8331, wherein the container comprises a conduit.

8334. The method of claim 8331, further comprising supplying electrical power to the conductor through a lead-in conductor electrically coupled to the conductor.

8335. The method of claim 8331, wherein a lead-in conductor is electrically coupled to the conductor, and wherein the lead-in conductor is at least partially insulated and comprises copper.

8336. The method of claim 8331, further comprising enclosing the conductor in the conduit with a seal on the conduit, wherein the seal maintains a pressure in the conduit.

8337. The method of claim 8331, further comprising pyrolyzing at least some hydrocarbons in the formation.

8338. The method of claim 8331, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature.

8339. The method of claim 8331, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the temperature is controlled as a function of pressure.

8340. The method of claim 8331, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8341. The method of claim 8331, further comprising controlling a pressure in at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8342. The method of claim 8331, further comprising controlling formation conditions such that a produced mixture comprises a partial pressure of H₂ in the mixture greater than about 0.5 bars.

8343. The method of claim 8331, further comprising altering a pressure in the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

8344. The method of claim 8331, wherein at least a portion of the part of the formation is heated to a minimum pyrolysis temperature of about 270°

C.

8345. A system configurable to heat a hydrocarbon containing formation, comprising:

a conduit configurable to be placed in an opening in the formation;

a conductor configurable to be at least partially placed in a conduit, wherein the conductor is further configurable to provide heat to at least a portion of the formation during use;

a sliding connector configurable to be coupled to the conductor and the conduit, wherein the sliding connector is configurable to electrically couple the conduit to a lead-out conductor; and

wherein the system is configurable to allow heat to transfer from the conductor to a section of the formation during use.

8346. The system of claim 8345, further comprising one or more insulators configurable to electrically insulate the conductor from the conduit.

8347. The system of claim 8345, further comprising one or more ceramic insulators configurable to electrically insulate the conductor from the conduit.

8348. The system of claim 8345, further comprising a lead-in conductor configurable to be electrically coupled to the conductor during use, wherein the lead-in conductor is further configurable to be at least partially placed in the formation overburden.

8349. The system of claim 8345, further comprising a lead-in conductor configurable to be electrically coupled to the conductor during use, wherein the lead-in conductor is further configurable supply electrical power to the conductor during use.

8350. The system of claim 8345, wherein the lead-out conductor comprises an insulated copper conductor.

8351. The system of claim 8345, wherein the system is further configurable to pyrolyze at least some hydrocarbons in the heated section of the formation during use.

8352. The system of claim 8345, wherein the system is configured to heat a hydrocarbon containing formation, the system comprising:

a conduit placed in an opening in the formation;

a conductor placed in a conduit, wherein the conductor is further configured to provide heat to at least a portion of the formation during use;

a sliding connector coupled to the conductor and the conduit, wherein the sliding connector electrically couples the conduit to a lead-out conductor; and

wherein the system is configured to allow heat to transfer from the conductor to a section of the formation during use.

8353. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to a conductor to provide heat to at least a portion of the formation, wherein the conductor is at least partially placed in a conduit, wherein a sliding connector is coupled to the conductor and the conduit, and wherein the sliding connector electrically couples the conduit to a lead-out conductor; and

allowing the heat to transfer from the conductor to at least a part of the formation.

8354. The method of claim 8353, wherein the sliding connector is electrically insulated from the conductor with one or more insulators.

8355. The method of claim 8353, wherein a lead-in conductor is electrically coupled to the conductor, and wherein the lead-in conductor is least partially placed in the formation overburden.

8356. The method of claim 8353, further comprising supplying electrical power to the conductor through a lead-in conductor electrically coupled to the conductor.

8357. The method of claim 8353, wherein the lead-out conductor comprises an insulated copper conductor.

8358. The method of claim 8353, further comprising pyrolyzing at least some hydrocarbons in the formation.

8359. The method of claim 8353, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature.

8360. The method of claim 8353, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the temperature is controlled as a function of pressure.

8361. The method of claim 8353, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8362. The method of claim 8353, further comprising controlling a pressure in at least a majority of the part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8363. The method of claim 8353, further comprising controlling formation conditions such that a produced mixture comprises a partial pressure of H₂ in the mixture greater than about 0.5 bars.

8364. The method of claim 8353, further comprising altering a pressure in the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

8365. The method of claim 8353, wherein at least a portion of the part of the formation is heated to a minimum pyrolysis temperature of about 270°

C.

8366. The method of claim 8353, wherein the sliding connector is at least partially flexible.

8367. A system configured to heat at least a part of a hydrocarbon containing formation, comprising:

a conductor configurable to be placed within an opening in the formation, wherein the conductor is further configurable to provide heat to at least a part of the formation during use;

a first electrically conductive material configurable to be coupled to at least a portion of the conductor, wherein the first electrically conductive material is configurable to lower an electrical resistance of at least part of the conductor when such conductor is in formation overburden during use; and

wherein the system is configurable to allow heat to transfer from the conductor to at least a part of the formation during use.

8368. The system of claim 8367, wherein the conductor is configured to be placed in a conduit, and the conduit is configurable to be placed in the opening in the formation.

8369. The system of claim 8368, further comprising a second electrically conductive material configurable to be coupled to at least a portion of an inside surface of the conduit.

8370. The system of claim 8367, further comprising a low resistance conductor configurable to be electrically coupled to the conductor during use, wherein the substantially low resistance conductor is further configurable to be placed within the formation overburden.

8371. The system of claim 8369, wherein the low resistance conductor comprises carbon steel.

8372. The system of claim 8367, wherein the electrically conductive material comprises metal tubing or strips configurable to be clad, at least in part, to the conductor.

8373. The system of claim 8367, wherein the electrically conductive material comprises metal tubing or strips configurable to be clad, at least in part, to an electrically conductive coating configurable to be applied to the conductor.

8374. The system of claim 8367, wherein the electrically conductive material comprises metal tubing or strips configurable to be clad, at least in part, to a thermal plasma applied coating.

8375. The system of claim 8367, wherein the electrically conductive material comprises aluminum.

8376. The system of claim 8367, wherein the electrically conductive material comprises copper.

8377. The system of claim 8367, wherein the electrically conductive material is configurable to reduce the electrical resistance of the conductor in the overburden by a factor of greater than about 3.

8378. The system of claim 8367, wherein the electrically conductive material is configurable to reduce the electrical resistance of the conductor in the overburden by a factor of greater than about 10.

8379. The system of claim 8367, wherein the electrically conductive material is configurable to reduce the electrical resistance of the conductor in the overburden by a factor of greater than about 15.

8380. The system of claim 8367, wherein the system is further configurable to pyrolyze at least some hydrocarbons in the heated section of the formation during use.

8381. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to a conductor to provide heat to at least a portion of the formation, wherein the conductor is configurable to be placed within an opening in the formation, wherein at least part of the conductor is coupled to a first electrically conductive material to lower a resistance of the part of the conductor in a formation overburden; and

allowing the heat to transfer from the conductor to at least a part of the formation.

8382. The method of claim 8381, further comprising placing the conductor in a conduit, wherein the conduit is configurable to be placed in the opening in the formation.

8383. The method of claim 8382, further comprising coupling a second electrically conductive material to at least a portion of an inside surface of the conduit.

8384. The method of claim 8381, further comprising reducing the electrical resistance of the conductor in the overburden by a factor of greater than about 3 with the electrically conductive material.

8385. The method of claim 8381, further comprising reducing the electrical resistance of the conductor in the overburden by a factor of greater than about 10 with the electrically conductive material.

8386. The method of claim 8381, further comprising reducing the electrical resistance of the conductor in the overburden by a factor of greater than about 15 with the electrically conductive material.

8387. The method of claim 8381, further comprising pyrolyzing at least some hydrocarbons within the formation.

8388. The method of claim 8381, further comprising controlling a pressure and a temperature within at least a majority of the part of the formation, wherein the pressure is controlled as a function of temperature.

8389. The method of claim 8381, further comprising controlling a pressure and a temperature within at least a majority of the part of the formation, wherein the temperature is controlled as a function of pressure.

8390. The method of claim 8381, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8391. The method of claim 8381, further comprising controlling a pressure within at least a majority of the part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8392. The method of claim 8381, further comprising controlling formation conditions such that a produced mixture comprises a partial pressure of H₂ within the mixture greater than about 0.5 bars.

8393. The method of claim 8381, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

8394. The method of claim 8381, wherein at least a portion of the part of the formation is heated to a minimum pyrolysis temperature of about 270°

C.

8395. A system configurable to heat a hydrocarbon containing formation, comprising:

a conduit configured to be placed within an opening in the formation;

a conductor configured to be placed within a conduit, wherein the conductor is further configured to provide heat to at least a portion of the formation during use;

an electrically conductive material configured to be electrically coupled to the conductor, wherein the electrically conductive material is further configured to propagate a majority of electrical current, in the overburden, provided to the conductor during use; and

wherein the system is configured to allow heat to transfer from the conductor to a section of the formation during use.

8396. The system of claim 8395, further comprising a second electrically conductive material configurable to be coupled to at least a portion of an inside surface of the conduit.

8397. The system of claim 8395, further comprising a low resistance conductor configurable to be electrically coupled to the conductor during use, wherein the substantially low resistance conductor is further configurable to be placed within the formation overburden.

8398. The system of claim 8397, wherein the low resistance conductor comprises carbon steel.

8399. The system of claim 8395, wherein the electrically conductive material comprises metal tubing or strips configurable to be clad, at least in part, to the conductor.

8400. The system of claim 8395, wherein the electrically conductive material comprises metal tubing or strips configurable to be clad, at least in part, to an electrically conductive coating configurable to be applied to the conductor.

8401. The system of claim 8395, wherein the electrically conductive material comprises metal tubing or strips configurable to be clad, at least in part, to a thermal plasma applied coating.

8402. The system of claim 8395, wherein the electrically conductive material comprises aluminum.

8403. The system of claim 8395, wherein the electrically conductive material comprises copper.

8404. The system of claim 8395, wherein the electrically conductive material is configurable to reduce the electrical resistance of the conductor in the overburden by a factor of greater than about 3.

8405. The system of claim 8395, wherein the electrically conductive material is configurable to reduce the electrical resistance of the conductor in the overburden by a factor of greater than about 10.

8406. The system of claim 8395, wherein the electrically conductive material is configurable to reduce the electrical resistance of the conductor in the overburden by a factor of greater than about 15.

8407. The system of claim 8395, wherein the system is further configurable to pyrolyze at least some hydrocarbons in the heated section of the formation during use.

8408. An in situ method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to a conductor to provide heat to at least a portion of the formation, wherein the conductor is configurable to be placed within a conduit, wherein the conduit is configurable to be placed in an opening in the formation, wherein at least part of the conductor in a formation overburden is coupled to a first electrically conductive material so that a majority of the electrical current provided to the conductor flows through the first electrically conductive material in the formation overburden; and

allowing the heat to transfer from the conductor to at least a part of the formation.

