In situ thermal processing of an oil reservoir formation

• US 7,077,199 B2
• Filed: 10/24/2002
• Issued: 07/18/2006
• Est. Priority Date: 10/24/2001
• Status: Expired due to Fees

• Current Assignee: Shell Oil Company (Shell Plc)
• Original Assignee: Shell Oil Company (Shell Plc)
• Inventors: de Rouffignac, Eric P., Vinegar, Harold J., Wellington, Scott Lee, Ryan, Robert Charles, Fowler, Thomas David, Berchenko, Ilya Emil, Zhang, Etuan
• Primary Examiner(s): SUCHFIELD, GEORGE A
• Application Number:
  US10/279,230
• Publication Number:
  US 20030173081A1
• Time in Patent Office: 1,363 Days
• Field of Search: 166/50, 166/57, 166/59, 166/60, 166/245, 166/250.01, 166/250.07, 166/257, 166/263, 166/265, 166/266, 166/267, 166/268, 166/272.1, 166/272.3, 166/272.6, 166/272.7, 166/302, 166/303
• US Class Current: 166/250.01
• CPC Class Codes: E21B 43/243 Combustion in situ

Abstract

An in situ process for treating an oil containing formation is provided. The process may include providing heat from one or more heaters to at least a portion of the formation. The heat may be allowed to transfer from the one or more heaters to a part of the formation such that heat from the one or more heat sources pyrolyzes at least some hydrocarbons within the part. Hydrocarbons may be produced from the formation.

Claims

1. A method of treating an oil containing formation in situ, comprising:

injecting a recovery fluid into the formation;

providing heat from heaters to the formation;

allowing the heat to transfer from the heaters to a selected section of the formation, wherein the selected section comprises hydrocarbons, and wherein the hydrocarbons comprise oil from the oil containing formation;

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°

.

2. The method of claim 1, wherein the heat provided from at least one of the heaters is transferred to at least a portion of the formation substantially by conduction.

3. The method of claim 1, 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.

4. The method of claim 1, further comprising pyrolyzing at least some of the hydrocarbons in the selected section.

5. The method of claim 1, further comprising pyrolyzing at least some of the mobilized hydrocarbons.

6. The method of claim 1, wherein the recovery fluid comprises water.

7. The method of claim 1, wherein the recovery fluid comprises hydrocarbons.

8. The method of claim 1, wherein the mixture comprises pyrolyzation fluids.

9. The method of claim 1, wherein the mixture further comprises steam.

10. The method of claim 1, wherein producing the mixture from the formation comprises producing a fluid from the formation, 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.

11. The method of claim 1, wherein superposition of heat from two of the heaters pyrolyzes at least some hydrocarbons in the selected section of the formation.

12. The method of claim 1, wherein the heat is provided such that an average temperature in the selected section ranges from 270°

C. to about 375°

C.

13. The method of claim 1, 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.

14. The method of claim 13, wherein the pressure is controlled by a valve proximate to a location where the mixture is produced.

15. The method of claim 13, 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.

16. The method of claim 1, wherein a residence time of the recovery fluid in the formation is greater than about one month and less than about six months.

17. The method of claim 1, 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.

18. A method of treating an oil containing formation in situ, comprising:

injecting a heated recovery fluid into the 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 hydrocarbons in the selected section of the formation, and wherein at least before pyrolyzation the hydrocarbons comprise oil from the oil containing formation;

allowing the heat from the recovery fluid or at least one of the heaters to mobilize at least some of the hydrocarbons at the recovery fluid front;

allowing the heat from the recovery fluid, and heat from at least one of the heaters, to pyrolyze at least a portion of the hydrocarbons in the mobilized fluid; and

producing a mixture from the formation.

19. The method of claim 18, wherein the mixture is produced as a mixture of vapors.

20. The method of claim 18, wherein an average temperature of the selected section is about 300°

C., and wherein a pressure of the recovery fluid is about 90 bars.

21. The method of claim 18, wherein the mobilized hydrocarbons flow substantially parallel to the recovery fluid front.

22. The method of claim 18, wherein the mixture is produced from an upper portion of the formation.

23. The method of claim 18, 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.

24. The method of claim 18, wherein the mobilized fluid with the pyrolyzed hydrocarbons migrates to an upper portion of the formation.

