In situ thermal processing of an oil shale formation using a natural distributed combustor

• US 7,013,972 B2
• Filed: 04/24/2002
• Issued: 03/21/2006
• 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: Karanikas, John Michael, de Rouffignac, Eric Pierre, Coles, John Matthew, Vinegar, Harold J., Wellington, Scott Lee, Van Hardeveld, Robert Martijn, Menotti, James Louis
• Primary Examiner(s): SUCHFIELD, GEORGE A
• Application Number:
  US10/131,050
• Publication Number:
  US 20030148894A1
• Time in Patent Office: 1,427 Days
• Field of Search: 166/57, 166/60, 166/242.1, 166/245, 166/251.1, 166/256, 166/257, 166/261, 166/272.1, 166/272.2, 166/302, 166/308, 299/2
• US Class Current: 166/257
• 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 be supplied to the formation by reacting an oxidant with hydrocarbons adjacent to wellbores to generate heat. Generated heat may be transferred to the portion substantially by conduction to pyrolyze at least a portion of hydrocarbon material within the portion.

Claims

1. A method of treating an oil shale 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 reaction zone within the portion, wherein the reaction zone supports an oxidation reaction between hydrocarbons and the oxidant;

reacting a portion of the oxidant with hydrocarbons to generate heat;

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; and

controlling the heat such that an average heating rate of the pyrolysis zone is less than about 1°

C. per day in a pyrolysis temperature range from about 270°

C. to about 400°

C.

2. The method of claim 1, wherein heating the portion of the formation comprises raising a temperature of the portion above about 400°

C.

3. The method of claim 1, wherein the conduit comprises critical flow orifices, the method further comprising flowing the oxidant through the critical flow orifices to the reaction zone.

4. The method of claim 1, further comprising removing reaction products from the reaction zone through the wellbore.

5. The method of claim 1, further comprising removing excess oxidant from the reaction zone to inhibit transport of the oxidant to the pyrolysis zone.

6. The method of claim 1, further comprising transporting the oxidant from the conduit to the reaction zone substantially by diffusion.

7. The method of claim 1, further comprising heating the conduit with reaction products being removed through the wellbore.

8. The method of claim 1, wherein the oxidant comprises hydrogen peroxide.

9. The method of claim 1, wherein the oxidant comprises air.

10. The method of claim 1, wherein the oxidant comprises a fluid substantially free of nitrogen.

11. The method of claim 1, further comprising limiting an amount of oxidant to maintain a temperature of the reaction zone less than about 1200°

C.

12. The method of claim 1, wherein heating the portion of the formation comprises electrically heating the formation.

13. The method of claim 1, wherein heating the portion of the formation comprises heating the portion using exhaust gases from a surface burner.

14. The method of claim 1, wherein heating the portion of the formation comprises heating the portion with a flameless distributed combustor.

15. The method of claim 1, 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.

16. The method of claim 1, 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.).

17. The method of claim 1, 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.

18. The method of claim 1, 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.

19. The method of claim 1, wherein transferring generated heat comprises increasing a permeability of a majority of the pyrolysis zone to greater than about 100 millidarcy.

20. The method of claim 1, wherein transferring generated heat comprises substantially uniformly increasing a permeability of a majority of the pyrolysis zone.

21. The method of claim 1, wherein the heating is controlled to yield greater than about 60% by weight of condensable hydrocarbons, as measured by Fischer Assay.

22. The method of claim 1, wherein the wellbore is located along strike to reduce pressure differentials along a heated length of the wellbore.

23. The method of claim 1, wherein the wellbore is located along strike to increase uniformity of heating along a heated length of the wellbore.

24. The method of claim 1, wherein the wellbore is located along strike to increase control of heating along a heated length of the wellbore.

25. An in situ method for heating an oil shale 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;

controlling the heat such that an average heating rate of the pyrolysis zone is less than about 1°

C. per day in a pyrolysis temperature range from about 270°

C. to about 400°

C.

26. A method of treating an oil shale 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 reaction zone within the portion, wherein the reaction zone supports an oxidation reaction between hydrocarbons and the oxidant;

reacting a portion of the oxidant with hydrocarbons to generate heat;

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; and

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.

27. The method of claim 26, wherein heating the portion of the formation comprises raising a temperature of the portion above about 400°

C.

28. The method of claim 26, wherein the conduit comprises critical flow orifices, the method further comprising flowing the oxidant through the critical flow orifices to the reaction zone.

29. The method of claim 26, further comprising removing reaction products from the reaction zone through the wellbore.

30. The method of claim 26, further comprising transporting the oxidant from the conduit to the reaction zone substantially by diffusion.

31. The method of claim 26, further comprising heating the conduit with reaction products being removed through the wellbore.

32. The method of claim 26, further comprising limiting an amount of oxidant to maintain a temperature of the reaction zone less than about 1200°

C.

33. The method of claim 26, 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.).

34. A method of treating an oil shale 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 reaction zone within the portion, wherein the reaction zone supports an oxidation reaction between hydrocarbons and the oxidant;

reacting a portion of the oxidant with hydrocarbons to generate heat;

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; and

controlling the 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.

35. The method of claim 34, 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.

36. The method of claim 34, wherein transferring generated heat comprises increasing a permeability of a majority of the pyrolysis zone to greater than about 100 millidarcy.

37. The method of claim 34, wherein transferring generated heat comprises substantially uniformly increasing a permeability of a majority of the pyrolysis zone.

38. The method of claim 34, wherein heating the portion of the formation comprises raising a temperature of the portion above about 400°

C.

39. The method of claim 34, wherein the conduit comprises critical flow orifices, the method further comprising flowing the oxidant through the critical flow orifices to the reaction zone.

40. The method of claim 34, further comprising removing reaction products from the reaction zone through the wellbore.

41. The method of claim 34, further comprising transporting the oxidant from the conduit to the reaction zone substantially by diffusion.

42. A method of treating an oil shale 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 reaction zone within the portion, wherein the reaction zone supports an oxidation reaction between hydrocarbons and the oxidant;

reacting a portion of the oxidant with hydrocarbons to generate heat;

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; and

removing excess oxidant from the reaction zone to inhibit transport of the oxidant to the pyrolysis zone.

43. The method of claim 42, further comprising heating the conduit with reaction products being removed through the wellbore.

44. The method of claim 42, further comprising limiting an amount of oxidant to maintain a temperature of the reaction zone less than about 1200°

C.

45. The method of claim 42, 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.).

46. The method of claim 42, wherein transferring generated heat comprises increasing a permeability of the pyrolysis zone to greater than about 100 millidarcy.

47. The method of claim 42, wherein transferring generated heat comprises substantially uniformly increasing a permeability of the majority of the pyrolysis zone.

48. The method of claim 42, wherein heating the portion of the formation comprises electrically heating the formation.

49. The method of claim 42, 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.