8409. The method of claim 8408, further comprising coupling a second electrically conductive material to at least a portion of an inside surface of the conduit.

8410. The method of claim 8408, further comprising reducing the electrical resistance of the conductor in the overburden by a factor of greater than about 3 with the electrically conductive material.

8411. The method of claim 8408, further comprising reducing the electrical resistance of the conductor in the overburden by a factor of greater than about 10 with the electrically conductive material.

8412. The method of claim 8408, further comprising reducing the electrical resistance of the conductor in the overburden by a factor of greater than about 15 with the electrically conductive material.

8413. The method of claim 8408, further comprising pyrolyzing at least some hydrocarbons within the formation.

8414. The method of claim 8408, further comprising controlling a pressure and a temperature within at least a majority of the part of the formation, wherein the pressure is controlled as a function of temperature.

8415. The method of claim 8408, further comprising controlling a pressure and a temperature within at least a majority of the part of the formation, wherein the temperature is controlled as a function of pressure.

8416. The method of claim 8408, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8417. The method of claim 8408, further comprising controlling a pressure within at least a majority of the part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8418. The method of claim 8408, further comprising controlling formation conditions such that a produced mixture comprises a partial pressure of H₂ within the mixture greater than about 0.5 bars.

8419. The method of claim 8408, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

8420. The method of claim 8408, wherein at least a portion of the part of the formation is heated to a minimum pyrolysis temperature of about 270°

C.

8421. A method for treating a hydrocarbon containing formation, comprising:

providing heat from one or more heaters to at least a portion of the formation, wherein at least one heater is in at least one open wellbore in the formation, and wherein heating from one or more heaters is controlled to inhibit substantial deformation of one or more heaters caused by thermal formation expansion against such one or more heaters;

allowing the heat to transfer from the one or more heaters to a part of the formation;

producing a mixture from the formation.

8422. The method of claim 8421, further comprising controlling the heating to maintain a minimum space between at least one heater and the formation in at least one open wellbore.

8423. The method of claim 8421, further comprising controlling the heating to maintain a minimum space of at least about 0.25 cm between at least one heater and the formation in at least one open wellbore.

8424. The method of claim 8421, wherein at least one heater is in an open wellbore having a diameter sufficient to inhibit the formation from expanding against such heater during heating of the formation.

8425. The method of claim 8424, wherein the diameter of the open wellbore is greater than or equal to about 30 cm.

8426. The method of claim 8421, wherein one or more of the open wellbores have an expanded diameter proximate to relatively rich zones in the formation.

8427. The method of claim 8426, wherein one or more of the expanded diameters is greater than or equal to about 30 cm.

8428. The method of claim 8426, wherein the relatively rich zones comprise a richness greater than about 0.15 L/kg.

8429. The method of claim 8426, wherein the relatively rich zones comprise a richness greater than about 0.17 L/kg.

8430. The method of claim 8421, wherein controlling the heating comprises adjusting a heat output of at least one heater such that the heat output provided to relatively rich zones of the formation is less than the heat output provided to other zones of the formation.

8431. The method of claim 8421, wherein controlling the heating comprises adjusting a heat output of at least one heater such that about the heat output provided to relatively rich zones of the formation is less than about ½

the heat output provided to other zones of the formation.

8432. The method of claim 8431, wherein the relatively rich zones comprise a richness greater than about 0.15 L/kg.

8433. The method of claim 8421, further comprising reaming at least one open wellbore after at least some heating of the formation from the wellbore being reamed.

8434. The method of claim 8421, further comprising reaming at least one open wellbore after at least some heating of the formation from the wellbore being reamed, and wherein the reaming is conducted to remove at least some hydrocarbon material that has expanded in the open wellbore.

8435. The method of claim 8421, further comprising removing at least one heater from at least one open wellbore, and then reaming at least one such open wellbore.

8436. The method of claim 8421, further comprising perforating one or more relatively rich zones in at least part of the formation to allow for expansion of at least one or more of the relatively rich zones during heating of the formation.

8437. The method of claim 8421, further comprising placing a liner in at least one open wellbore and between at least a part of a heater and the formation, wherein the liner inhibits heater deformation caused by thermal formation expansion during heating.

8438. The method of claim 8437, wherein the liner comprises a mechanical strength sufficient to inhibit collapsing of the liner proximate relatively rich zones of the formation.

8439. The method of claim 8437, wherein the liner comprises one or more openings to allow fluids to flow through the open wellbore.

8440. The method of claim 8421, further comprising maintaining a temperature in at least a portion of the formation in a pyrolysis temperature range with a lower pyrolysis temperature of about 250°

C. and an upper pyrolysis temperature of about 400°

C.

8441. The method of claim 8421, further comprising heating at least a part of the formation to substantially pyrolyze at least some of the hydrocarbons in the formation.

8442. The method of claim 8421, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

8443. The method of claim 8421, wherein allowing the heat to transfer from the one or more heaters to the part of the formation comprises transferring heat substantially by conduction.

8444. The method of claim 8421, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8445. The method of claim 8421, further comprising controlling a pressure in at least a majority of a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8446. The method of claim 8421, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H₂ in the mixture greater than about 0.5 bars.

8447. A method for treating a hydrocarbon containing formation, comprising:

providing heat from one or more heaters to at least a portion of the formation, wherein at least one heater is in at least one open wellbore in the formation, and wherein at least one open wellbore has been sized, at least in part, based on a determination of formation expansion caused by heating of the formation such that formation expansion caused by heating of the formation is not sufficient to cause substantial deformation of one or more heaters in such sized wellbores;

allowing the heat to transfer from the one or more heaters to a part of the formation; and

producing a mixture from the formation.

8448. The method of claim 8447, further comprising controlling the heating to maintain a minimum space between at least one heater and the formation in at least one open wellbore.

8449. The method of claim 8447, further comprising controlling the heating to maintain a minimum space of at least about 0.25 cm between at least one heater and the formation in at least one open wellbore.

8450. The method of claim 8447, wherein at least one heater is in an open wellbore having a diameter sufficient to inhibit the formation from expanding against such heater during heating of the formation.

8451. The method of claim 8450, wherein the diameter of one or more of the sized open wellbores is greater than or equal to about 30 cm.

8452. The method of claim 8447, wherein one or more of the open wellbores have an expanded diameter proximate to relatively rich zones in the formation.

8453. The method of claim 8452, wherein one or more of the expanded diameters is greater than or equal to about 30 cm.

8454. The method of claim 8452, wherein the relatively rich zones comprise a richness greater than about 0.15 L/kg.

8455. The method of claim 8452, wherein the relatively rich zones comprise a richness greater than about 0.17 L/kg.

8456. The method of claim 8447, further comprising adjusting a heat output of at least one heater such that the heat output provided to relatively rich zones of the formation is less than the heat output provided to other zones of the formation.

8457. The method of claim 8447, further comprising adjusting a heat output of at least one heater such that about the heat output provided to relatively rich zones of the formation is less than about ½

the heat output provided to other zones of the formation.

8458. The method of claim 8456, wherein the relatively rich zones comprise a richness greater than about 0.15 L/kg.

8459. The method of claim 8447, further comprising reaming at least one open wellbore after at least some heating of the formation from the wellbore being reamed.

8460. The method of claim 8447, further comprising reaming at least one open wellbore after at least some heating of the formation from the wellbore being reamed, and wherein the reaming is conducted to remove at least some hydrocarbon material that has expanded in the open wellbore.

8461. The method of claim 8447, further comprising removing at least one heater from at least one open wellbore, and then reaming at least one such open wellbore.

8462. The method of claim 8447, further comprising perforating one or more relatively rich zones in at least part of the formation to allow for expansion of at least one or more of the relatively rich zones during heating of the formation.

8463. The method of claim 8447, further comprising placing a liner in at least one open wellbore and between at least a part of a heater and the formation, wherein the liner inhibits heater deformation caused for thermal formation expansion during heating.

8464. The method of claim 8463, wherein the liner comprises a mechanical strength sufficient to inhibit collapsing of the liner proximate relatively rich zones of the formation.

8465. The method of claim 8463, wherein the liner comprises one or more openings to allow fluids to flow through the open wellbore.

8466. The method of claim 8447, further comprising maintaining a temperature in at least a portion of the formation in a pyrolysis temperature range with a lower pyrolysis temperature of about 250°

C. and an upper pyrolysis temperature of about 400°

C.

8467. The method of claim 8447, further comprising heating at least a part of the formation to substantially pyrolyze at least some of the hydrocarbons in the formation.

8468. The method of claim 8447, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

8469. The method of claim 8447, wherein allowing the heat to transfer from the one or more heaters to the part of the formation comprises transferring heat substantially by conduction.

8470. The method of claim 8447, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8471. The method of claim 8447, further comprising controlling a pressure in at least a majority of a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8472. The method of claim 8447, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H₂ in the mixture greater than about 0.5 bars.

8473. A method for treating a hydrocarbon containing formation, comprising:

heating a first volume of the formation using a first set of heaters;

heating a second volume of the formation using a second set of heaters, wherein the first volume is spaced apart from the second volume by a third volume of the formation;

heating the third volume using a third set of heaters, wherein the third set of heaters begin heating at a selected time after the first set of heaters and the second set of heaters;

allowing the heat to transfer from the first, second, and third volumes of the formation to at least a part of the formation; and

producing a mixture from the formation.

8474. The method of claim 8473, wherein the first, second, or third volumes are sized, shaped, or located based on, at least in part, a calculated geomechanical motion of at least a portion of the formation.

8475. The method of claim 8473, further comprising sizing, shaping, or locating the first, second, or third volumes based on, at least in part, a calculated geomechanical motion of at least a portion of the formation.

8476. The method of claim 8473, wherein the first, second, or third volumes are sized, shaped, or located, at least in part, to inhibit deformation, caused by geomechanical motion, of one or more selected wellbores in the formation.

8477. The method of claim 8473, wherein the first, second, or third volumes are at least in part sized, shaped, or located based on a calculated geomechanical motion of at least a portion of the formation, and wherein the first, second, or third volumes are sized, shaped, or located, at least in part, to inhibit deformation, caused by geomechanical motion, of one or more selected wellbores in the formation.

8478. The method of claim 8473, wherein the first, second, or third volume of the formation has been sized, shaped, or located, at least in part, based on a simulation.

8479. The method of claim 8473, wherein the first, second, and third volumes of the formation have been sized, shaped, or located, at least in part, based on a simulation.

8480. The method of claim 8473, wherein a footprint area of the first volume, second volume, or third volume is less than about 400 square meters.

8481. The method of claim 8473, wherein the third set of heaters begin heating after a selected amount of geomechanical motion in the first or second volumes.

