Power systems utilizing the heat of produced formation fluid

• US 7,866,385 B2
• Filed: 04/20/2007
• Issued: 01/11/2011
• Est. Priority Date: 04/21/2006
• Status: Expired due to Fees

• Current Assignee: Shell Oil Company (Shell Plc)
• Original Assignee: Shell Oil Company (Shell Plc)
• Inventors: Lambirth, Gene Richard
• Primary Examiner(s): SUCHFIELD, GEORGE A
• Application Number:
  US11/788,822
• Publication Number:
  US 20080174115A1
• Time in Patent Office: 1,362 Days
• Field of Search: 166/57, 166/59, 166/60, 166/75.12, 166/256, 166/267, 166/302, 299/4, 299/5
• US Class Current: 166/256
• CPC Class Codes: B32B 1/08 Tubular products
• CPC Class Codes: B32B 15/013 one layer being formed of an iron alloy or steel, another layer being formed of a metal other than iron or aluminium
• CPC Class Codes: B32B 15/015 the said other metal being copper or nickel or an alloy thereof
• CPC Class Codes: B32B 2307/202 Conductive
• CPC Class Codes: B32B 2307/208 Magnetic, paramagnetic
• CPC Class Codes: B32B 9/002 comprising natural stone or artificial stone
• CPC Class Codes: B32B 9/045 of synthetic resin
• CPC Class Codes: C21D 2211/001 Austenite
• CPC Class Codes: C21D 2211/004 Dispersions; Precipitations
• CPC Class Codes: C21D 2211/005 Ferrite
• CPC Class Codes: C21D 6/002 containing Cr C21D6/004 takes precedence
• CPC Class Codes: C21D 6/007 containing Co
• CPC Class Codes: C22C 38/02 containing silicon
• CPC Class Codes: C22C 38/04 containing manganese
• CPC Class Codes: C22C 38/10 containing cobalt
• CPC Class Codes: C22C 38/12 containing tungsten, tantalum, molybdenum, vanadium, or niobium
• CPC Class Codes: C22C 38/14 containing titanium or zirconium
• CPC Class Codes: C22C 38/24 with vanadium
• CPC Class Codes: C22C 38/28 with titanium or zirconium
• CPC Class Codes: C22C 38/30 with cobalt
• CPC Class Codes: E21B 36/04 : using electrical heaters
• CPC Class Codes: E21B 43/2401 : by means of electricity
• CPC Class Codes: G05F 1/10 : Regulating voltage or current G05F1/02 takes precedence; for electric railways B60M3/02
• CPC Class Codes: Y10S 166/902 : for inhibiting corrosion or coating

Abstract

Systems, methods, and heaters for treating a subsurface formation are described herein. At least one method includes treating a hydrocarbon containing formation. The method may include providing heat to the formation; producing heated fluid from the formation; and generating electricity from at least a portion of the heated fluid using a Kalina cycle.

Claims

1. A method for treating a hydrocarbon containing formation, comprising:

providing heat to the formation;

producing heated fluid from the formation, wherein a temperature of the produced heated fluid is above 100°

C.; and

generating electricity from at least a portion of the heated fluid using a Kalina cycle, wherein the Kalina cycle comprises heating at least a first portion of a working fluid of the Kalina cycle using heat from the heated formation.

2. The method of claim 1, wherein providing heat to the formation comprises heating the formation using a fireflood.

3. The method of claim 1, wherein providing heat to the formation comprises transferring heat to the formation from electrical resistance heaters.

4. The method of claim 1, wherein providing heat to the formation comprises transferring heat to the formation from subsurface gas burners.

5. The method of claim 1, wherein providing heat to the formation comprises transferring heat to the formation from fluid flowing through conduits positioned in the formation.

6. The method of claim 1, wherein the Kalina cycle comprises passing a rich working fluid stream from a separator to a turbine to generate electricity.

7. The method of claim 1, wherein the Kalina cycle comprises passing the heated fluid through a first heat exchanger to transfer heat to the first portion of the working fluid of the Kalina cycle;

passing a second portion of the working fluid to a second heat exchanger to transfer heat from the second portion of the working fluid to a lean working fluid stream exiting a separator of the Kalina cycle; and

passing the heated portion of the working fluid stream and the second portion of the working fluid stream to the separator.

8. The method of claim 1, wherein the first portion of the working fluid of the Kalina cycle is heated by passing the heated fluid through a heat exchanger to transfer heat to the first portion of the working fluid;

and then passing the heated working fluid to a separator.

9. The method of claim 1, wherein at least a portion of the heated fluid is produced using an in situ heat treatment process.

10. The method of claim 1, wherein the heated fluid comprises fluid produced during a solution mining process.

11. The method of claim 1, further comprising using at least a portion of the electricity to power electrical resistance heaters in the formation, or in another formation.

12. The method of claim 1, further comprising using a least a portion of the electricity to power a refrigeration system for a barrier around a treatment area.

13. The method of claim 1, further comprising using a least a portion of the electricity to power one or more compressors.

