초록 ▼

Systems and methods are provided for treating a wellbore using a loop system to heat oil in a subterranean formation contacted by the wellbore. The loop system comprises a loop that conveys a fluid (e.g., steam) down the wellbore via a injection conduit and returns fluid (e.g., condensate) from the

Systems and methods are provided for treating a wellbore using a loop system to heat oil in a subterranean formation contacted by the wellbore. The loop system comprises a loop that conveys a fluid (e.g., steam) down the wellbore via a injection conduit and returns fluid (e.g., condensate) from the wellbore via a return conduit. A portion of the fluid in the loop system may be injected into the subterranean formation using one or more valves disposed in the loop system. Alternatively, only heat and not fluid may be transferred from the loop system into the subterranean formation. The fluid returned from the wellbore may be re-heated and re-conveyed by the loop system into the wellbore. Heating the oil residing in the subterranean formation reduces the viscosity of the oil so that it may be recovered more easily.

대표청구항 ▼

What is claimed is: 1. A method of servicing a wellbore, comprising: using a loop system to heat oil in a subterranean formation contacted by the wellbore, wherein the loop system conveys steam down the wellbore, wherein the loop system comprises a closed loop that circulates the steam through a co

What is claimed is: 1. A method of servicing a wellbore, comprising: using a loop system to heat oil in a subterranean formation contacted by the wellbore, wherein the loop system conveys steam down the wellbore, wherein the loop system comprises a closed loop that circulates the steam through a conduit disposed in the wellbore such that heat is transferred from the steam to the subterranean formation, and wherein the steam is circulated through the loop system until the steam is substantially absent of condensate, and then the loop system is switched from the closed loop to an open loop in which at least a portion of the steam is injected into the subterranean formation. 2. The method of claim 1, wherein the loop system returns fluid from the wellbore. 3. The method of claim 2, wherein the fluid comprises condensate, steam, or combinations thereof. 4. The method of claim 1, further comprising injecting at least a portion of the steam from the loop system into the subterranean formation. 5. The method of claim 4, wherein another material is injected into the subterranean formation before, after, or concurrent with injecting the steam. 6. The method of claim 5, wherein the another material is recovered from the subterranean formation prior to being injected therein. 7. The method of claim 5, wherein the another material comprises an oil-soluble fluid. 8. The method of claim 1, wherein the steam is injected from the loop system into the subterranean formation until a predetermined temperature is achieved at a location in the wellbore. 9. The method of claim 1, wherein the loop system comprises one or more valves for controlling the injection of the steam into the subterranean formation. 10. The method of claim 9, wherein the loop system can automatically or manually be switched from a closed loop system in which all of the valves are closed to an injection system in which the valves are regulated to control the flow of the steam into the subterranean formation. 11. The method of claim 9, wherein the valve comprises a thermally-controlled valve, a pressure-activated valve, a spring loaded-control valve, a surface-controlled valve, a hydraulically-controlled valve, a fiber optic-controlled valve, a sub-surface controlled valve, a manual valve, or combinations thereof. 12. The method of claim 8, wherein the loop system comprises one or more thermally-controlled valves for regulating the flow of the steam into the subterranean formation. 13. The method of claim 9, wherein the one or more valves correspond to one or more heating zones in the subterranean formation such that the steam may be selectively injected into the heating zones. 14. The method of claim 13, wherein the one or more heating zones are isolated from each other by one or more isolation packers. 15. The method of claim 12, wherein the one or more thermally-controlled valves correspond to one or more heating zones in the subterranean formation such that the steam may be selectively injected into the heating zones. 16. The method of claim 15, wherein each thermally-controlled valve controls the injection of the steam into the subterranean formation in response to the temperature corresponding to the heating zone. 17. The method of claim 16, wherein the control results in the injection of about saturated steam. 18. The method of claim 1, further comprising recovering oil from the subterranean formation. 19. The method of claim 16, further comprising recovering oil from the subterranean formation. 20. The method of claim 18, wherein the recovery of oil and the condensate are simultaneous. 21. The method of claim 18, wherein the recovery of oil and the condensate are sequential. 22. The method of claim 1, further comprising reheating the condensate to form a portion of the steam. 23. The method of claim 18, wherein the oil and the condensate are recovered from a common wellbore. 24. The method of claim 18, wherein the oil and the condensate are recovered from different wellbores. 25. The method of claim 18, wherein the oil and condensate are recovered from a multilateral wellbore. 26. The method of claim 18, wherein the oil and the condensate are recovered from a SAGD wellbore. 27. The method of claim 19, wherein the oil and the condensate are recovered from a SAGD wellbore. 28. The method of claim 1, wherein the subterranean formation comprises oil and tar sands. 29. The method of claim 1, further comprising passing a chemical into the loop system for reducing contaminants therein. 30. The method of claim 1, wherein the steam loop comprises a steam boiler coupled to a steam injection conduit coupled to a condensate recovery conduit. 31. The method of claim 30, wherein the steam boiler is fired from hydrocarbons recovered from the wellbore. 