8482. The method of claim 8473, wherein the third set of heaters begin heating to maintain or enhance a production rate of the mixture from the formation.

8483. The method of claim 8473, wherein the selected time has been at least in part determined using a simulation.

8484. The method of claim 8473, wherein the first and second volumes comprise rectangular footprints.

8485. The method of claim 8473, wherein the first and second volumes comprise square footprints.

8486. The method of claim 8473, wherein the first and second volumes comprise circular footprints.

8487. The method of claim 8473, wherein the first, second, and third volumes comprise rectangular footprints.

8488. The method of claim 8473, wherein the first, second, and third volumes comprise square footprints.

8489. The method of claim 8473, wherein the first, second, and third volumes comprise circular footprints.

8490. The method of claim 8473, wherein the first, second, and third volumes comprise footprints in a concentric ring pattern.

8491. The method of claim 8473, further comprising maintaining a temperature in at least a portion of the formation in a pyrolysis temperature range with a lower pyrolysis temperature of about 250°

C. and an upper pyrolysis temperature of about 400°

C.

8492. The method of claim 8473, further comprising pyrolyzing at least some of the hydrocarbons in the formation.

8493. The method of claim 8473, further comprising controlling a pressure and a temperature in at least a majority of the part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

8494. The method of claim 8473, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8495. The method of claim 8473, further comprising controlling a pressure in at least a majority of a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8496. The method of claim 8473, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H₂ in the mixture greater than about 0.5 bars.

8497. The method of claim 8473, wherein the third set of heaters begins heating within 6 months before or after the first set or second set of heaters begin heating.

8498. A method for treating a hydrocarbon containing formation, comprising:

heating a first volume of the formation using a first set of heaters; and

heating a second volume of the formation using a second set of heaters, wherein the first volume is spaced apart from the second volume by a third volume of the formation, and wherein the first volume, second volume, and third volume are sized, shaped, or located to inhibit deformation of subsurface equipment caused by geomechanical motion of the formation during heating.

8499. The method of claim 8498, further comprising allowing the heat to transfer from the first and second volumes of the formation to at least a part of the formation.

8500. The method of claim 8498, wherein a footprint of the first volume, second volume, or third volume is sized, shaped, or located to inhibit deformation of subsurface equipment caused by geomechanical motion of the formation during heating.

8501. The method of claim 8498, further comprising producing a mixture from the formation.

8502. The method of claim 8498, further comprising sizing, shaping, or locating the first volume, second volume, or third volume to inhibit deformation of subsurface equipment caused by geomechanical motion of the formation during heating.

8503. The method of claim 8498, further comprising calculating geomechanical motion in a footprint of the first volume or the second volume, and using the calculated geomechanical motion to size, shape, or locate the first volume, the second volume, or the third volume.

8504. The method of claim 8498, further comprising allowing the heat to transfer from the first and second volumes of the formation to at least a part of the formation, and producing a mixture from the formation.

8505. The method of claim 8498, wherein the third volume substantially surrounds the first volume, and the second volume substantially surrounds the first volume.

8506. The method of claim 8498, wherein the third volume substantially surrounds all or a portion of the first volume, and the second volume substantially surrounds all or a portion of the third volume.

8507. The method of claims 8498, wherein the third volume has a footprint that is a linear, curved, or irregular shaped strip.

8508. The method of claim 8498, wherein the first and second volumes comprise rectangular footprints.

8509. The method of claim 8498, wherein the first and second volumes comprise square footprints.

8510. The method of claim 8498, wherein the first and second volumes comprise circular footprints.

8511. The method of claim 8498, wherein the first and second volumes comprise footprints in a concentric ring pattern.

8512. The method of claim 8498, wherein the first, second, and third volumes comprise rectangular footprints.

8513. The method of claim 8498, wherein the first, second, and third volumes comprise square footprints.

8514. The method of claim 8498, wherein the first, second, and third volumes comprise circular footprints.

8515. The method of claim 8498, wherein the first, second, and third volumes comprise footprints in a concentric ring pattern.

8516. The method of claim 8498, wherein the first, second, or third volumes are sized, shaped, or located based on, at least in part, a calculated geomechanical motion of at least a portion of the formation.

8517. The method of claim 8498, further comprising sizing, shaping, or locating the first, second, or third volumes based on, at least in part, a calculated geomechanical motion of at least a portion of the formation.

8518. The method of claim 8498, wherein the first, second, or third volumes are sized, shaped, or located, at least in part, to inhibit deformation, caused by geomechanical motion, of one or more selected wellbores in the formation.

8519. The method of claim 8498, wherein the first, second, or third volumes are at least in part sized, shaped, or located based on a calculated geomechanical motion of at least a portion of the formation, and wherein the first, second, or third volumes are sized, shaped, or located, at least in part, to inhibit deformation, caused by geomechanical motion, of one or more selected wellbores in the formation.

8520. The method of claim 8498, wherein the first, second, or third volumes of the formation have been sized, shaped, or located, at least in part, based on a simulation.

8521. The method of claim 8498, wherein the first, second, and third volumes of the formation have been sized, shaped, or located, at least in part, based on a simulation.

8522. The method of claim 8498, wherein a footprint area of the first volume, second volume, or third volume is less than about 400 square meters.

8523. The method of claim 8498, wherein the third set of heaters begin heating after a selected amount of geomechanical motion in the first or second volumes.

8524. The method of claim 8498, wherein the third set of heaters begin heating to maintain or enhance a production rate of the mixture from the formation.

8525. The method of claim 8498, wherein the selected time has been at least in part determined using a simulation.

8526. The method of claim 8498, further comprising maintaining a temperature in at least a portion of the formation in a pyrolysis temperature range with a lower pyrolysis temperature of about 250°

C. and an upper pyrolysis temperature of about 400°

C.

8527. The method of claim 8498, further comprising pyrolyzing at least some of the hydrocarbons in the formation.

8528. The method of claim 8498, further comprising controlling a pressure and a temperature in at least a part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.

8529. The method of claim 8498, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8530. The method of claim 8498, further comprising controlling a pressure in at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8531. The method of claim 8498, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H₂ in the mixture greater than about 0.5 bars.

8532. A system configured to heat at least a part of a hydrocarbon containing formation, comprising:

one or more electrical conductors configured to be placed in an opening in the formation, wherein at least one electrical conductor comprises at least one electrically resistive portion configured to provide a heat output when current is applied through such electrically resistive portion, and wherein at least one of such electrically resistive portions is configured, when above or near a selected temperature, to automatically provide a reduced heat output; and

wherein the system is configured to allow heat to transfer from at least one of the electrically resistive portions to at least a part of the formation.

8533. The system of claim 8532, wherein at least one electrical conductor is configured to propagate electrical current out of the opening.

8534. The system of claim 8532, wherein at least one electrical conductor is configured to propagate electrical current into the opening.

8535. The system of claim 8532, wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.

8536. The system of claim 8532, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.

8537. The system of claim 8532, wherein at least one electrical conductor comprises an inner conductor and at least one electrical conductor comprises an outer conductor.

8538. The system of claim 8532, further comprising an electrically insulating material placed between at least two electrical conductors.

8539. The system of claim 8532, further comprising an electrically insulating material, comprising a packed powder, placed between at least two electrical conductors.

8540. The system of claim 8532, further comprising a flexible electrically insulating material placed between at least two electrical conductors.

8541. The system of claim 8532, wherein at least one electrically resistive portion comprises a resistance that decreases at, near, or above the selected temperature such that the at least one electrically resistive portion provides a reduced heat output above the selected temperature.

8542. The system of claim 8532, wherein at least one electrically resistive portion comprises a ferromagnetic material.

8543. The system of claim 8532, wherein at least one electrically resistive portion comprises a ferromagnetic material comprising iron, nickel, chromium, cobalt, or mixtures thereof.

8544. The system of claim 8532, wherein at least one electrically resistive portion comprises a ferromagnetic material with sufficient thickness that is substantially greater than the skin depth at the Curie temperature of the ferromagnetic material.

8545. The system of claim 8532, wherein at least one electrically resistive portion comprises a ferromagnetic material with sufficient thickness such that the thickness is substantially greater than the skin depth at the Curie temperature of the ferromagnetic material, and wherein the ferromagnetic material is coupled to a more conductive material such that, at the Curie temperature of the ferromagnetic material, the electrically resistive portion has a higher conductivity than the electrically resistive portion would if the ferromagnetic material were used, in the same or greater thickness, without the more conductive material.

8546. The system of claim 8532, wherein at least one electrically resistive portion comprises a first ferromagnetic material with a first Curie temperature, and a second ferromagnetic material with a second Curie temperature.

8547. The system of claim 8532, wherein at least one electrically resistive portion comprises a ferromagnetic material with a thickness greater than the skin depth of the ferromagnetic material at the Curie temperature of the ferromagnetic material.

8548. The system of claim 8532, wherein at least one electrically resistive portion comprises ferromagnetic material with a thickness at least about 1.5 times greater than the skin depth of the ferromagnetic material at the Curie temperature of the ferromagnetic material.

8549. The system of claim 8532, wherein at least one electrically resistive portion comprises ferromagnetic material coupled to a higher conductivity material.

8550. The system of claim 8532, wherein at least one electrically resistive portion comprises ferromagnetic material coupled to a higher conductivity non-ferromagnetic material.

8551. The system of claim 8532, wherein at least one electrically resistive portion comprises ferromagnetic material, and wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.

8552. The system of claim 8532, wherein at least one electrically resistive portion comprises ferromagnetic material and non-ferromagnetic electrically conductive material.

8553. The system of claim 8532, wherein at least one electrically conductive portion is located proximate a relatively rich zone of the formation.

8554. The system of claim 8532, wherein at least one electrically resistive portion is located proximate a hot spot of the formation.

8555. The system of claim 8532, wherein at least one electrically resistive portion comprises carbon steel.

8556. The system of claim 8532, wherein at least one electrically resistive portion comprises iron.

8557. The system of claim 8532, wherein the electrically resistive portion comprises a ferromagnetic material, and the ferromagnetic material is coupled to a corrosion resistant material.

8558. The system of claim 8532, wherein the electrically resistive portion comprises a ferromagnetic material, and a corrosion resistant material is coated on the ferromagnetic material.

8559. The system of claim 8532, wherein the electrically resistive portion comprises one or more bends.

8560. The system of claim 8532, wherein the electrically resistive portion comprises a helically shaped portion.

8561. The system of claim 8532, wherein the electrically resistive portion is part of an insulated conductor.

8562. The system of claim 8532, wherein the electrically resistive portion comprises a thickness of ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.

8563. The system of claim 8532, wherein the electrically resistive portion comprises a thickness of a ferromagnetic material, and such ferromagnetic material comprises iron, nickel, chromium, cobalt, or mixtures thereof, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.