14. The method of claim 1, wherein the working fluid of the Kalina cycle comprises aqueous ammonia.

15. The method of claim 1, wherein the working fluid of the Kalina cycle comprises alkanes.

16. The method of claim 1, wherein the working fluid of the Kalina cycle comprises hydrofluorocarbons.

17. The method of claim 1, wherein the working fluid stream comprises alkanes and hydrofluorocarbons.

18. The method of claim 1, wherein at least a portion of heat transfer to the working fluid stream of the Kalina cycle takes place in the heated formation.

19. The method of claim 1, further comprising passing the heated fluid to a separator or other treatment unit after passing the heated fluid through a heat exchanger used in the Kalina cycle.

20. The method of claim 1, wherein producing the heated fluid comprises injecting a fluid into the heated formation, wherein the heated formation has been subjected an situ heat treatment process, and transferring heat from the heated formation to the fluid.

21. The method of claim 1, wherein the first portion of the working fluid of Kalina cycle is heated by passing the heated fluid through a heat exchanger to transfer heat to the first portion of the working fluid, and evaporating at least a portion of the first portion of the working fluid in the heat exchanger.

22. A method for treating a hydrocarbon containing formation, comprising:

providing heat to the formation;

producing heated fluid from the formation; and

generating electricity from at least a portion of the heated fluid using a Kalina cycle, wherein the Kalina cycle comprises passing a rich working fluid stream from a separator to a turbine to generate electricity.

23. The method of claim 22, wherein providing heat to the formation comprises transferring heat to the formation from electrical resistance heaters.

24. The method of claim 22, wherein the Kalina cycle comprises passing the heated fluid through a heat exchanger to transfer heat to a first portion of a working fluid;

and then passing the heated working fluid to the separator to form the rich working fluid stream.

25. The method of claim 22, wherein at least a portion of the heated fluid is produced using an in situ heat treatment process.

26. The method of claim 22, wherein the heated fluid comprises fluid produced during a solution mining process.

27. The method of claim 22, further comprising using at least a portion of the electricity to power electrical resistance heaters in the formation, or in another formation.

28. The method of claim 22, further comprising using a least a portion of the electricity to power a refrigeration system for a barrier around a treatment area.

29. The method of claim 22, further comprising using a least a portion of the electricity to power one or more compressors.

30. The method of claim 22, wherein the rich working fluid stream comprises aqueous ammonia.

31. The method of claim 22, wherein the rich working fluid stream comprises alkanes.

32. The method of claim 22, wherein the rich working fluid stream comprises hydrofluorocarbons.

33. The method of claim 22, wherein the rich working fluid comprises alkanes and hydrofluorocarbons.

34. The method of claim 22, further comprising passing the heated fluid to another separator or other treatment unit after passing the heated fluid through a heat exchanger used in the Kalina cycle.

35. The method of claim 22, wherein producing the heated fluid comprises injecting a fluid into the heated formation, wherein the heated formation has been subjected to in situ heat treatment process, and transferring heat from the heated formation to the fluid.

36. The method of claim 22, wherein the Kalina cycle comprises passing the heated fluid through a heat exchanger to transfer heat to a working fluid, and evaporating at least a portion of the working fluid in the heat exchanger to form the rich working fluid stream.

37. A method for treating a hydrocarbon containing formation, comprising:

providing heat to the formation;

producing heated fluid from the formation;

generating electricity from at least a portion of the heated fluid using a Kalina cycle, wherein the Kalina cycle comprises passing the heated fluid through a heat exchanger to transfer heat to a working fluid; and

passing the heated working fluid to a separator.

38. The method of claim 37, wherein providing heat to the formation comprises transferring heat to the formation from electrical resistance heaters.

39. The method of claim 37, wherein at least a portion of the heated fluid is produced using an in situ heat treatment process.

40. The method of claim 37, wherein the heated fluid comprises fluid produced during a solution mining process.

41. The method of claim 37, further comprising using at least a portion of the electricity to power electrical resistance heaters in the formation, or in another formation.

42. The method of claim 37, further comprising using a least a portion of the electricity to power a refrigeration system for a barrier around a treatment area.

43. The method of claim 37, further comprising using a least a portion of the electricity to power one or more compressors.

44. The method of claim 37, wherein the working fluid stream comprises aqueous ammonia.

45. The method of claim 37, wherein the working fluid stream comprises alkanes.

46. The method of claim 37, wherein the working fluid stream comprises hydrofluorocarbons.

47. The method of claim 37, wherein the working fluid stream comprises alkanes and hydrofluorocarbons.

48. The method of claim 37, further comprising passing the heated fluid to another separator or other treatment unit after passing the heated fluid through a heat exchanger used in the Kalina cycle.

49. The method of claim 37, wherein producing the heated fluid comprises injecting a fluid into the heated formation, wherein the heated formation has been subjected to an in situ heat treatment process, and transferring heat from the heated formation to the fluid.

50. The method of claim 37, wherein the Kalina cycle comprises passing a rich working fluid stream from the separator to a turbine to generate electricity.

51. The method of claim 37, wherein the Kalina cycle comprises passing a second portion of the working fluid to a second heat exchanger to transfer heat from the second portion of the working fluid to a lean working fluid stream exiting the separator of the Kalina cycle;

and passing the heated portion of the working fluid stream and the second portion of the working fluid stream to the separator.