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Kafe 바로가기국가/구분 | United States(US) Patent 등록 |
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국제특허분류(IPC7판) |
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출원번호 | US-0919702 (2009-03-25) |
등록번호 | US-8984857 (2015-03-24) |
국제출원번호 | PCT/US2009/038247 (2009-03-25) |
§371/§102 date | 20100826 (20100826) |
국제공개번호 | WO2009/120779 (2009-10-01) |
발명자 / 주소 |
|
출원인 / 주소 |
|
대리인 / 주소 |
|
인용정보 | 피인용 횟수 : 2 인용 특허 : 540 |
Methods and systems for low emission power generation in hydrocarbon recovery processes are provided. One system includes integrated pressure maintenance and miscible flood systems with low emission power generation. An alternative system provides for low emission power generation, carbon sequestrat
Methods and systems for low emission power generation in hydrocarbon recovery processes are provided. One system includes integrated pressure maintenance and miscible flood systems with low emission power generation. An alternative system provides for low emission power generation, carbon sequestration, enhanced oil recovery (EOR), or carbon dioxide sales using a hot gas expander and external combustor. Another alternative system provides for low emission power generation using a gas power turbine to compress air in the inlet compressor and generate power using hot carbon dioxide laden gas in the expander. Other efficiencies may be gained by incorporating heat cross-exchange, a desalination plant, co-generation, and other features.
1. An integrated system, comprising: an air separation unit configured to produce an oxygen stream and a nitrogen stream;a gaseous control fuel stream;a combustion unit configured to combust at least the gaseous control fuel stream and the oxygen stream to produce a gaseous combustion stream having
1. An integrated system, comprising: an air separation unit configured to produce an oxygen stream and a nitrogen stream;a gaseous control fuel stream;a combustion unit configured to combust at least the gaseous control fuel stream and the oxygen stream to produce a gaseous combustion stream having carbon dioxide and water;a power generation system configured to receive the gaseous combustion stream having carbon dioxide and water and produce at least a compressed gaseous carbon dioxide stream comprising from about 60 volume percent (vol %) carbon dioxide to about 95 vol % carbon dioxide;a first injector unit configured to inject at least a portion of the compressed gaseous carbon dioxide stream into an enhanced oil recovery reservoir;a second injector unit configured to inject at least a portion of the nitrogen stream into a pressure maintenance reservoir;a first hydrocarbon recovery reservoir configured to produce a first hydrocarbon mixture; anda first hydrocarbon separation unit configured to separate at least liquid hydrocarbons from the first hydrocarbon mixture and produce a first hydrocarbon stream and a secondary gas stream comprising carbon dioxide and hydrocarbons, wherein the combustion unit is further configured to utilize at least a portion of the secondary gas stream with the gaseous control fuel stream and the oxygen stream to produce the gaseous combustion stream having carbon dioxide and water. 2. The system of claim 1, wherein the power generation system comprises: an expander configured to receive the gaseous combustion stream and produce mechanical power and a gaseous exhaust stream;a heat recovery unit configured to receive and cool the gaseous exhaust stream, produce heat energy, and generate at least a volume of water and a cooled gaseous carbon dioxide stream, wherein the heat energy is optionally utilized to generate steam to generate steam power; anda carbon dioxide compressor configured to compress the cooled gaseous carbon dioxide stream to produce the compressed gaseous carbon dioxide stream. 3. The system of claim 1, further comprising: a second hydrocarbon recovery reservoir configured to produce a second hydrocarbon mixture; anda second hydrocarbon separation unit configured to separate at least liquid hydrocarbons from the second hydrocarbon mixture and produce a second hydrocarbon stream and an inert gas stream comprising nitrogen, wherein the second injector is further configured to inject the inert gas stream into the pressure maintenance reservoir. 4. The system of claim 3, wherein the enhanced oil recovery reservoir is selected from the group consisting of: the first hydrocarbon recovery reservoir, the second hydrocarbon recovery reservoir, another hydrocarbon recovery reservoir, and any combination thereof. 5. The system of claim 3, wherein the pressure maintenance reservoir is selected from the group consisting of: the first hydrocarbon recovery reservoir, the second hydrocarbon recovery reservoir, another hydrocarbon recovery reservoir, and any combination thereof. 6. The system of claim 2, further comprising a recycle loop configured to direct at least a portion of the compressed gaseous carbon dioxide stream to the combustion unit or the secondary gas stream. 7. The system of claim 1, further comprising a control algorithm configured to control the mixture and combustion of the gaseous control fuel stream, the secondary gas stream comprising carbon dioxide and hydrocarbons, and the oxygen stream to ensure consumption of substantially all of the oxygen in the oxygen stream. 