32. The method of claim 30, wherein the steam loop further comprises one or more control valves in the steam injection conduit. 33. The method of claim 32, wherein the control valve comprises a thermally-controlled valve, a pressure-activated valve, a spring loaded-control valve, a surface-controlled valve, a hydraulically-controlled valve, a fiber optic-controlled valve, a sub-surface controlled valve, a manual valve, or combinations thereof. 34. The method of claim 30, further comprising a steam trap disposed between the steam injection conduit and the condensate recovery conduit. 35. The method of claim 30, further comprising a condensate pump disposed within the condensate recovery conduit. 36. The method of claim 35, further comprising a flash tank disposed within the condensate recovery conduit. 37. The method of claim 30, wherein the wellbore is a multilateral wellbore. 38. The method of claim 30, wherein the wellbore is an SAGD wellbore. 39. The method of claim 38, wherein the steam boiler is fired from hydrocarbons recovered from the wellbore. 40. The method of claim 30, further comprising means for recovering oil from the wellbore. 41. The method of claim 40, wherein the means for recovering oil comprises an oil recovery conduit. 42. The method of claim 41, wherein the steam injection conduit, the condensate recovery conduit, or both are disposed within the oil recovery conduit. 43. The method of claim 42, wherein the wellbore is an SAGD wellbore. 44. The method of claim 42, wherein the steam injection conduit and the condensate recovery conduit are arranged in a concentric configuration. 45. The method of claim 30, wherein the wellbore contacts a subterranean formation comprising oil and tar sands. 46. The method of claim 32, wherein the steam loop is capable of being automatically or manually switched from a closed loop system in which all of the control valves are closed to an injection system in which the control valves are regulated to control the flow of the steam into the subterranean formation. 47. The method of claim 32, wherein the one or more valves correspond to one or more heating zones in the subterranean formation such that the steam may be selectively injected into the heating zones. 48. The method of claim 47, wherein the one or more heating zones are isolated from each other by one or more isolation packers. 49. The method of claim 32, wherein one or more control valves are disposed in the oil recovery conduit. 50. The method of claim 1 further comprising: injecting fluid into the subterranean formation contacted by the wellbore for heating the subterranean formation, wherein the wellbore comprises a plurality of heating zones. 51. The method of claim 50, further comprising using a plurality of control valves disposed in the wellbore to regulate the flow of the fluid into the wellbore, wherein the valves correspond to the heating zones such that the fluid may be selectively injected into the heating zones. 52. The method of claim 51, wherein one or more of the control valves are thermally controlled. 53. The method of claim 50, wherein the heating zones are isolated from each other by isolation packers. 54. The method of claim 50, wherein the fluid comprises steam, heated water, or combinations thereof. 55. The method of claim 1 wherein the steam loop comprises a delivery conduit for injecting fluid into the subterranean formation penetrated by the wellbore, wherein the delivery conduit comprises a plurality of heating zones that correspond to heating zones in the wellbore. 56. The method of claim 55, wherein the heating zones are isolated by isolation packers. 57. The method of claim 55, further comprising control valves in the delivery conduit that correspond to the heating zones for selectively injecting the fluid into the respective heating zones. 58. The method of claim 1 further comprising: using the loop system disposed in the wellbore to controllably release fluid into the subterranean formation contacted by the wellbore for heating the subterranean formation. 59. The method of claim 58, wherein the fluid comprises steam, heated water, or combinations thereof. 60. The method of claim 58, further comprising using the loop system to return the same or different fluid from the wellbore. 61. The method of claim 59, wherein the loop system comprises one or more control valves for controlling the injection of the fluid into the subterranean formation. 62. The method of claim 61, wherein one or more of the control valves are thermally controlled. 63. The method of claim 61, wherein the loop system can be automatically or manually switched from a closed loop system in which all of the control valves are closed to an injection system in which one or more of the control valves are regulated open to control the flow of the fluid into the subterranean formation. 64. The method of claim 1 wherein the loop system is capable of controllably releasing fluid into the subterranean formation contacted by the wellbore for heating the subterranean formation. 65. The method of claim 64, wherein the fluid comprises steam, heated water, or combinations thereof. 66. The method of claim 64, wherein the loop system comprises one or more control valves for controlling the release of the fluid into the subterranean formation. 67. The method of claim 66, wherein one or more of the control valves are thermally controlled. 68. The method of claim 66, wherein the loop system is capable of being automatically or manually switched from a closed loop system in which all of the control valves are closed to an injection system in which one or more of the control valves are regulated open to control the flow of the fluid into the subterranean formation. 69. The method of claim 1 wherein the heat reduces the viscosity of the oil, thereby allowing the oil to flow by natural forces into a second wellbore. 70. The method of claim 69 wherein the natural force is gravity. 71. The method of claim 30 wherein the heat reduces the viscosity of hydrocarbons, thereby allowing the hydrocarbons to flow by natural forces into a second wellbore. 72. The method of claim 71 wherein the natural force is gravity.