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Kafe 바로가기국가/구분 | United States(US) Patent 등록 |
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국제특허분류(IPC7판) |
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출원번호 | US-0405901 (2009-03-17) |
등록번호 | US-8230929 (2012-07-31) |
발명자 / 주소 |
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출원인 / 주소 |
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대리인 / 주소 |
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인용정보 | 피인용 횟수 : 0 인용 특허 : 240 |
A method for producing hydrocarbon fluids from an organic-rich rock formation to a surface facility is provided. The method may include heating the formation in situ to cause pyrolysis of formation hydrocarbons, and producing production fluids from the formation via two or more wells. The produced f
A method for producing hydrocarbon fluids from an organic-rich rock formation to a surface facility is provided. The method may include heating the formation in situ to cause pyrolysis of formation hydrocarbons, and producing production fluids from the formation via two or more wells. The produced fluids have been at least partially generated as a result of pyrolysis of the formation hydrocarbons. In addition, the produced fluids comprise non-condensable fluids, or gases, which taken together have an averaged Wobbe Index which varies at a rate of more than 5% over a period of time. The method also includes controlling production from one or more of the wells such that a combination of the production fluids from the wells results in a combined gas stream that's averaged Wobbe Index varies at a rate of less than 5% over the period of time. The combined stream comprises combustible hydrocarbon fluids.
1. A method for producing hydrocarbon fluids from an organic-rich rock formation to a surface facility, comprising: heating the organic-rich rock formation in situ in order to cause pyrolysis of formation hydrocarbons;producing production fluids from the organic-rich rock formation via two or more w
1. A method for producing hydrocarbon fluids from an organic-rich rock formation to a surface facility, comprising: heating the organic-rich rock formation in situ in order to cause pyrolysis of formation hydrocarbons;producing production fluids from the organic-rich rock formation via two or more wells, each of which two or more wells produces fluids which: have been at least partially generated as a result of pyrolysis of the formation hydrocarbons located in the organic-rich rock formation, andcomprise noncondensable gases having a Wobbe Index value which varies at a rate of more than 5% over a period of time;obtaining a combined gas stream from the production fluids, the combined gas stream comprising combustible hydrocarbon fluids; andcontrolling production from the two or more wells such that a combination of the production fluids from the two or more wells results in the combined gas stream having a Wobbe Index value that varies at a rate of less than 5% over the period of time. 2. The method of claim 1, wherein the formation hydrocarbons comprise heavy hydrocarbons or solid hydrocarbons. 3. The method of claim 1, wherein the organic-rich rock formation is an oil shale formation. 4. The method of claim 3, wherein the period of time is at least six months. 5. The method of claim 3, wherein the Wobbe Index value constitutes a daily average or a weekly average of Wobbe Index assessments. 6. The method of claim 3, wherein controlling production comprises controlling start-up times of the two or more wells. 7. The method of claim 6, wherein the two or more wells comprises at least a first group of wells, a second group of wells and a third group of wells. 8. The method of claim 7, wherein the first group of wells comprises a different number of wells than the second group of wells or the third group of wells. 9. The method of claim 7, wherein the first group of wells begins to produce at a first start-up time, the second group of wells begins to produce at a second later start-up time, and the third group of wells begins to produce at yet a third later start-up time. 10. The method of claim 9, wherein: a time between the first start-up time and the second start-up time represents a first increment;a time between the second start-up time and the third start-up time represents a second increment; andthe first increment and the second increment are different lengths of time. 11. The method of claim 7, wherein each of the wells in the first group of wells and the second group of wells is heated over the same period of time before the respective first and second start-up times begin. 12. The method of claim 7, wherein the first group of wells is heated for a first length of time before producing production fluids from the first group of wells begins, and the second group of wells is heated for a second length of time that is greater than the first length of time before producing production fluids from the second group of wells begins. 13. The method of claim 6, wherein controlling start-up times comprises performing a computer simulation in order to assess the impact of production from the two or more wells on a composition of the combined gas stream over the period of time. 14. The method of claim 6, further comprising: monitoring the composition of the non-condensable gases in the production fluids of the two or more wells; andwherein controlling production from the two or more wells comprises adjusting the composition of the combined gas stream by adding selected one or more inert gas species to the combined gas stream from a gas reserve. 15. The method of claim 3, wherein controlling production comprises controlling production rates from the two or more wells. 16. The method of claim 3, wherein the surface facility comprises a gas turbine; andthe method further comprises passing the combined gas stream through the gas turbine to form a gas turbine exhaust stream, the gas turbine being configured to provide energy to an electrical generator. 17. The method of claim 16, further comprising: adjusting the composition of the combined gas stream before it is passed through the gas turbine by (i) adding methane from a gas reserve, (ii) adding carbon dioxide from a gas reserve, (iii) removing carbon dioxide, (iv) adding hydrogen from a gas reserve, (v) removing hydrogen, (vi) removing ethane, (vii) removing propane, or (viii) combinations thereof. 18. The method of claim 16, further comprising: adjusting the composition of the combined gas stream before it is passed through the gas turbine by adding any of carbon dioxide, hydrogen, ethane, ethylene, propane, or combinations thereof in order to increase flame speed, adjust burn rate, or stabilize combustion of the combined gas stream. 19. The method of claim 16, wherein: the heating step comprises heating the organic-rich rock formation through use of electrical resistance heaters; andthe electrical resistance heaters are powered at least partially by the electrical generator. 