Water treatment method for heavy oil production using calcium sulfate seed slurry evaporation
원문보기
IPC분류정보
국가/구분
United States(US) Patent
등록
국제특허분류(IPC7판)
E21B-043/24
E21B-043/16
E21B-043/40
E21B-043/34
B01D-001/28
B01D-001/00
B01D-003/42
C02F-001/04
C02F-009/00
출원번호
US-0149072
(2005-06-08)
등록번호
US-7438129
(2008-10-21)
발명자
/ 주소
Heins,William F.
출원인 / 주소
GE Ionics, Inc.
대리인 / 주소
Goodloe, Jr.,R. Reams
인용정보
피인용 횟수 :
55인용 특허 :
61
초록▼
A process for treating produced water to generate high pressure steam. Produced water from heavy oil recovery operations is treated by first removing oil and grease. Feedwater is then acidified and steam stripped to remove alkalinity and dissolved non-condensable gases. Pretreated produced water is
A process for treating produced water to generate high pressure steam. Produced water from heavy oil recovery operations is treated by first removing oil and grease. Feedwater is then acidified and steam stripped to remove alkalinity and dissolved non-condensable gases. Pretreated produced water is then fed to an evaporator. Up to 95% or more of the pretreated produced water stream is evaporated to produce (1) a distillate having a trace amount of residual solutes therein, and (2) evaporator blowdown containing substantially all solutes from the produced water feed. The distillate may be directly used, or polished to remove the trace residual solutes before being fed to a steam generator. Steam generation in a packaged boiler, such as a water tube boiler having a steam drum and a mud drum with water cooled combustion chamber walls, produces 100% quality high pressure steam for down-hole use.
대표청구항▼
The invention claimed is: 1. A process for producing steam for downhole injection in the recovery of heavy oil, said process comprising: (a) providing an oil/water mixture gathered from an oil/water collection well; (b) separating oil from said oil/water mixture to provide an oil product and a prod
The invention claimed is: 1. A process for producing steam for downhole injection in the recovery of heavy oil, said process comprising: (a) providing an oil/water mixture gathered from an oil/water collection well; (b) separating oil from said oil/water mixture to provide an oil product and a produced water product containing oil therein; (c) de-oiling said oil containing produced water product to at least partially provide an evaporator feedwater stream, said evaporator feedwater stream comprising water, dissolved gases, and dissolved solutes, said dissolved solutes comprising calcium, sulfate, and silica; (d) providing an evaporator having a plurality of heat transfer elements, a liquid containing sump reservoir, and a recirculating pump to recycle a concentrated brine form said sump reservoir to said plurality of heat transfer elements; (e) acidifying said feedwater to convert alkalinity to carbon dioxide, and steam stripping said carbon dioxide and said dissolved gases from said evaporator feedwater stream; (f) injecting said evaporator feedwater stream into said evaporator and evaporating a portion of said feedwater stream to produce said concentrated brine; (g) recirculating said concentrated brine in said evaporator, said concentrated brine comprising a slurry comprising water, dissolved solutes, calcium sulfate, and silica crystals; (h) distributing said concentrated brine on a first surface of at least one of said plurality of heat transfer elements to generate a steam vapor; (i) compressing said steam vapor to produce a compressed steam vapor; (j) directing said compressed steam vapor to a second surface of at least one of said plurality of heat transfer elements to condense said compressed steam vapor and to form a distillate; (k) collecting said distillate; (l) discharging at least some of said concentrated brine as an evaporator blowdown stream; (m) introducing said distillate stream into a steam generator, to produce (i) high pressure steam, and (ii) a boiler blowdown stream, said boiler blowdown stream comprising water and residual dissolved solids; (n) injecting said high pressure steam in an injection wells to fluidize oil present in a selected geological formation, to produce an oil and water mixture; (o) gathering said oil/water mixture. 2. The process as set forth in claim 1, wherein said distillate comprises residual solutes, further comprising the step of removing residual solutes from said distillate stream to produce a substantially solute free distillate. 3. The process as set forth in claim 2, wherein said residual solutes in said distillate comprise non-volatile total organic carbon constituents. 4. The process as set forth in claim 2, wherein said residual solutes in said distillate comprise hardness. 5. The process as set forth in claim 2, further comprising cooling said distillate prior to removal of said residual solutes. 6. The process as set forth in claim 5, wherein said method further comprises heating said substantially solute free distillate before introducing said stream into said steam generator. 7. The process as set forth in claim 2, wherein said residual solutes in said distillate are removed via ion exchange treatment. 8. The process as set forth in claim 7, further comprising regenrating said ion exchange resin to generate an ion exchange regenerant stream, and still further comprising returning said ion exchange regenerant stream to said evaporator feedwater stream pior to injecting said evaporator feedwater stream into said evaporator. 