8564. The system of claim 8532, wherein the electrically resistive portion comprises a thickness of a ferromagnetic material, and such ferromagnetic material comprises a first Curie temperature material and a second Curie temperature material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness of the ferromagnetic material and the thickness of the more conductive material have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.

8565. The system of claim 8532, wherein the electrically resistive portion comprises a thickness of a ferromagnetic material, and such ferromagnetic material is coupled to a thickness of a more conductive material, and wherein the thickness and skin depth characteristics of the ferromagnetic material, and the thickness of the more conductive material, have been selected such that the electrically resistive portion provides a selected resistance profile as a function of temperature.

8566. The system of claim 8532, wherein the electrically resistive portion is part of an insulated conductor, and wherein the insulated conductor comprises a lead-in conductor and a lead-out conductor.

8567. The system of claim 8532, wherein the electrically resistive portion is part of an insulated conductor, and wherein the insulated conductor is coupled to a support member.

8568. The system of claim 8532, wherein the electrically resistive portion is part of an insulated conductor, and the insulated conductor is frictionally secured against a cased or open wellbore.

8569. The system of claim 8532, wherein the electrically resistive portion is part of a conductor-in-conduit.

8570. The system of claim 8532, wherein at least one electrical conductor is electrically coupled to the earth, and wherein electrical current is propagated from the electrical conductor to the earth.

8571. The system of claim 8532, wherein the reduced heat output is less than about 800 watts per meter.

8572. The system of claim 8532, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat resistance profile in a temperature range between about 100°

C. and 750°

C.

8573. The system of claim 8532, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat resistance profile in a temperature range between about 100°

C. and 750°

C., and a relatively sharp resistance profile at a temperature above about 750°

C. and less than about 850°

C.

8574. The system of claim 8532, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat resistance profile in a temperature range between about 300°

C. and 600°

C.

8575. The system of claim 8532, wherein the at least one electrical conductor is greater than about 10 m in length.

8576. The system of claim 8532, wherein the at least one electrical conductor is greater than about 50 m in length.

8577. The system of claim 8532, wherein the at least one electrical conductor is greater than about 100 m in length.

8578. The system of claim 8532, wherein the system is configured to reduce heat output such that the system does not overheat in the opening.

8579. The system of claim 8532, wherein the system is configured to sharply reduce heat output at or near the selected temperature.

8580. The system of claim 8532, wherein the electrically resistive portion comprises drawn iron.

8581. The system of claim 8532, wherein the electrically resistive portion comprises a ferromagnetic material drawn together or against a more conductive material.

8582. The system of claim 8532, wherein the electrically resistive portion comprises an elongated conduit comprising iron, wherein a center of the conduit is lined or filled with a material comprising copper or aluminum.

8583. The system of claim 8532, wherein the electrically resistive portion comprises an elongated conduit comprising iron, wherein a center of the conduit is lined or filled with a material comprising copper or aluminum, and wherein the copper or aluminum was melted in a center of the conduit and allowed to harden.

8584. The system of claim 8532, wherein the electrically resistive portion comprises an elongated conduit comprising a center portion and an outer portion, and wherein the diameter of the center portion is at least about 0.5 cm and comprises iron.

8585. The system of claim 8532, wherein the electrically resistive portion comprises an elongated conduit comprising a center portion and an outer portion.

8586. The system of claim 8532, wherein the electrically resistive portion comprises an elongated conduit comprising a center portion and an outer portion, and wherein the diameter of the center portion is at least twice the skin depth.

8587. The system of claim 8532, wherein the current is an alternating current.

8588. The system of claim 8532, wherein at least one of the electrically resistive portions comprises a composite material, wherein the composite material comprises a first material that has a resistance that declines when heated to the selected temperature, and wherein the composite material includes a second material that is more electrically conductive than the first material, and wherein the first material is coupled to the second material.

8589. The system of claim 8532, wherein the system is configured such that, at or near the selected temperature, the heat output of at least a portion of the system declines due to the Curie effect.

8590. The system of claim 8532, wherein the heat output is reduced below the rate at which the formation will absorb or transfer heat, thereby inhibiting overheating of the formation.

8591. The system of claim 8532, wherein the electrically resistive portion comprises a magnetic material that, at or near the selected temperature, becomes substantially nonmagnetic.

8592. The system of claim 8532, wherein the electrically resistive portion is elongated, and configured such that only portions of the electrically resistive portion that are at or near the selected temperature will automatically reduce heat output.

8593. The system of claim 8532, wherein the system comprises a heater which in turn comprises one or more of the electrically resistive portions.

8594. The system of claim 8532, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion increases.

8595. The system of claim 8532, configured such that when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion decreases.

8596. The system of claim 8532, configured that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion gradually decreases.

8597. The system of claim 8532, configured such that when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion sharply decreases.

8598. The system of claim 8532, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion increases, and when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion decreases.

8599. The system of claim 8532, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion increases, and when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion decreases, and wherein the selected temperature is a temperature above the boiling point of water but below a failure temperature of one or more system components.

8600. The system of claim 8532, configured such that when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion gradually decreases.

8601. The system of claim 8532, configured such that different portions of the formation, with different thermal conductivities, can be heated within 10% of the failure temperature of the system.

8602. A method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to one or more electrical conductors placed in an opening in the formation, wherein at least one electrical conductor comprises one or more electrically resistive portions configured to provide a heat output when electrical current is applied through such electrically resistive portion, and wherein at least one of such electrically resistive portions is configured, when above or near a selected temperature, to automatically provide a reduced heat output; and

allowing the heat to transfer from one or more electrical resistive portions to at least a part of the formation.

8603. The method of claim 8602, further comprising applying a relatively constant electrical current to the one or more electrical conductors.

8604. The method of claim 8602, further comprising providing electrical current to one or more electrical conductors.

8605. The method of claim 8602, further comprising providing a relatively constant heat output in a temperature range between about 300°

C. and 600°

C.

8606. The method of claim 8602, further comprising providing a relatively constant heat output in a temperature range between about 100°

C. and 750°

C.

8607. The method of claim 8602, wherein at least one electrically conductive portion comprises a resistance that decreases above the selected temperature such that the electrically conductive portion provides the reduced heat output above the selected temperature.

8608. The method of claim 8602, wherein at least one electrically conductive portion comprises ferromagnetic material with a thickness at least 1.5 times greater than the skin depth of the ferromagnetic material at the Curie temperature of the ferromagnetic material.

8609. The method of claim 8602, wherein at least one electrically conductive portion comprises ferromagnetic material.

8610. The method of claim 8602, further comprising locating at least one electrically resistive portion proximate a relatively rich zone of the formation.

8611. The method of claim 8602, further comprising locating at least one electrically resistive portion proximate a hot spot of the formation.

8612. The method of claim 8602, further comprising pyrolyzing at least some hydrocarbons within the formation.

8613. The method of claim 8602, further comprising controlling a pressure and a temperature within at least a part of the formation, wherein the pressure is controlled as a function of temperature, and/or the temperature is controlled as a function of pressure.

8614. The method of claim 8602, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8615. The method of claim 8602, further comprising controlling a pressure within at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8616. The method of claim 8602, further comprising controlling formation conditions such that a produced mixture comprises a partial pressure of H₂ within the mixture greater than about 0.5 bars.

8617. The method of claim 8602, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

8618. The method of claim 8602, wherein at least a portion of the part of the formation is heated to a minimum pyrolysis temperature of about 270°

C.

8619. The method of claim 8602, wherein the reduced heat output is less than about 800 watts per meter.

8620. The method of claim 8602, further comprising controlling a skin depth in at least one electrically resistive portion by controlling a frequency of alternating current applied to at least one electrically resistive portion.

8621. The method of claim 8602, further comprising applying additional power to at least one electrically resistive portion as the temperature of the electrically resistive portion increases, and continuing to do so until the temperature is at or near the selected temperature.

8622. The method of claim 8602, wherein the hydrocarbon containing formation contains at least two portions with different thermal conductivities, and further comprising applying heat to such portions with an electrically resistive portion that is proximate to such portions, and further comprising automatically allowing less heat to be applied from a part of an electrically resistive portion that is proximate a portion of the formation with a lower thermal conductivity.

8623. The method of claim 8602, wherein the hydrocarbon containing formation contains at least two portions with different thermal conductivities, and further comprising applying heat to such portions with an electrically resistive portion that is proximate to such portions, and further comprising automatically allowing less heat to be applied from a part of the electrically resistive portion that is proximate a portion of the formation with a lower thermal conductivity while also allowing more heat to be applied from a part of the electrically resistive portion that is proximate a portion of the formation with a higher thermal conductivity.

8624. The method of claim 8602, wherein the hydrocarbon containing formation contains at least two layers with different thermal conductivities, and further comprising applying heat to such layers with an electrically resistive portion that is proximate to such layers, and further comprising automatically allowing less heat to be applied from a part of an electrically resistive portion that is proximate a layer of the formation with a lower thermal conductivity.

8625. The method of claim 8602, wherein the hydrocarbon containing formation contains at least two layers with different thermal conductivities, and further comprising applying heat to such layers with an electrically resistive portion that is proximate to such layers, and further comprising automatically allowing less heat to be applied from a part of the electrically resistive portion that is proximate a layer of the formation with a lower thermal conductivity while also allowing more heat to be applied from a part of the electrically resistive portion that is proximate a layer of the formation with a higher thermal conductivity.

8626. The method of claim 8602, further comprising controlling the heat applied from an electrically resistive portion by allowing less heat to be applied from any part of the electrically resistive portion that is at or near the selected temperature.

8627. The method of claim 8602, wherein the hydrocarbon containing formation comprises an oil shale formation.

8628. The method of claim 8602, wherein the hydrocarbon containing formation comprises a coal formation.

8629. The method of claim 8602, wherein the hydrocarbon containing formation comprises a tar sands formation.

8630. A system configured to heat at least a part of a hydrocarbon containing formation, comprising:

one or more electrical conductors configured to be placed in an opening in the formation, wherein at least one electrical conductor comprises a ferromagnetic material configured to provide a reduced heat output above or near a selected temperature; and

wherein the system is configured to allow heat to transfer from the electrical conductors to a part of the formation.

8631. The system of claim 8630, wherein at least one electrical conductor is configured to propagate electrical current into the opening.

8632. The system of claim 8630, wherein the system is configured to pyrolyze at least some hydrocarbons in the formation.

8633. The system of claim 8630, wherein at least one electrical conductor is configured to propagate electrical current out of the opening.

8634. The system of claim 8630, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.

8635. The system of claim 8630, wherein at least one electrical conductor comprises an inner conductor and at least one electrical conductor comprises an outer conductor.

8636. The system of claim 8630, further comprising an electrically insulating material placed between at least two electrical conductors.

8637. The system of claim 8630, further comprising a flexible electrically insulating material placed between at least two electrical conductors.