25. The method of claim 18, wherein the mixture comprises pyrolyzation fluids.

26. The method of claim 18, wherein the mixture comprises recovery fluid.

27. The method of claim 18, wherein the recovery fluid comprises steam.

28. The method of claim 18, wherein the recovery fluid is injected through one or more injection wells.

29. The method of claim 22, wherein a portion of one or more of the injection wells is oriented substantially horizontally in a hydrocarbon containing portion of the formation.

30. The method of claim 22, wherein a portion of one or more of the injection wells is oriented substantially vertically in a hydrocarbon containing portion of the formation.

31. The method of claim 18, wherein the mixture is produced through one or more production wells.

32. The method of claim 31, wherein a portion of one or more of the production wells is oriented substantially horizontally in a hydrocarbon containing portion of the formation.

33. The method of claim 18, wherein the mixture is produced through a heater wellbore.

34. The method of claim 18, wherein the produced mixture comprises hydrocarbons having an average API gravity of at least about 25°

.

35. The method of claim 18, wherein heat from one or more of the heaters transfers to the formation substantially radiatively.

36. The method of claim 18, further comprising injecting water into the formation, and wherein the heat from one or more of the heaters vaporizes water injected into the formation.

37. The method of claim 18, wherein the heat from one or more of the heaters heats recovery fluid in the formation, wherein the recovery fluid comprises steam.

38. The method of claim 18, wherein at least one of the heaters comprises an electrical heater.

39. The method of claim 18, wherein at least one of the heaters comprises a flameless distributed combustor.

40. The method of claim 18, wherein at least one of the heaters comprises a natural distributed combustor.

41. The method of claim 18, further comprising separating recovery fluid from pyrolyzation fluids in the formation.

42. The method of claim 18, further comprising producing liquid hydrocarbons from the formation, and further comprising reinjecting at least a portion of the produced liquid hydrocarbons into the formation.

43. The method of claim 18, further comprising producing a liquid mixture from the formation, wherein the produced liquid mixture comprises condensed recovery fluid.

44. The method of claim 18, further comprising separating condensed recovery fluid from liquid hydrocarbons in the formation, and further comprising producing the condensed recovery fluid from the formation.

45. The method of claim 18, wherein the recovery fluid is injected into regions of relatively high water saturation.

46. The method of claim 18, wherein injected recovery fluid contacts a substantial portion of a volume of the selected section.

47. The method of claim 18, 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.

48. The method of claim 18, wherein the formation comprises sulfur, wherein at least a portion of sulfur is retained in the formation after producing the mixture from the formation.

49. The method of claim 18, wherein the heat from the recovery fluid partially upgrades at least a portion of the hydrocarbons in the selected section of the formation, and wherein the partial upgrading reduces the viscosity of the portion of the hydrocarbons.

50. The method of claim 18, further comprising allowing some hydrocarbons to vaporize in the formation, wherein the recovery fluid and the vaporized hydrocarbons are separated with membranes.

51. The method of claim 18, wherein a residence time of the recovery fluid in the formation is greater than about one month and less than about six months.

52. The method of claim 18, further comprising:

allowing the heated 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.

53. The method of claim 18, wherein the heat provided from at least one of the heaters is transferred to at least a portion of the formation substantially by conduction.

54. The method of claim 18, 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.

55. The method of claim 18, wherein the recovery fluid comprises water.

56. The method of claim 18, wherein the recovery fluid comprises hydrocarbons.

57. The method of claim 18, wherein the mixture further comprises steam.

58. The method of claim 18, wherein producing a mixture from the formation comprises producing a fluid from the formation, 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.

59. The method of claim 18, wherein the heat is provided such that an average temperature in the selected section ranges from about 270°

C. to about 375°

C.

60. The method of claim 18, 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.

61. The method of claim 60, wherein the pressure is controlled by a valve proximate to a location where the mixture is produced.

62. The method of claim 60, 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.

63. The method of claim 18, wherein superposition of heat from at least two of the heaters pyrolyzes at least some hydrocarbons in the selected section of the formation.

64. A method of treating a heavy oil containing formation in situ, comprising:

injecting a heated recovery fluid into the 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 hydrocarbons in the selected section of the formation, and wherein at least before pyrolyzation the hydrocarbons comprise oil from the oil containing formation;

allowing the heat from the recovery fluid or at least one of the heaters to mobilize at least some of the hydrocarbons at the recovery fluid front;

allowing the heat from the recovery fluid, and heat from at least one of the heaters, to pyrolyze at least a portion of the hydrocarbons in the mobilized fluid; and

producing a mixture from the formation.