9. The process as set forth in claim 2, wherein said residual solutes are removed via membrane separation, wherein a solute contaning membrane rejected stream is produced. 10. The process as set forth in claim 9, wherin said membrane separation method comprises reverse osmosis. 11. The process as set forth in claim 2, wherein said membrane separation method comprises electrodeionization. 12. The process as set forth in claim 11, wherein after adding said boiler blowdown stream, said evaporator feedwater stream is heated. 13. The process as set forth in claim 1, further comprising removing said residual solutes from said distillate in an electrodeionization treatment unit to produce (a) a substantially solute free boiler feedwater and (2) a solute containg electrodeionization reject stream. 14. The process as set forth in claim 13, further comprising, before injecting said evaporator feedwater stream into said evaporator, directing said electrodeionization reject stream to said evaporator feedwater stream. 15. The process as set forth in claim 1, wherein said process further comprises adding said boiler blowdown stream to said evaporator feedwater stream. 16. The process as set forth in claim 1, wherein said boiler blowdown is directly injected into said sump reservoir. 17. The process as set forth in claim 1, wherein said boiler blowdown stream is injected into said concentrated brine at a location upstream of said recirculation pump. 18. The process as set forth in claim 1, wherein said evaporator feedwater further comprises dissolved gases,and wherein said process further comprises heating said evaporator feedwater to remove at least some of said dissolved gases from said evaporator feedwater, prior to injection of said evaporator feedwater stream into said evaporator. 19. The process as set forth in claim 1, wherein the pH of the concentrated brine is maintained at a pH of at least 7.5 by adding a selected base to said sump reservoir. 20. The process as set forth in claim 19, wherein said selected base comprises sodium hydroxide. 21. The process as set forth in claim 1, wherein said evaporator further comprises a feed tank, and wherein the pH of the concentrated brine is raised to a pH of at least 8.5 by adding a selected base to said sump reservoir. 22. The process as set forth in claim 1, wherein the pH of the concentratde brine is raised to a pH of at least 7.5 by injection of a selected base into said recirculating brine. 23. The process as set forth in claim 1, wherein the pH of the concentrated brine is raised to a ph of at least 8.5 by injection of a selected base into said concentrated brine. 24. The process as set forth in claim 23, wherein said selected base is injected into said concentrated brine prior to said recirculating pump. 25. The process as set forth in claim 1, wherein said evaporator comprises a falling-film type evaporator. 26. The process as set forth in claim 25, wherein said heat transfer elements comprise tubular heat transfer elements having an interior surface and an exterior surface. 27. The process as set forth in claim 25, wherein said evaporator comprises a mechanical vapor recompression evaporator. 28. The process as set forth in claim 1, wherein said evaporator comprises a forcedcirculation type evaporator. 29. The process as set forth in claim 28, wherein said heat transfer elements comprise tubular elements having an interior surface and an exterior surface. 30. The process as set forth in claim 29, wherein said evaporator feedwater stream is concentrated at the interior surface of said tubular heat transfer elements. 31. The process as set forth in claim 28, wherein said evaporator comprises a mechanical vapor recompression evaporator. 32. The process as set forth in claim 1, further comprising treating said evaporator blowdown stream in a crystallizer. 33. The process as set forth in claim 1, further comprising treating said evaporator blowdown stream in a dryer. 34. The process as se torth in claim 1, further comprising removing oil from said evaporator feedwater stream to a selected oil concentration before injecting said evaporator feedwater stream into said evaporator. 35. The process as set forth in claim 34, wherein the selected concentration of oil in said evaporator feedwater stream comprises less than about twenty parts per million. 36. The process as set forth in claim 1, wherein said steam generator comprises a packaged boiler. 37. The process as set forth in claim 36, wherein said packaged boiler cimprises a water tube boiler. 38. The process as set forth in claim 1, wherein said steam generator comprises a once-through steam generator, said once-through steam generator producing said high pressure steam stream and said boiler blowdown stream. 39. The process as set forth in claim 38, further comprising separating said high pressure steam stream and said boiler blowdown stream to produce a steam stream having substantially 100% steam quality. 40. The process as set forth in claim 39, wherein said substantially 100% steam quality steam is injected into said injection wells. 