8638. The system of claim 8630, wherein the ferromagnetic material comprises a resistance that decreases above the selected temperature such that the system provides the reduced heat output above the selected temperature.

8639. The system of claim 8630, wherein the ferromagnetic material comprises a thickness greater than the skin depth of the ferromagnetic material at the Curie temperature of the ferromagnetic material.

8640. The system of claim 8630, wherein the ferromagnetic material comprises a thickness at least 1.5 times greater than the skin depth of the ferromagnetic material at the Curie temperature of the ferromagnetic material.

8641. The system of claim 8630, further comprising a higher conductivity material coupled to the ferromagnetic material.

8642. The system of claim 8630, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.

8643. The system of claim 8630, further comprising a second ferromagnetic material coupled to the ferromagnetic material.

8644. The system of claim 8630, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.

8645. The system of claim 8630, wherein at least one electrical conductor comprises ferromagnetic material and non-ferromagnetic, electrically conductive material.

8646. The system of claim 8630, wherein the ferromagnetic material comprises iron.

8647. The system of claim 8630, wherein at least one electrical conductor is electrically coupled to the earth, and wherein electrical current is propagated from the electrical conductor to the earth.

8648. The system of claim 8630, wherein the reduced heat output is less than about 800 watts per meter.

8649. The system of claim 8630, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat resistance profile in a temperature range between about 100°

C. and 750°

C.

8650. The system of claim 8630, wherein the at least one electrical conductor is greater than about 10 m in length.

8651. A method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to one or more electrical conductors placed in an opening in the formation, wherein at least one electrical conductor comprises a ferromagnetic material configured to provide a reduced heat output above or near a selected temperature; and

allowing the heat to transfer from the one or more electrical conductors to a part of the formation.

8652. The method of claim 8651, further comprising applying a relatively constant electrical current to the one or more electrical conductors.

8653. The method of claim 8651, further comprising allowing the electrical current to propagate through at least one electrical conductor into the opening.

8654. The method of claim 8651, further comprising providing a relatively constant heat output in a temperature range between about 100°

C. and 750°

C.

8655. The method of claim 8651, wherein the ferromagnetic material comprises a resistance that decreases above the selected temperature such that the ferromagnetic material provides the reduced heat output above the selected temperature.

8656. The method of claim 8651, wherein the ferromagnetic material comprises a thickness at least 1.5 times greater than the skin depth of the ferromagnetic material at the Curie temperature of the ferromagnetic material.

8657. The method of claim 8651, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.

8658. The method of claim 8651, further comprising pyrolyzing at least some hydrocarbons within the formation.

8659. The method of claim 8651, further comprising controlling a pressure and a temperature within at least a part of the formation, wherein the pressure is controlled as a function of temperature, and/or the temperature is controlled as a function of pressure.

8660. The method of claim 8651, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8661. The method of claim 8651, further comprising controlling a pressure within at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8662. The method of claim 8651, further comprising controlling formation conditions such that a produced mixture comprises a partial pressure of H₂ within the mixture greater than about 0.5 bars.

8663. The method of claim 8651, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

8664. The method of claim 8651, wherein at least a portion of the part of the formation is heated to a minimum pyrolysis temperature of about 270°

C.

8665. The method of claim 8651, wherein the reduced heat output is less than about 800 watts per meter.

8666. The method of claim 8651, wherein the hydrocarbon containing formation comprises an oil shale formation.

8667. The method of claim 8651, wherein the hydrocarbon containing formation comprises a coal formation.

8668. The method of claim 8651, wherein the hydrocarbon containing formation comprises a tar sands formation.

8669. A system configured to heat at least a part of a hydrocarbon containing formation, comprising:

one or more electrical conductors configured to be placed in an opening in the formation, wherein at least one electrical conductor comprises a ferromagnetic material configured to provide a reduced heat output above or near a selected temperature, wherein at least one electrical conductor is electrically coupled to the earth, and wherein electrical current is propagated from the electrical conductor to the earth; and

wherein the system is configured to allow heat to transfer from the electrical conductors to a part of the formation.

8670. The system of claim 8669, wherein at least one electrical conductor is electrically coupled to the earth through an electrical contacting section.

8671. The system of claim 8669, wherein the electrical contacting section comprises a second opening coupled to the opening.

8672. The system of claim 8669, wherein the electrical contacting section comprises a second opening coupled to the opening and having a larger diameter than the opening.

8673. The system of claim 8669, wherein the electrical contacting section comprises a second opening coupled to the opening, and wherein the second opening is filled with a material that enhances electrical contact between at least one electrical conductor and the earth.

8674. The system of claim 8669, wherein at least one electrical conductor is configured to propagate electrical current into the opening.

8675. The system of claim 8669, wherein at least one electrical conductor is configured to propagate electrical current out of the opening.

8676. The system of claim 8669, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.

8677. The system of claim 8669, wherein at least one electrical conductor comprises an inner conductor and at least one electrical conductor comprises an outer conductor.

8678. The system of claim 8669, further comprising an electrically insulating material placed between at least two electrical conductors.

8679. The system of claim 8669, further comprising a flexible electrically insulating material placed between at least two electrical conductors.

8680. The system of claim 8669, wherein the ferromagnetic material comprises a resistance that decreases above the selected temperature such that the system provides the reduced heat output above the selected temperature.

8681. The system of claim 8669, wherein the ferromagnetic material comprises a thickness greater than the skin depth of the ferromagnetic material at the Curie temperature of the ferromagnetic material.

8682. The system of claim 8669, wherein the ferromagnetic material comprises a thickness at least 1.5 times greater than the skin depth of the ferromagnetic material at the Curie temperature of the ferromagnetic material.

8683. The system of claim 8669, further comprising a higher conductivity material coupled to the ferromagnetic material.

8684. The system of claim 8669, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.

8685. The system of claim 8669, further comprising a second ferromagnetic material coupled to the ferromagnetic material.

8686. The system of claim 8669, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.

8687. The system of claim 8669, wherein at least one electrical conductor comprises ferromagnetic material and non-ferromagnetic, electrically conductive material.

8688. The system of claim 8669, wherein the ferromagnetic material comprises iron.

8689. The system of claim 8669, wherein the reduced heat output is less than about 800 watts per meter.

8690. The system of claim 8669, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat resistance profile in a temperature range between about 100°

C. and 750°

C.

8691. The system of claim 8669, wherein the at least one electrical conductor is greater than about 10 m in length.

8692. The system of claim 8669, wherein the system is configured for use in soil remediation of the hydrocarbon containing formation.

8693. The system of claim 8669, configured such that different portions of the formation, with different thermal conductivities, can be heated within 10% of the failure temperature of the system.

8694. A method for heating a hydrocarbon containing formation, comprising:

applying an electrical current to one or more electrical conductors placed in an opening in the formation, wherein at least one electrical conductor comprises a ferromagnetic material configured to provide a reduced heat output above or near a selected temperature, wherein at least one electrical conductor is electrically coupled to the earth, and wherein electrical current is propagated from the electrical conductor to the earth; and

allowing the heat to transfer from the one or more electrical conductors to a part of the formation.

8695. The method of claim 8694, further comprising applying a relatively constant electrical current to the one or more electrical conductors.

8696. The method of claim 8694, further comprising allowing the electrical current to propagate through at least one electrical conductor into the opening.

8697. The method of claim 8694, further comprising providing a relatively constant heat output in a temperature range between about 100°

C. and 750°

C.

8698. The method of claim 8694, wherein the ferromagnetic material comprises a resistance that decreases above the selected temperature such that the ferromagnetic material provides the reduced heat output above the selected temperature.

8699. The method of claim 8694, wherein the ferromagnetic material comprises a thickness at least 1.5 times greater than the skin depth of the ferromagnetic material at the Curie temperature of the ferromagnetic material.

8700. The method of claim 8694, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.

8701. The method of claim 8694, further comprising pyrolyzing at least some hydrocarbons within the formation.

8702. The method of claim 8694, further comprising controlling a pressure and a temperature within at least a part of the formation, wherein the pressure is controlled as a function of temperature, and/or the temperature is controlled as a function of pressure.

8703. The method of claim 8694, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8704. The method of claim 8694, further comprising controlling a pressure within at least a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8705. The method of claim 8694, further comprising controlling formation conditions such that a produced mixture comprises a partial pressure of H₂ within the mixture greater than about 0.5 bars.

8706. The method of claim 8694, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

8707. The method of claim 8694, wherein at least a portion of the part of the formation is heated to a minimum pyrolysis temperature of about 270°

C.

8708. The method of claim 8694, wherein the reduced heat output is less than about 800 watts per meter.

8709. A heater, comprising:

an electrical conductor configured to generate heat during application of electrical current to the electrical conductor; and

wherein the electrical conductor comprises a ferromagnetic material having a thickness greater than the skin depth of the ferromagnetic material at the Curie temperature of the ferromagnetic material such that the heater provides a reduced heat output above or near a selected temperature.

8710. The heater of claim 8709, wherein the heater is configured to allow heat to transfer from the heater to a part of a hydrocarbon containing formation to pyrolyze at least some hydrocarbons in the hydrocarbon containing formation.

8711. The heater of claim 8709, wherein the heater is configured to be placed in an opening in a hydrocarbon containing formation.

8712. The heater of claim 8709, wherein the heater is configured to be placed in an opening in an oil shale formation.

8713. The heater of claim 8709, wherein the heater is configured to be placed in an opening in a coal formation.

8714. The heater of claim 8709, wherein the heater is configured to be placed in an opening in a tar sands formation.

8715. The heater of claim 8709, further comprising two additional electrical conductors configured to generate heat during application of electrical current to the two additional electrical conductors, wherein the electrical conductor and the two additional electrical conductors are configured to be coupled in a three-phase electrical configuration.

8716. The heater of claim 8709, further comprising at least one additional electrical conductor.

8717. The heater of claim 8709, further comprising at least one additional electrical conductor and an electrically insulating material placed between the electrical conductor and at least one additional electrical conductor.

8718. The heater of claim 8709, further comprising at least one additional electrical conductor and a flexible electrically insulating material placed between the electrical conductor and at least one additional electrical conductor.

8719. The heater of claim 8709, wherein a resistance of the ferromagnetic material decreases above the selected temperature such that the heater provides the reduced heat output above the selected temperature.

8720. The heater of claim 8709, wherein the ferromagnetic material comprises a thickness at least 1.5 times greater than the skin depth of the ferromagnetic material at the Curie temperature of the ferromagnetic material.

8721. The heater of claim 8709, further comprising a higher conductivity material coupled to the ferromagnetic material.

8722. The heater of claim 8709, further comprising a higher conductivity non-ferromagnetic material coupled to the ferromagnetic material.

8723. The heater of claim 8709, further comprising a second ferromagnetic material coupled to the ferromagnetic material.

