Thermal processing of an oil shale formation to increase permeability of the formation

• US 7,040,397 B2
• Filed: 04/24/2002
• Issued: 05/09/2006
• Est. Priority Date: 04/24/2001
• Status: Expired due to Fees

• Current Assignee: Shell Oil Company (Shell Plc)
• Original Assignee: Shell Oil Company (Shell Plc)
• Inventors: de Rouffignac, Eric Pierre, Vinegar, Harold J., Wellington, Scott Lee, Ryan, Robert Charles, Fowler, Thomas David, Stegemeier, George Leo, Berchenko, Ilya Emil, Zhang, Etuan, Shahin, Gordon Thomas Jr.
• Primary Examiner(s): SUCHFIELD, GEORGE A
• Application Number:
  US10/128,699
• Publication Number:
  US 20030141067A1
• Time in Patent Office: 1,476 Days
• Field of Search: 166/57, 166/60, 166/245, 166/251.1, 166/256, 166/259, 166/261, 166/266, 166/267, 166/272.1, 166/272.2, 166/302, 166/303, 166/308
• US Class Current: 166/245
• 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 43/247 in association with fracturing processes or crevice forming processes
• CPC Class Codes: E21B 43/30 Specific pattern of wells, e.g. optimising the spacing of wells

Abstract

An oil shale formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H₂, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. Heat may also be applied to the formation to increase a permeability of the formation. In some embodiments, the permeability of a portion of the formation may increase to a relatively high permeability as compared to the initial permeability.

Claims

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

providing heat from one or more heaters disposed in the formation to at least a section of the formation such that an average heating rate of the section of the formation is less than about 1°

C. per day in a pyrolysis temperature range; and

allowing the heat to transfer from the one or more heaters to a part of the formation such that a permeability of at least a portion of the part of the formation increases to greater than about 100 millidarcy.

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 in the part of the formation.

3. The method of claim 1, further comprising maintaining a temperature in the part of the formation in a pyrolysis temperature range of about 270°

C. to about 400°

C.

4. The method of claim 1, wherein at least one of the heaters comprises an electrical heater.

5. The method of claim 1, wherein at least one of the heaters comprises a surface burner.

6. The method of claim 1, wherein at least one of the heaters comprises a flameless distributed combustor.

7. The method of claim 1, wherein at least one of the heaters comprises a natural distributed combustor.

8. The method of claim 1, 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.

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

heating a selected volume (V) of the oil shale 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 in 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 less than about 1°

C./day.

10. The method of claim 1, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.

11. The method of claim 1, wherein providing heat from the one or more heaters increases a thermal conductivity of at least a portion of the part of the formation to greater than about 0.5 W/(m°

C.).

12. The method of claim 1, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°

.

13. The method of claim 1, 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.

14. The method of claim 1, 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.

15. The method of claim 1, 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.

16. The method of claim 1, 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.

17. The method of claim 1, 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.

18. The method of claim 1, 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.

19. The method of claim 1, 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.

20. The method of claim 1, 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.

21. The method of claim 1, 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.

22. The method of claim 1, 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.

23. The method of claim 1, further comprising producing a mixture from the formation, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises molecular hydrogen, wherein the molecular hydrogen is greater than about 10% by volume of the non-condensable component at 25°

C. and one atmosphere absolute pressure, and wherein the molecular hydrogen is less than about 80% by volume of the non-condensable component at 25°

C. and one atmosphere absolute pressure.

24. The method of claim 1, 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.

25. The method of claim 1, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.

26. The method of claim 1, 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.

27. The method of claim 1, further comprising controlling formation conditions to produce a mixture from the formation, wherein a partial pressure of H₂ in the mixture is greater than about 0.5 bars.

28. The method of claim 27, further comprising producing a mixture from the formation, wherein the partial pressure of H₂ in the mixture is measured when the mixture is at a production well.

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

30. The method of claim 1, further comprising producing a mixture from the formation and controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.

31. The method of claim 1, further comprising:

providing hydrogen (H₂) to the part of the formation to hydrogenate hydrocarbons in the part of the formation; and

heating a portion of the part of the formation with heat from hydrogenation.

32. The method of claim 1, further comprising:

producing hydrogen (H₂) and condensable hydrocarbons from the formation; and

hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.

33. The method of claim 1, further comprising increasing a permeability of a majority of the part of the formation to greater than about 5 Darcy.

34. The method of claim 1, wherein allowing the heat to transfer increases a permeability of a majority of the part of the formation such that the permeability of the majority of the part is substantially uniform.

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

36. The method of claim 1, 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.

37. The method of claim 36, wherein at least about 20 heaters are disposed in the formation for each production well.

38. 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.

39. 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.

40. A method of treating an oil shale formation in situ, comprising:

providing heat from one or more heaters disposed in the formation to at least a section of the

formation; and

allowing the heat to transfer from the one or more heaters to a part of the formation such that an average heating rate of the part of the formation is less than about 1°

C. per day in a pyrolysis temperature range and such that a permeability of a majority of at least a portion of the part of the formation increases substantially uniformly.

41. The method of claim 40, wherein the pyrolysis temperature range is between about 270°

C. and about 400°

C.

42. The method of claim 40, wherein at least one of the heaters comprises an electrical heater.