65. The method of claim 64, wherein the mixture is produced as a mixture of vapors.

66. The method of claim 64, wherein an average temperature of the selected section is about 300°

C., and wherein a pressure of the recovery fluid is about 90 bars.

67. The method of claim 64, wherein the mobilized hydrocarbons flow substantially parallel to the recovery fluid front.

68. The method of claim 64, wherein the mixture is produced from an upper portion of the formation.

69. The method of claim 64, 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.

70. The method of claim 64, wherein the mobilized fluid with the pyrolyzed hydrocarbons migrates to an upper portion of the formation.

71. The method of claim 64, wherein the mixture comprises pyrolyzation fluids.

72. The method of claim 64, wherein the mixture comprises recovery fluid.

73. The method of claim 64, wherein the recovery fluid comprises steam.

74. The method of claim 64, wherein the recovery fluid is injected through one or more injection wells.

75. The method of claim 74, wherein a portion of one or more of the injection wells is oriented substantially horizontally in a hydrocarbon containing portion of the formation.

76. The method of claim 74, wherein a portion of one or more of the injection wells is oriented substantially vertically in a hydrocarbon containing portion of the formation.

77. The method of claim 64 wherein the mixture is produced through one or more production wells.

78. The method of claim 77, wherein a portion of one or more of the production wells is oriented substantially horizontally in a hydrocarbon containing portion of the formation.

79. The method of claim 64, wherein the mixture is produced through a heater wellbore.

80. The method of claim 64, wherein the produced mixture comprises hydrocarbons having an average API gravity of at least about 25°

.

81. The method of claim 64, wherein heat from one or more of the heaters transfers to the formation substantially radiatively.

82. The method of claim 64, further comprising injecting water into the formation, and wherein the heat from one or more of the heaters vaporizes water injected into the formation.

83. The method of claim 64, wherein the heat from one or more of the heaters heats recovery fluid in the formation, wherein the recovery fluid comprises steam.

84. The method of claim 64, wherein at least one of the heaters comprises an electrical heater.

85. The method of claim 64, further comprising separating recovery fluid from pyrolyzation fluids in the formation.

86. The method of claim 64, further comprising producing liquid hydrocarbons from the formation, and further comprising reinjecting at least a portion of the produced liquid hydrocarbons into the formation.

87. The method of claim 64, further comprising producing a liquid mixture from the formation, wherein the produced liquid mixture comprises condensed recovery fluid.

88. The method of claim 64, further comprising separating condensed recovery fluid from liquid hydrocarbons in the formation, and further comprising producing the condensed recovery fluid from the formation.

89. The method of claim 64, wherein the recovery fluid is injected into regions of relatively high water saturation.

90. The method of claim 64, wherein injected recovery fluid contacts a substantial portion of a volume of the selected section.

91. The method of claim 64, 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.

92. The method of claim 64, wherein the formation comprises sulfur, wherein at least a portion of sulfur is retained in the formation after producing the mixture from the formation.

93. The method of claim 64, wherein the heat from the recovery fluid partially upgrades at least a portion of the hydrocarbons in the selected section of the formation, and wherein the partial upgrading reduces the viscosity of the portion of the hydrocarbons.

94. The method of claim 64, further comprising allowing some hydrocarbons to vaporize in the formation, wherein the recovery fluid and the vaporized hydrocarbons are separated with membranes.

95. The method of claim 64, wherein a residence time of the recovery fluid in the formation is greater than about one month and less than about six months.

96. The method of claim 64, further comprising:

allowing the heated 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.

97. The method of claim 64, wherein the heat provided from at least one of the heaters is transferred to at least a portion of the formation substantially by conduction.

98. The method of claim 64, 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.

99. The method of claim 64, wherein the recovery fluid comprises water.

100. The method of claim 64, wherein the recovery fluid comprises hydrocarbons.

101. The method of claim 64, wherein the mixture further comprises steam.

102. The method of claim 64, wherein producing a mixture from the formation comprises producing a fluid from the formation, 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.

103. The method of claim 64, wherein the heat is provided such that an average temperature in the selected section ranges from about 270°

C. to about 375°

C.

104. The method of claim 64, 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.

105. The method of claim 104, wherein the pressure is controlled by a valve proximate to a location where the mixture is produced.

106. The method of claim 64, 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.

107. The method of claim 64, wherein superposition of heat from at least two of the heaters pyrolyzes at least some hydrocarbons in the selected section of the formation.