8. The system of claim 7, wherein the combustion unit is selected from the group consisting of: an oxygen combustor, a pre-mix combustor, a piloted combustor, a partial oxidation (POX) combustor, a diffusion burner, an autothermal reformer, and an oxyClaus reaction furnace burner. 9. The system of claim 2, wherein the expander is selected from the group consisting of: an expander in a gas power turbine and a hot gas expander. 10. The system of claim 9, further comprising an inlet compressor configured to compress atmospheric air to form a compressed air stream, wherein the air separation unit is configured to utilize the compressed air stream to form the oxygen stream and the nitrogen stream. 11. The system of claim 10, wherein the expander is the expander in a gas power turbine and the inlet compressor is driven by the gas power turbine and the compressed gaseous carbon dioxide stream is utilized as a working fluid in the expander of the gas power turbine. 12. The system of claim 3, wherein the secondary gas stream comprising carbon dioxide and hydrocarbons comprises from about 60 volume percent carbon dioxide to about 95 volume percent carbon dioxide; wherein the oxygen stream comprises from about 70 volume percent oxygen to about 100 volume percent oxygen;wherein the inert gas stream comprising nitrogen comprises from about 70 volume percent nitrogen to about 100 volume percent nitrogen;wherein the gaseous control fuel stream comprises from about 80 volume percent to about 100 volume percent methane; andwherein the nitrogen stream comprises from about 85 volume percent nitrogen to about 100 volume percent nitrogen. 13. The system of any one of claims 1-2, wherein at least a portion of the nitrogen stream is sent to a location selected from the group consisting of: a nitrogen storage location, a nitrogen sales location, and a nitrogen venting location. 14. The system of claim 1, further comprising a secondary gas compressor configured to compress the secondary gas stream comprising carbon dioxide and hydrocarbons to form a compressed secondary gas stream prior to feeding at least a portion of the compressed secondary gas stream to the combustion unit. 15. The system of any one of claims 1-2, wherein at least a portion of the compressed gaseous carbon dioxide stream is sent to a location selected from the group consisting of: a carbon dioxide sequestration location, a carbon dioxide sales location, a carbon capture location, a venting location, and any combination thereof. 16. The system of claim 10, further comprising a desalination plant configured to utilize at least a portion of the mechanical power, at least a portion of the steam power, the at least a portion of the heat energy, and at least a portion of the heat generated by the inlet compressor. 17. The system of claim 14, further comprising a cross-exchange heating system configured to transfer at least a portion of the heat generated from a heat source to the compressed secondary gas stream, wherein the heat source is selected from the group consisting of: the carbon dioxide compressor, the heat recovery unit, the gaseous combustion stream, the gaseous exhaust stream, and any combination thereof. 18. The system of claim 2, wherein the gaseous exhaust stream is provided to the heat recovery unit at above atmospheric pressure. 19. The system of claim 1, wherein at least a portion of the system is located on an offshore barge or platform. 20. A method of improved hydrocarbon recovery, comprising: separating air into an oxygen stream and a nitrogen stream;providing a gaseous control fuel stream;combusting in a combustor, at least the gaseous control fuel stream and the high purity oxygen stream to form a gaseous combustion stream having carbon dioxide and water;receiving the gaseous combustion stream having carbon dioxide and water into a power generation system, wherein the power generation system produces at least a compressed gaseous carbon dioxide stream comprising from about 60 volume percent (vol %) carbon dioxide to about 95 vol % carbon dioxide;injecting at least a portion of the compressed gaseous carbon dioxide stream into an enhanced oil recovery reservoir; andinjecting at least a portion of the nitrogen stream into a pressure maintenance reservoir,producing a first hydrocarbon mixture from a first hydrocarbon recovery reservoir;separating the first hydrocarbon mixture into a first hydrocarbon stream and a secondary gas stream comprising carbon dioxide and hydrocarbons; andproducing the gaseous combustion stream having carbon dioxide and water at the combustion unit utilizing at least a portion of the secondary gas stream with the gaseous control fuel stream and the oxygen stream. 21. The method of claim 20, wherein the method of operating the power generation system comprises: expanding the gaseous combustion stream in an expander to produce mechanical power and a gaseous exhaust stream;cooling the gaseous exhaust stream in a heat recovery unit configured to produce heat energy, a cooled gaseous carbon dioxide stream, and a volume of water, wherein the heat energy is optionally utilized to produce steam for generating steam power; andcompressing the cooled gaseous carbon dioxide stream in a carbon dioxide compressor to form the compressed gaseous carbon dioxide stream. 