8724. The heater of claim 8709, wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.

8725. The heater of claim 8709, wherein the ferromagnetic material comprises iron.

8726. The heater of claim 8709, wherein the ferromagnetic material comprises carbon steel.

8727. The heater of claim 8709, wherein the reduced heat output is less than about 800 watts per meter.

8728. The heater of claim 8709, wherein the heater comprises a relatively flat resistance profile in a temperature range between about 100°

C. and 750°

C.

8729. The heater of claim 8709, wherein the heater is greater than about 10 m in length.

8730. A heating system, comprising:

one or more electrical conductors, wherein at least one electrical conductor comprises at least one electrically resistive portion configured to provide a heat output when current is applied through such electrically resistive portion, and wherein at least one of such electrically resistive portions is configured, when above or near a selected temperature, to automatically provide a reduced heat output.

8731. The heating system of claim 8730, wherein three or more electrical conductors are configured to be coupled in a three-phase electrical configuration.

8732. The heating system of claim 8730, wherein at least one electrical conductor comprises an inner conductor and at least one electrical conductor comprises an outer conductor.

8733. The heating system of claim 8730, further comprising an electrically insulating material placed between at least two electrical conductors.

8734. The heating system of claim 8730, further comprising an electrically insulating material, comprising a packed powder, placed between at least two electrical conductors.

8735. The heating system of claim 8730, further comprising a flexible electrically insulating material placed between at least two electrical conductors.

8736. The heating system of claim 8730, wherein at least one electrically resistive portion comprises a resistance that decreases above or near the selected temperature such that the at least one electrically resistive portion provides a reduced heat output above the selected temperature.

8737. The heating system of claim 8730, wherein at least one electrically resistive portion comprises a ferromagnetic material.

8738. The heating system of claim 8730, wherein at least one electrically resistive portion comprises a ferromagnetic material with sufficient thickness that is substantially greater than the skin depth at the Curie temperature of the ferromagnetic material.

8739. The heating system of claim 8730, wherein at least one electrically resistive portion comprises a ferromagnetic material with sufficient thickness such that the thickness is substantially greater than the skin depth at the Curie temperature of the ferromagnetic material, and wherein the ferromagnetic material is coupled to a more conductive material such that, at the Curie temperature of the ferromagnetic material, the electrically resistive portion has a higher conductivity than the electrically resistive portion would if the ferromagnetic material were used, in the same or greater thickness, without the more conductive material.

8740. The heating system of claim 8730, wherein at least one electrically resistive portion comprises a first ferromagnetic material with a first Curie temperature, and a second ferromagnetic material with a second Curie temperature.

8741. The heating system of claim 8730, wherein at least one electrically resistive portion comprises a ferromagnetic material with a thickness greater than the skin depth of the ferromagnetic material at the Curie temperature of the ferromagnetic material.

8742. The heating system of claim 8730, wherein at least one electrically resistive portion comprises ferromagnetic material with a thickness at least about 1.5 times greater than the skin depth of the ferromagnetic material at the Curie temperature of the ferromagnetic material.

8743. The heating system of claim 8730, wherein at least one electrically resistive portion comprises ferromagnetic material coupled to a higher conductivity material.

8744. The heating system of claim 8730, wherein at least one electrically resistive portion comprises ferromagnetic material coupled to a higher conductivity non-ferromagnetic material.

8745. The heating system of claim 8730, wherein at least one electrically resistive portion comprises ferromagnetic material, and wherein the selected temperature is approximately the Curie temperature of the ferromagnetic material.

8746. The heating system of claim 8730, wherein at least one electrically resistive portion comprises ferromagnetic material and non-ferromagnetic, electrically conductive material.

8747. The heating system of claim 8730, wherein at least one electrically resistive portion comprises carbon steel.

8748. The heating system of claim 8730, wherein at least one electrically resistive portion comprises iron.

8749. The heating system of claim 8730, wherein the electrically resistive portion comprises a ferromagnetic material, and the ferromagnetic material is coupled to a corrosion resistant material.

8750. The heating system of claim 8730, wherein the electrically resistive portion comprises a ferromagnetic material, and a corrosion resistant material that coated on the ferromagnetic material.

8751. The heating system of claim 8730, wherein the electrically resistive portion comprises one or more bends.

8752. The heating system of claim 8730, wherein the electrically resistive portion comprises a helically shaped portion.

8753. The heating system of claim 8730, wherein the electrically resistive portion is part of an insulated conductor.

8754. The heating system of claim 8730, wherein the electrically resistive portion is part of an insulated conductor, and wherein the insulated conductor is coupled to a support member.

8755. The heating system of claim 8730, wherein the electrically resistive portion is part of a conductor-in-conduit.

8756. The heating system of claim 8730, wherein at least one electrical conductor is electrically coupled to the earth, and wherein electrical current is propagated from the electrical conductor to the earth.

8757. The heating system of claim 8730, wherein the reduced heat output is less than about 800 watts per meter.

8758. The heating system of claim 8730, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat resistance profile in a temperature range between about 100°

C. and 750°

C.

8759. The heating system of claim 8730, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat resistance profile in a temperature range between about 100°

C. and 750°

C., and a relatively sharp resistance profile at a temperature above about 750°

C. and less than about 850°

C.

8760. The heating system of claim 8730, wherein at least one electrical conductor comprises at least one section configured to comprise a relatively flat resistance profile in a temperature range between about 300°

C. and 600°

C.

8761. The heating system of claim 8730, wherein the at least one electrical conductor is greater than about 10 m in length.

8762. The heating system of claim 8730, wherein the at least one electrical conductor is greater than about 50 m in length.

8763. The heating system of claim 8730, wherein the at least one electrical conductor is greater than about 100 m in length.

8764. The heating system of claim 8730, wherein the heating system is configured to sharply reduce heat output at or near the selected temperature.

8765. The heating system of claim 8730, wherein the electrically resistive portion comprises drawn iron.

8766. The heating system of claim 8730, wherein the electrically resistive portion comprises a ferromagnetic material drawn together or against a more conductive material.

8767. The heating system of claim 8730, wherein the electrically resistive portion comprises an elongated conduit comprising iron, wherein a center of the conduit is lined or filled with a material comprising copper or aluminum.

8768. The heating system of claim 8730, wherein the electrically resistive portion comprises an elongated conduit comprising iron, wherein a center of the conduit is lined or filled with a material comprising copper or aluminum, and wherein the copper or aluminum was melted in a center of the conduit and allowed to harden.

8769. The heating system of claim 8730, wherein the electrically resistive portion comprises an elongated conduit comprising a center portion and an outer portion, and wherein the diameter of the center portion is at least about 0.5 cm and comprises iron.

8770. The heating system of claim 8730, wherein the electrically resistive portion comprises an elongated conduit comprising a center portion and an outer portion.

8771. The heating system of claim 8730, wherein the electrically resistive portion comprises an elongated conduit comprising a center portion and an outer portion, and wherein the diameter of the center portion is at least twice the skin depth.

8772. The heating system of claim 8730, wherein the current is an alternating current.

8773. The heating system of claim 8730, wherein at least one of the electrically resistive portions comprises a composite material, wherein the composite material comprises a first material that has a resistance that declines when heated to the selected temperature, and wherein the composite material includes a second material that is more electrically conductive than the first material, and wherein the first material is coupled to the second material.

8774. The heating system of claim 8730, wherein the heating system is configured such that, at or near the selected temperature, the heat output of at least a portion of the heating system declines due to the Curie effect.

8775. The heating system of claim 8730, wherein the electrically resistive portion comprises a magnetic material that, at or near the selected temperature, becomes substantially nonmagnetic.

8776. The heating system of claim 8730, wherein the electrically resistive portion is elongated, and configured such that only portions of the electrically resistive portion that are at or near the selected temperature will automatically reduce heat output.

8777. The heating system of claim 8730, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion increases.

8778. The heating system of claim 8730, configured such that when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion decreases.

8779. The heating system of claim 8730, configured that when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion gradually decreases.

8780. The heating system of claim 8730, configured such that when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion sharply decreases.

8781. The heating system of claim 8730, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion increases, and when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion decreases.

8782. The heating system of claim 8730, configured such that when a temperature of at least one electrically resistive portion is below the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion increases, and when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion decreases, and wherein the selected temperature is a temperature above the boiling point of water but below a failure temperature of one or more heating system components.

8783. The heating system of claim 8730, configured such that when a temperature of at least one electrically resistive portion is above the selected temperature, and such temperature increases, then the resistance of such electrically resistive portion gradually decreases.

8784. A method for treating a hydrocarbon containing formation, comprising:

inhibiting migration of fluids into a first treatment area of the formation from a surrounding portion of the formation, wherein the first treatment area is surrounded, in whole or in part, by one or more openings, and wherein at least one opening comprises a first end that contacts a ground surface at a first location, and a second end that contacts the ground surface at a second location;

heating at least a portion of the first treatment area with heaters to raise a temperature in the first treatment area above a pyrolysis temperature; and

producing a mixture from the formation.

8785. The method of claim 8784, further comprising providing a refrigerant to the one or more openings.

8786. The method of claim 8784, wherein one or more of the openings comprises a first conduit positioned in a second conduit.

8787. The method of claim 8784, wherein at least one opening comprises a first conduit positioned in a second conduit, the method further comprising flowing a refrigerant through the first conduit from the first end of one or more openings towards a second end of one or more openings, and flowing an additional refrigerant through the second conduit from the second end of one or more openings towards the first end of one or more openings.

8788. The method of claim 8787, wherein the refrigerant flowing through the first conduit flows countercurrently to the additional refrigerant flowing through the second conduit.

8789. The method of claim 8787, wherein the refrigerant flowing through the first conduit flows cocurrently to the additional refrigerant flowing through the second conduit.

8790. The method of claim 8784, further comprising using at least one opening that contacts the ground surface at the first location and the second location to form a substantially frozen subsurface barrier.

8791. The method of claim 8784, further comprising forming at least one opening in the formation with a river crossing rig.

8792. The method of claim 8784, wherein the surrounding portion of the formation comprises at least a portion beside the first treatment area of the formation.

8793. The method of claim 8784, wherein the surrounding portion of the formation comprises at least a portion above the first treatment area of the formation.

8794. The method of claim 8784, wherein the surrounding portion of the formation comprises at least a portion below the first treatment area of the formation.

8795. The method of claim 8784, wherein inhibiting migration of fluids comprises providing a barrier to at least a portion of the formation.

8796. The method of claim 8784, wherein inhibiting migration of fluids comprises establishing a barrier in at least a portion of the formation.

8797. The method of claim 8784, further comprising controlling a pressure within the first treatment area.

8798. The method of claim 8784, further comprising controlling a temperature within the first treatment area.

8799. The method of claim 8784, further comprising controlling a heating rate within the first treatment area.

8800. The method of claim 8784, further comprising controlling an amount of fluid removed from the first treatment area.

8801. The method of claim 8784, further comprising establishing a low temperature barrier zone proximate to the first treatment area of the formation.

