In situ thermal processing of an oil shale formation

• US 8,608,249 B2
• Filed: 04/26/2010
• Issued: 12/17/2013
• 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: Vinegar, Harold J., de Rouffignac, Eric Pierre, Maher, Kevin Albert, Schoeling, Lanny Gene, Wellington, Scott Lee
• Primary Examiner(s): KRECK, JOHN J
• Application Number:
  US12/767,572
• Publication Number:
  US 20100270015A1
• Time in Patent Office: 1,331 Days
• Field of Search: 299 3- 5, 166/302, 166/303
• US Class Current: 299/3
• 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

A method of treating an oil shale formation in situ includes allowing a temperature of a portion of the formation to decrease. The portion has previously undergone an in situ heat treatment process. A first fluid is injected into a part of the portion and a second fluid is produced from the formation.

Claims

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

providing heat from a plurality of heaters located in a plurality of wellbores to a least a portion of the formation during an in situ heat treatment process,

allowing a temperature of the portion of the formation to decrease following the in situ heat treatment process;

injecting a heated first fluid into a part of the portion having a decreased temperature;

providing heat from the first fluid to the portion having the decreased temperature; and

producing a second fluid from the formation.

2. The method of claim 1, wherein the in situ heat treatment process comprises:

pyrolyzing at least some hydrocarbons in the portion; and

producing a mixture from the formation.

3. The method of claim 1, wherein the first fluid comprises water.

4. The method of claim 1, wherein the second fluid comprises a metal.

5. The method of claim 1, wherein the second fluid comprises a mineral.

6. The method of claim 1, wherein the second fluid comprises aluminum.

7. The method of claim 1, wherein the second fluid comprises a metal, and further comprising producing the metal from the second fluid.

8. The method of claim 1, further comprising producing a non-hydrocarbon material from the second fluid.

9. The method of claim 1, wherein the portion of the hydrocarbon formation comprises nahcolite.

10. The method of claim 1, wherein greater than about 10% by weight of the portion comprises nahcolite.

11. The method of claim 1, wherein the portion comprises dawsonite.

12. The method of claim 1, wherein greater than about 2% by weight of the portion comprises dawsonite.

13. The method of claim 1, further comprising providing heat to the formation by transferring waste heat from another portion of the formation to the portion of the formation having a decreased temperature.

14. The method of claim 1, wherein the first fluid comprises steam.

15. The method of claim 1, wherein the first fluid is at a temperature above about 90°

C.

16. The method of claim 1, wherein the reduced temperature of the portion is less than about 90°

C.

17. The method of claim 1, further comprising removing mass from the portion of the formation in the second fluid such that a permeability of the portion of the formation increases.

18. The method of claim 1, wherein the formation comprises phosphates.

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

providing heat directly from a plurality of heaters located in a plurality of wellbores to a least a portion of the formation during an in situ heat treatment process,

controlling the heat providing from the plurality of heaters to maintain an average temperature of the portion below a dissociation temperature of carbonate minerals in the portion;

allowing a temperature of the portion of the formation to decrease following the in situ heat treatment process;

injecting a first fluid into a part of the portion having a decreased temperature; and

producing a second fluid from the formation.