22. The method of claim 21, further comprising: feeding at least a portion of the secondary gas stream comprising carbon dioxide and hydrocarbons to: 1) the gaseous control fuel stream for mixing or 2) the combustor in the step of combusting the gaseous control fuel stream and the oxygen stream. 23. The method of claim 22, further comprising: producing a second hydrocarbon mixture from a second hydrocarbon recovery reservoir;separating the second hydrocarbon mixture into a second hydrocarbon stream and an inert gas stream comprising nitrogen; andadding the inert gas stream comprising nitrogen to the nitrogen stream for injection into the pressure maintenance reservoir. 24. The method of claim 22, further comprising compressing the secondary gas stream comprising carbon dioxide and hydrocarbons prior to feeding at least a portion of the secondary gas stream to the combustor to form a compressed secondary gas stream. 25. The method of claim 20, further comprising recycling at least a portion of the compressed gaseous carbon dioxide stream to the combustor or the secondary gas stream. 26. The method of claim 21, further comprising providing at least a portion of the volume of water for use as irrigation water or to generate steam. 27. The method of claim 21, wherein the expander is selected from the group consisting of: an expander in a gas power turbine and a hot gas expander. 28. The method of claim 27, further comprising compressing atmospheric air in an inlet compressor; and utilizing, the compressed air in the air separation unit to form the oxygen stream and the nitrogen stream. 29. The method of claim 28, wherein the expander is the expander in a gas power turbine and the inlet compressor is driven by the gas power turbine; and utilizing the compressed gaseous carbon dioxide stream as a working fluid in the gas power turbine. 30. The method of claim 23, wherein the secondary gas stream comprising carbon dioxide comprises from about 60 volume percent carbon dioxide to about 95 volume percent carbon dioxide; wherein the oxygen stream comprises from about 70 volume percent oxygen to about 100 volume percent oxygen; wherein the inert gas stream comprising nitrogen comprises from about 70 volume percent nitrogen to about 100 volume percent nitrogen; wherein the gaseous control fuel stream comprises from about 80 volume percent to about 100 volume percent methane; and wherein the nitrogen stream comprises from about 85 volume percent nitrogen to about 100 volume percent nitrogen. 31. The method of claim 22, wherein the enhanced oil recovery reservoir is selected from the group consisting of: the first hydrocarbon recovery reservoir, the second hydrocarbon recovery reservoir, another hydrocarbon recovery reservoir, and any combination thereof. 32. The method of claim 23, wherein the pressure maintenance reservoir is selected from the group consisting of: the second hydrocarbon recovery reservoir, the first hydrocarbon recovery reservoir, another hydrocarbon recovery reservoir, and any combination thereof. 33. The method of claim 24, further comprising heating at least a portion of the compressed secondary gas stream utilizing a heat source selected from the group consisting of: heat generated by compressing the cooled gaseous carbon dioxide stream, heat generated by compressing atmospheric air, heat from the gaseous combustion stream having carbon dioxide and water, heat from the gaseous exhaust stream, the heat energy, and any combination thereof. 34. The method of claim 28, further comprising heating at least a portion of the compressed secondary gas stream utilizing a heat source selected from the group consisting of: heat generated by compressing the cooled gaseous carbon dioxide stream, heat generated by compressing atmospheric air, heat from the gaseous combustion stream having carbon dioxide and water, heat from the gaseous exhaust stream, the heat energy, and any combination thereof. 35. The method of claim 22, further comprising controlling the mixing and combustion of the gaseous control fuel stream, the secondary gas stream comprising carbon dioxide and hydrocarbons, and the oxygen stream to ensure consumption of substantially all of the oxygen in the oxygen stream. 36. The method of claim 35, wherein the combustor is selected from the group consisting of: an oxygen combustor, a pre-mix combustor, a piloted combustor, a partial oxidation (POX) combustor, a diffusion burner, an autothermal reformer, and an oxyClaus reaction furnace burner. 37. The method of claim 21, further comprising desalinating water in a desalination plant, wherein the desalination plant utilizes at least one of the of mechanical power, the heat energy, the steam power, heat generated by compressing the cooled gaseous carbon dioxide stream, heat from the gaseous combustion stream having carbon dioxide and water, heat from the gaseous exhaust stream, and any combination thereof. 38. The method of claim 21, wherein the gaseous exhaust stream is provided to the heat recovery unit at above atmospheric pressure. 39. The method of claim 20, further comprising sending at least a portion of the compressed gaseous carbon dioxide stream to a location selected from the group consisting of: a carbon dioxide sequestration location, a carbon dioxide sales location, a carbon capture location, and any combination thereof; and sending at least a portion of the nitrogen stream to a nitrogen storage location.
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