8802. The method of claim 8784, further comprising using the opening to establish a frozen barrier zone to inhibit migration of fluids into the first treatment area.

8803. The method of claim 8784, further comprising establishing a frozen barrier zone to inhibit migration of fluids out of the first treatment area.

8804. The method of claim 8784, further comprising establishing a frozen barrier zone to inhibit migration of fluids into or out of the first treatment area, wherein the frozen barrier zone is proximate the first treatment area of the formation.

8805. The method of claim 8784, further comprising establishing a frozen barrier zone to inhibit migration of fluids into or out of the first treatment area, wherein at least one or more heaters is positioned greater than about 5 m from a frozen barrier zone.

8806. The method of claim 8784, further comprising establishing a frozen barrier zone to inhibit migration of fluids into or out of the first treatment area, wherein at least one or more heaters is positioned less than about 1.5 m from a frozen barrier zone.

8807. A method for treating a hydrocarbon containing formation, comprising:

forming one or more openings proximate to, or substantially surrounding, in whole or in part, at least a portion of the formation, wherein at least one of the openings comprises a first end that contacts a ground surface at a first location, and a second end that contacts the ground surface at a second location;

forming a low temperature barrier zone using at least one of the openings that comprises a first end that contacts a ground surface at a first location, and a second end that contacts the ground surface at a second location;

heating at least a portion of the formation to pyrolyze at least some hydrocarbons in the formation; and

producing a mixture from the formation.

8808. The method of claim 8807, further comprising providing a refrigerant to the one or more openings that comprise a first end that contacts a ground surface at a first location, and a second end that contacts the ground surface at a second location.

8809. The method of claim 8807, wherein one or more of the openings comprise a first conduit positioned in a second conduit.

8810. The method of claim 8807, wherein at least one opening comprises a first conduit positioned in a second conduit, the method further comprising flowing a refrigerant through the first conduit from the first end of one or more openings towards a second end of one or more openings, and flowing an additional refrigerant through the second conduit from the second end of one or more openings towards the first end of one or more openings.

8811. The method of claim 8810, wherein the refrigerant flowing through the first conduit flows countercurrently to the additional refrigerant flowing through the second conduit.

8812. The method of claim 8810, wherein the refrigerant flowing through the first conduit flows cocurrently to the additional refrigerant flowing through the second conduit.

8813. The method of claim 8807, further comprising forming at least one opening in the formation with a river crossing rig.

8814. The method of claim 8807, wherein the low temperature barrier zone is proximate to at least a portion of the formation being heated.

8815. The method of claim 8807, wherein the low temperature barrier zone is above at least a portion of the formation being heated.

8816. The method of claim 8807, wherein the low temperature barrier zone is below at least a portion of the formation being heated.

8817. The method of claim 8807, further comprising controlling a pressure in at least part of the formation being heated.

8818. The method of claim 8807, further comprising controlling a temperature in at least part of the formation being heated.

8819. The method of claim 8807, further comprising controlling a heating rate in at least part of the formation being heated.

8820. The method of claim 8807, further comprising establishing a frozen barrier zone to inhibit migration of fluids in or out of the portion of the formation being heated.

8821. The method of claim 8807, further comprising establishing a frozen barrier zone to inhibit migration of fluids in or out of the portion of the formation being heated, wherein the frozen barrier zone is proximate the portion of the formation being heated.

8822. The method of claim 8807, further comprising establishing a frozen barrier zone to inhibit migration of fluids in or out of the portion of the formation being heated, wherein at least one or more heaters is positioned greater than about 5 m from a frozen barrier zone.

8823. The method of claim 8807, further comprising establishing a frozen barrier zone to inhibit migration of fluids in or out of the portion of the formation being heated, wherein at least one or more heaters is positioned less than about 1.5 m from a frozen barrier zone.

8824. A method of forming a subsurface barrier in a subsurface formation, comprising:

positioning a conduit in an opening in a part of the formation;

positioning one or more baffles in an annulus formed between a wall of the conduit and a wall of the opening to inhibit a flow of fluids in the annulus; and

using the opening to form the subsurface barrier in the formation.

8825. The method of claim 8824, wherein at least one baffle comprises rubberized metal.

8826. The method of claim 8824, wherein inhibiting the flow of fluids assists in establishing the barrier in the formation.

8827. The method of claim 8824, wherein at least one baffle is a cement catcher.

8828. The method of claim 8824, further comprising flowing refrigerant through the conduit to form a low temperature barrier.

8829. The method of claim 8824, further comprising flowing refrigerant through the conduit to form a frozen barrier.

8830. A system configured to heat at least a part of a hydrocarbon containing formation, comprising:

a heater configured to be placed in an opening in the formation;

wherein the system is configured to allow heat to transfer from the heater to a part of the formation to pyrolyze at least some hydrocarbons in the formation; and

wherein the system is configured such that the heater can be removed from the opening in the formation and redeployed in at least one alternative opening in the formation.

8831. The system of claim 8830, wherein the heater comprises an insulated conductor heater.

8832. The system of claim 8830, wherein the heater comprises a conductor-in-conduit heater.

8833. The system of claim 8830, wherein the heater comprises a natural distributed combustor heater.

8834. The system of claim 8830, wherein the heater comprises a flameless distributed combustor heater.

8835. The system of claim 8830, wherein the opening in the formation comprises an open wellbore.

8836. The system of claim 8830, wherein the opening in the formation comprises an uncased wellbore.

8837. The system of claim 8830, wherein the heater is configured to be removed using a spool.

8838. The system of claim 8830, wherein the heater is configured to be removed using coiled tubing removal.

8839. The system of claim 8830, wherein the heater is configured to be installed using a spool.

8840. The system of claim 8830, wherein the heater is configured to be installed using a coiled tubing installation.

8841. The system of claim 8830, wherein the opening comprises a diameter of at least approximately 5 cm, and wherein the system is configured to fit in the opening.

8842. The system of claim 8830, wherein the opening comprises a diameter of at least approximately 7 cm, and wherein the system is configured to fit in the opening.

8843. The system of claim 8830, wherein the opening comprises a diameter of at least approximately 10 cm, and wherein the system is configured to fit in the opening.

8844. The system of claim 8830, wherein the heater is configured to be removed from the opening to repair the heater.

8845. The system of claim 8830, wherein the heater is configured to be removed from the opening to replace the heater with another heater.

8846. A method for installing a heater of a desired length in a hydrocarbon containing formation, comprising:

placing at least a portion of a heater of a desired length in an opening in a hydrocarbon containing formation, wherein placing the heater in the opening comprises uncoiling at least a portion of the heater while placing the heater in the opening; and

wherein the heater is configured such that the heater can be removed from the opening in the formation and redeployed in at least one alternative opening in the formation.

8847. The method of claim 8846, further comprising assembling the heater of the desired length, wherein the assembling of the heater of the desired length is performed at a location proximate the hydrocarbon containing formation.

8848. The method of claim 8847, further comprising coiling the heater of the desired length after forming the heater.

8849. The method of claim 8846, wherein the heater is configurable to allow heat to transfer from the heater to a part of the formation.

8850. The method of claim 8846, wherein the heater comprises an insulated conductor heater.

8851. The method of claim 8846, wherein the heater comprises a conductor-in-conduit heater.

8852. The method of claim 8846, wherein the heater comprises a natural distributed combustor heater.

8853. The method of claim 8846, wherein the heater comprises a flameless distributed combustor heater.

8854. The method of claim 8846, wherein the opening in the formation comprises an open wellbore.

8855. The method of claim 8846, wherein the opening in the formation comprises an uncased wellbore.

8856. The method of claim 8846, wherein the heater is configurable to be removed using a spool.

8857. The method of claim 8846, wherein the heater is configurable to be removed using coiled tubing removal.

8858. The method of claim 8846, wherein the heater is configurable to be installed using a spool.

8859. The method of claim 8846, wherein the heater is configurable to be installed using a coiled tubing installation.

8860. The method of claim 8846, wherein the opening comprises a diameter of at least approximately 5 cm, and wherein the heater is configurable to fit in the opening.

8861. The method of claim 8846, wherein the opening comprises a diameter of at least approximately 7 cm, and wherein the heater is configurable to fit in the opening.

8862. The method of claim 8846, wherein the opening comprises a diameter of at least approximately 10 cm, and wherein the heater is configurable to fit in the opening.

8863. The method of claim 8846, wherein the heater is configurable to be removed from the opening to repair the heater.

8864. The method of claim 8846, wherein the heater is configurable to be removed from the opening to replace the heater with another heater.

8865. The method of claim 8846, further comprising coupling at least one low resistance conductor to the heater, wherein at least one low resistance conductor is configured to be placed in an overburden of the formation.

8866. The method of claim 8846, further comprising removing at least a portion of the heater from the opening by recoiling at least a portion of the heater.

8867. The method of claim 8846, further comprising coiling the heater on a spool.

8868. The method of claim 8846, further comprising uncoiling the heater on a spool.

8869. The method of claim 8846, further comprising transporting the heater on a cart from an assembly location to the opening in the hydrocarbon containing formation.

8870. The method of claim 8846, further comprising transporting the heater on a train from an assembly location to the opening in the hydrocarbon containing formation.

8871. The method of claim 8846, further comprising transporting the heater on a cart from an assembly location to the opening in the hydrocarbon containing formation, wherein the cart can be further used to transport more than one heater to more than one opening in the hydrocarbon containing formation.

8872. The method of claim 8846, further comprising transporting the heater on a train from an assembly location to the opening in the hydrocarbon containing formation, wherein the train can be further used to transport more than one heater to more than one opening in the hydrocarbon containing formation.

8873. The method of claim 8846, further comprising removing the heater from the opening in the formation to inspect the heater and reinstall the heater in the opening.

8874. The method of claim 8846, further comprising removing the heater from the opening in the formation to repair the heater and reinstall the heater in the opening.

8875. The method of claim 8846, further comprising removing the heater from the opening in the formation to redeploy the heater in at least one alternative opening in the formation.

8876. The method of claim 8846, further comprising removing the heater from the opening in the formation to replace at least a portion of the heater.

8877. A method of treating at least a part of a hydrocarbon containing formation in situ, comprising:

placing one or more heaters in one or more openings;

providing heat from one or more of the heaters to at least one part of the formation;

allowing the heat to transfer from one or more of the heaters to a part of the formation;

removing one or more of the heaters from one or more of the openings; and

redeploying one or more of the heaters removed from the one or more openings in one or more alternate openings.