20. The method of claim 16, wherein the combined gas stream composition is sufficient to meet a targeted NOx concentration in the gas turbine exhaust stream. 21. The method of claim 3, further comprising: monitoring the composition of the non-condensable gases in the production fluids of the two or more wells; andwherein controlling production from the two or more wells comprises adjusting production rates in response to data received as a result of the monitoring. 22. The method of claim 3, wherein upon controlling production from the two or more wells: a concentration of CO2 in the combined gas stream generally ranges from between 25 and 50 mol. %; anda concentration of H2 in the combined gas stream generally ranges from between 20 and 40 mol. %. 23. A method for utilizing gas produced from an in situ conversion process in a hydrocarbon development area, comprising: operating in a development area in which production fluids are to be produced as a result of pyrolysis of formation hydrocarbons located in an organic-rich formation within the development area;dividing the development area into sections, each respective section having two or more production wells;selecting a gas turbine, the gas turbine being designed to receive a combustible gas stream having concentrations of carbon dioxide and hydrogen within defined ranges, and the gas turbine being configured to provide energy to an electrical generator or to a steam boiler;incrementally producing production fluids from the organic-rich rock formation within the respective sections over a period of time, wherein the production fluids are delivered to a surface processing facility; andobtaining a combined gas stream from the production fluids, the combined gas stream having concentrations of carbon dioxide and hydrogen that remain substantially within the defined ranges for the gas turbine over the period of time, and the combined gas stream further comprising combustible hydrocarbons. 24. The method of claim 23, wherein the combined gas stream is obtained by: separating the respective production fluids at a surface facility into liquid streams and gas streams; andcombining the gas streams separated from the respective production fluids to form the combined gas stream. 25. The method of claim 23, wherein the combined gas stream is obtained by: commingling the respective production fluids; andseparating the commingled production fluids at a surface facility into at least a combined liquid stream and a combined gas stream. 26. The method of claim 23, wherein: the formation hydrocarbons comprise oil shale; andthe production fluids comprise shale oil. 27. The method of claim 26, further comprising: passing the combined gas stream through the gas turbine to form a gas turbine exhaust stream. 28. The method of claim 27, wherein: the combined gas stream comprises hydrogen sulfide; andthe method further comprises removing at least a portion of the hydrogen sulfide from the combined gas stream before it is passed through the gas turbine. 29. The method of claim 27, further comprising: adjusting the composition of the combined gas stream before it is passed through the gas turbine by (i) adding methane from a gas reserve, (ii) adding carbon dioxide from a gas reserve, (iii) removing carbon dioxide, (iv) adding hydrogen from a gas reserve, (v) removing hydrogen, (vi) removing ethane, (vii) removing propane, or (viii) combinations thereof. 30. The method of claim 26, further comprising: adjusting the production rate of the production fluids being produced from at least one section of the development area to maintain the concentrations of carbon dioxide and hydrogen within the combined gas stream within the defined ranges. 31. The method of claim 26, further comprising: simultaneously producing production fluids from a first section, a second section and a third section of the development area at different production rates; andadjusting the production rate of production fluids being produced from the first section, the second section and the third section over a period of time to maintain the concentrations of carbon dioxide and hydrogen within the defined ranges. 32. The method of claim 31, wherein: the concentration of carbon dioxide in the combined gas stream generally ranges from between 25 and 50 mol. %; andthe concentration of hydrogen in the combined gas stream generally ranges from between 20 and 40 mol. %. 33. The method of claim 31, further comprising: selecting start-up times for production wells within the second section and the third section to further maintain the concentrations of carbon dioxide and hydrogen within the defined ranges. 34. A method for producing hydrocarbon fluids from an organic-rich rock formation in a shale oil development area, comprising: dividing the development area into a plurality of production areas;heating the organic-rich rock formation in situ in a first production area of the development area in order to cause pyrolysis of formation hydrocarbons;producing hydrocarbon fluids from the first production area via two or more production wells at a first production rate;sequentially heating the organic-rich rock formation in situ in respective subsequent production areas in order to cause pyrolysis of formation hydrocarbons in the respective subsequent production areas;incrementally producing hydrocarbon fluids from the respective subsequent production areas, each subsequent production area comprising two or more production wells;obtaining a gas stream from the hydrocarbon fluids; andcontrolling production rates from one or more of the subsequent production areas in order to substantially match the capacity of fluids processing facilities at the development area and to maintain a substantially constant concentration of carbon dioxide or hydrogen in the gas stream. 35. The method of claim 34, wherein matching the capacity of processing facilities means maintaining a substantially constant hydrocarbon production rate from the development area. 36. The method of claim 34, wherein incrementally producing hydrocarbon fluids from the respective subsequent production areas comprises spacing start-up of production between the respective subsequent production areas by at least three months. 37. The method of claim 34, wherein controlling production rates comprises controlling production rates from individual wells within one or more selected subsequent production areas. 38. The method of claim 34, wherein: the surface facility comprises a gas turbine configured to provide energy to an electrical generator; andthe method further comprises passing the gas stream through the gas turbine to form a gas turbine exhaust stream. 39. The method of claim 34, wherein incrementally producing hydrocarbon fluids comprises controlling start-up times of the two or more production wells in the respective subsequent production areas. 40. The method of claim 39, wherein the start-up times are separated by at least six months.
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