41. The process as set forth in claim 39, wherein said boiler blowdown stream is flashed at least once to produce a still further concentrated boiler blowdown stream comprising water and residual dissolved solutes. 42. The process as set forth in claim 41, further comprising adding said residual liquid stream containing dissolved solutes to said evaporator feedwater stream. 43. A process for producing steam for downhole injection in the recovery of heavy oil, said process comprising: (a) providing an oil/water mixture gathered from an oil/water collection well; (b) separating oil from said oil/water mixture to provide an oil product and a produced water product containing oil therein; (c) pretreating said produced water product, said pretreating comprising de-oiling said oil containing produced water product to at least partially provide a feedwater stream, said feedwater stream comprising water, dissolved gases, said dissolved gases comprising alkalinity, and dissolved solutes, said dissolved solutes comprising silica; (d) providing an evaporator having a plurality of heat transfer elements, a liquid containing sump reservoir, and a recirculating pump to recycle a concentrated brine from said sump reservoir to said plurality of heat transfer elements; (e) acidifying said feedwater stream to convert said alkalinity to carbon dioxide and then steam stripping said carbon dioxide from said feedwater stream; (f) recirculating said concentrated brine; (g) adding said feedwater stream to said concentrated brine before directing said concentrated brine to which said feedwater stream has been added to said plurality of heat transfer elements; (h) distributing said concentrated brine on a first surface of at least one of said plurality of heat transfer elements to generate a steam vapor; (i) compressing said steam vapor to produce a compressed steam vapor; (j) directing said compressed steam vapor to a second surface of at least one of said plurality of heat transfer elements to condense said compressed steam vapor and to form a distillate; (k) collecting said distillate; (l) discharging at least some of said concentrated brine as an evaporator blowdown stream; (m) introducing said distillate into a steam generator, to produce (i) high pressure steam, (ii) a boiler blowdown stream, said boiler blowdown stream comprising water and residual dissolved solids; (n) injecting said high pressure steam in injection wells to fluidize oil present in a selected geological formation, to produce an oil and water mixture; (o) gathering said oil/water mixture. 44. The process as set forth in claim 43, wherein said distillate comprises residual solutes, further comprising removing residual solutes from said distillate to produce a substantially solute free distillate. 45. The processas set forth in claim 44, further comprising cooling said distillate prior to removal of said residual solutes. 46. The process as set forth in claim 45, wherein said method further comprises heating said substantially solute free distillate before introducing said substantially solute free distillate into said steam generator. 47. The process as set forth in claim 43, wherein said process further comprises adding said boiler blowdown stream to said feedwater stream. 48. The process as set forth in claim 47, wherein, after adding said boiler blowdown stream, said evaporator feedwater stream is heated. 49. The process as set forth in claim 43, wherein said boiler blowdown stream is directly injected into said sump reservoir. 50. The process as set forth in claim 43, wherein said boiler blowdown stream is injected into said concentrated brine at a location upstream of said recirculation pump. 51. The process as set forth in claim 43, wherein the pH of the concentrated brine is maintained at a pH of at least 8.5. 52. The process as set forth in claim 51, wherein the pH of she concentrated brine is maintained at a pH of at least 8.5 by injection of hydroxide ions to said concentrated brine. 53. The process as set forth in claim 52, wherein said hydroxide ions are injected into said concentrated brine before said recirculating pump. 54. The process as set forth in claim 43, wherein the pH of thee concentrated brine is maintained as a pH of ac least 8.5 by injection of said hydroxide ions to said sump reservoir. 55. The process as set forth in claim 43, wherein said evaporator comprises a falling-film type evaporator. 56. The process as set forth in claim 43, wherein said evaporator comprises a forced-circulation type evaporator. 57. The process as set forth in claim 43, further comprising treating said evaporator blowdown stream in a crystallizer. 58. The process as set forch in claim 43, further comprising treating said evaporator blowdown stream in a dryer. 59. The process as set forth in claim 43, wherein said steam generator comprises a packaged boiler. 60. The process as set forth in claim 43, wherein said steam generator comprises a once-through steam generator, said once-through steam generator producing said high pressure steam stream arid said boiler blowdown stream. 61. The process as set forth in claim 60, further comprising separating said high pressure steam stream and said boiler blowdown stream to produce a high pressure steam stream having substantially 100% steam quality.
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