8878. The method of claim 8877, further comprising pyrolyzing at least some hydrocarbons in the formation.

8879. The method of claim 8877, further comprising producing a mixture from the formation.

8880. The method of claim 8877, wherein one or more of the heaters comprises an insulated conductor heater.

8881. The method of claim 8877, wherein one or more of the heaters comprises a conductor-in-conduit heater.

8882. The method of claim 8877, wherein one or more of the heaters comprises a natural distributed combustor heater.

8883. The method of claim 8877, wherein one or more of the heaters comprises a flameless distributed combustor heater.

8884. The method of claim 8877, wherein one or more of the openings in the formation comprises an uncased wellbore.

8885. The method of claim 8877, wherein one or more of the openings in the formation comprises an open wellbore.

8886. The method of claim 8877, wherein one or more of the heaters is configured to be removed using a spool.

8887. The method of claim 8877, wherein one or more of the heaters is configured to be removed using coiled tubing removal.

8888. The method of claim 8877, wherein one or more of the heaters is configured to be installed using a spool.

8889. The method of claim 8877, wherein one or more of the heaters is configured to be installed using a coiled tubing installation.

8890. The method of claim 8877, wherein one or more of the openings comprise a diameter of at least approximately 5 cm, and wherein the system is configured to fit in the one or more openings.

8891. The method of claim 8877, wherein one or more of the openings comprise a diameter of at least approximately 7 cm, and wherein the system is configured to fit in the one or more openings.

8892. The method of claim 8877, wherein one or more of the openings comprise a diameter of at least approximately 10 cm, and wherein the system is configured to fit in the one or more openings.

8893. The method of claim 8877, wherein one or more of the heaters is configured to be removed from one or more of the openings to repair the one or more heaters.

8894. The method of claim 8877, wherein one or more of the heaters is configured to be removed from one or more of the openings to replace the one or more heaters with another heater.

8895. The method of claim 8877, further comprising maintaining a temperature within at least a portion of the formation within a pyrolysis temperature range with a lower pyrolysis temperature of about 250°

C. and an upper pyrolysis temperature of about 400 °

C.

8896. The method of claim 8877, further comprising heating at least a part of the formation to substantially pyrolyze at least some of the hydrocarbons within the formation.

8897. The method of claim 8877, further comprising controlling a pressure and a temperature within at least a majority of the part of the formation, wherein the pressure is controlled as a function of temperature.

8898. The method of claim 8877, further comprising controlling a pressure and a temperature within at least a majority of the part of the formation, wherein the temperature is controlled as a function of pressure.

8899. The method of claim 8877, wherein allowing the heat to transfer from the one or more heaters to the part of the formation comprises transferring heat substantially by conduction.

8900. The method of claim 8877, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8901. The method of claim 8877, further comprising controlling a pressure within at least a majority of a part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8902. The method of claim 8877, further comprising controlling formation conditions such that the produced mixture comprises a partial pressure of H₂ within the mixture greater than about 0.5 bars.

8903. An in situ method for heating a hydrocarbon containing formation, comprising:

providing heat from one or more heaters to an opening in the formation, wherein a first end of the opening contacts the earth'"'"'s surface at a first location, and wherein a second end of the opening contacts the earth'"'"'s surface at a second location; and

allowing the heat to transfer from the opening to at least a part of the formation to pyrolyze at least some hydrocarbons in the formation.

8904. The method of claim 8903, wherein providing heat to the opening comprises providing heat from at least one heater to the opening.

8905. The method of claim 8903, wherein providing heat to the opening comprises providing heated materials from at least one heater to the opening.

8906. The method of claim 8903, wherein providing heat to the opening comprises providing oxidation products from at least one heater to the opening.

8907. The method of claim 8903, further comprising allowing the heat to transfer from a conduit positioned in at least a portion of the opening.

8908. The method of claim 8907, further comprising allowing the heat to transfer from the conduit and through an annulus formed between a wall of the opening and a wall of the conduit.

8909. The method of claim 8903, wherein at least one heater comprises an oxidizer, the method further comprising:

providing fuel to the oxidizer; and

oxidizing at least some of the fuel.

8910. The method of claim 8909, further comprising allowing heat to migrate through the opening, and thereby transfer heat to at least a part of the formation.

8911. The method of claim 8909, further comprising allowing heat to migrate through the conduit, and thereby transfer heat to at least a part of the formation.

8912. The method of claim 8909, further comprising allowing heat to migrate through the annulus, and thereby transfer heat to at least a part of the formation.

8913. The method of claim 8909, further comprising recycling at least some fuel to at least one additional oxidizer.

8914. The method of claim 8903, wherein at least one heater comprises a surface unit, the method further comprising heating a fluid or other material using the surface unit.

8915. The method of claim 8914, allowing the heated fluid or other material to migrate through the opening, and thereby transfer heat to at least a part of the formation.

8916. The method of claim 8914, allowing the heated fluid or other material to migrate through the conduit, and thereby transfer heat to at least a part of the formation.

8917. The method of claim 8914, allowing the heated fluid or other material to migrate through the annulus, and thereby transfer heat to at least a part of the formation.

8918. The method of claim 8903, further comprising:

providing fuel to a conduit positioned in the opening;

providing an oxidizing fluid to the opening;

oxidizing fuel in at least one oxidizer positioned in, or coupled to, the conduit; and

allowing the heat to transfer to at least a part of the formation.

8919. The method of claim 8903, further comprising providing oxidation products to the opening proximate the first location, and then allowing the oxidation products to exit the opening proximate the second location.

8920. The method of claim 8903, further comprising providing a fluid such as steam to the opening in order to inhibit coking in or proximate the opening.

8921. The method of claim 8903, further comprising controlling a pressure and a temperature within at least a majority of the part of the formation, wherein the pressure is controlled as a function of temperature.

8922. The method of claim 8903, further comprising controlling a pressure and a temperature within at least a majority of the part of the formation, wherein the temperature is controlled as a function of pressure.

8923. The method of claim 8903, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

8924. The method of claim 8903, further comprising controlling a pressure within at least a majority of the part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute.

8925. The method of claim 8903, further comprising controlling formation conditions such that a produced mixture comprises a partial pressure of H₂ within the mixture greater than about 0.5 bars.

8926. The method of claim 8903, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.

8927. The method of claim 8903, wherein at least a portion of the part of the formation is heated to a minimum pyrolysis temperature of about 270°

C.

8928. A system for in situ heating of a hydrocarbon containing formation, comprising:

one or more heaters configurable to provide heat to at least a part of the formation by transferring heat to an opening in the formation, wherein a first end of the opening contacts the earth'"'"'s surface at a first location, and wherein a second end of the opening contacts the earth'"'"'s surface at a second location; and

wherein heat transferred from the opening is configured to pyrolyze at least some hydrocarbons in the formation.

8929. The system of claim 8928, wherein transferring heat to the opening in the formation comprises providing heat to the opening.

8930. The system of claim 8928, wherein transferring heat to the opening in the formation comprises providing heated materials to the opening.

8931. The system of claim 8928, wherein transferring heat to the opening in the formation comprises providing oxidation products to the opening.

8932. The system of claim 8928, further comprising a casing positioned in at least a portion of the opening.

8933. The system of claim 8928, wherein at least one heater is an oxidizer located in the opening, or coupled to the opening.

8934. The system of claim 8928, wherein the heaters comprise at least a first oxidizer and a second oxidizer.

8935. The system of claim 8928, wherein heat from the first oxidizer flow through the opening from the first end towards the second end and heat from the second oxidizer flow through the opening from the second end towards the first end.

8936. The system of claim 8928, further comprising a conduit positionable in at least a portion of the opening.

8937. The system of claim 8936, wherein transferring heat to the opening in the formation comprises providing heat to the conduit.

8938. The system of claim 8936, wherein the heaters comprise at least a first oxidizer and a second oxidizer.

8939. The system of claim 8938, wherein the second oxidizer is positioned in, or coupled to, the conduit, and wherein the second oxidizer is configured to provide heat to at least a part of the formation.

8940. The system of claim 8938, wherein heat from the first oxidizer flow through the opening from the first end towards the second end and heat from the second oxidizer flow through the opening from the second end towards the first end.

8941. The system of claim 8928, wherein at least one heater comprises an oxidizer configurable to oxidize fuel to generate heat, the system further comprising a recycle conduit configurable to recycle at least some of the fuel flowing with oxidation products from the oxidizer to at least one additional oxidizer.

8942. The system of claim 8936, further comprising an annulus formed between a wall of the conduit and a wall of the opening.

8943. The system of claim 8942, wherein transferring heat to the opening in the formation comprises providing heat to the annulus.

8944. The system of claim 8942, wherein the heaters comprise one or more oxidizers positioned in the annulus and coupled to the conduit, wherein a fuel is provided to the conduit, and wherein the fuel flows through the conduit to the oxidizers.

8945. The system of claim 8942, wherein at least one oxidizer is positioned in, or coupled to, the annulus, and wherein at least one oxidizer is configured to provide heat to at least a part of the formation.

8946. The system of claim 8945, further comprising a first oxidizer positioned in or coupled to the annulus, and a second oxidizer positioned in or coupled to the conduit.

8947. The system of claim 8946, wherein heat from the first oxidizer flows to the annulus and countercurrent to heat that flows to the conduit from the second oxidizer.

8948. The system of claim 8946, further comprising:

a first recycle conduit configurable to recycle at least some fuel in the annulus to the second oxidizer; and

a second recycle conduit configurable to recycle at least some fuel in the conduit to the first oxidizer.

8949. The system of claim 8928, further comprising a second conduit positionable in the opening, and one or more heaters configurable to provide heat through the second conduit to at least a part of the formation.

8950. The system of claim 8949, wherein the heaters comprise at least a first oxidizer configurable to provide heat to at least a part of the formation by providing heat to the conduit, and a second oxidizer configurable to provide heat to at least a part of the formation by providing heat to the second conduit.

8951. The system of claim 8950, wherein the first oxidizer is positionable in the conduit, or the second oxidizer is positionable in the second conduit.

8952. The system of claim 8950, wherein oxidation products from the first oxidizer flow in a direction opposite to a flow of oxidation products from the second oxidizer.

8953. The system of claim 8928, wherein at least one heater comprises an oxidizer, and further comprising insulation positionable proximate the oxidizer.

8954. The system of claim 8928, wherein at least one heater comprises an oxidizer, and wherein at least one oxidizer comprises a ring burner or an inline burner.

8955. The system of claim 8928, wherein at least one of the heaters is a surface unit configurable to provide heat to the opening.

8956. The system of claim 8955, further comprising a first surface unit configured to provide heat, heated materials, or oxidation products to the opening or a conduit at the first location, and a second surface unit configured to provide heat to the opening or a conduit at the second location.

8957. The system of claim 8928, wherein heat from the first oxidizer flows in a direction opposite of heat.

8958. The system of claim 8928, wherein the system is configured to provide heat to a selected section of the formation and pyrolyze at least a part of the hydrocarbons in the selected section.