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Kafe 바로가기국가/구분 | United States(US) Patent 등록 |
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국제특허분류(IPC7판) |
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출원번호 | US-0131286 (2002-04-24) |
발명자 / 주소 |
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출원인 / 주소 |
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인용정보 | 피인용 횟수 : 205 인용 특허 : 400 |
A oil shale formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. Heat sources m
A oil shale formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. Heat sources may be used to heat the formation. The heat sources may be positioned within the formation in a selected pattern.
What is claimed is: 1. A method of treating an oil shale formation in situ, comprising: providing heat from heaters to at least a portion of the formation through one or more open wellbores in the formation; allowing the heat to transfer from the heaters to a part of the formation; and producing
What is claimed is: 1. A method of treating an oil shale formation in situ, comprising: providing heat from heaters to at least a portion of the formation through one or more open wellbores in the formation; allowing the heat to transfer from the heaters to a part of the formation; and producing a mixture from the formation through one or more production wells, wherein the heating is controlled such that the mixture can be produced from the formation as a vapor, wherein at least about 7 heaters are disposed in the formation for each production well, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises an equilateral triangular pattern. 2. The method of claim 1, wherein at least about 20 heaters are disposed in the formation for each production well. 3. The method of claim 1, wherein superposition of heat from at least two of the heaters pyrolyzes at least some hydrocarbons within the part of the formation. 4. The method of claim 1, further comprising maintaining a temperature within the part within a pyrolysis temperature range of about 270째 C. to about 400째 5. The method of claim 1, wherein at least one of the heaters comprises an electrical heater. 6. The method of claim 1, wherein at least one of the heaters comprises a surface burner. 7. The method of claim 1, wherein at least one of the heaters comprises a flameless distributed combustor. 8. The method of claim 1, wherein at least one of the heaters comprises a natural distributed combustor. 9. The method of claim 1, further comprising controlling a pressure and a temperature within at least a majority of the part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure. 10. The method of claim 1, further comprising controlling the heat such that an average heating rate of the part of the formation is less than about 1째 C. per day in a pyrolysis temperature range of about 270째 C. to about 400째 C. 11. The method of claim 1, wherein providing heat from the heaters to at least the portion of the formation comprises: heating a selected volume (V) of the oil shale formation from the heaters, wherein the formation has an average heat capacity (Cν ), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*Cν*ρ B, wherein ρB is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10째 C./day. 12. The method of claim 1, wherein allowing the heat to transfer comprises transferring heat substantially by conduction. 13. The method of claim 1, wherein providing heat from the heaters comprises heating the part of the formation such that a thermal conductivity of at least a portion of the part of the formation is greater than about 0.5 W/(m째 C.). 14. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25째. 15. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condensable hydrocarbons are olefins. 16. The method of claim 1, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein a molar ratio of ethene to ethane in the non-condensable hydrocarbons ranges from about 0. 001 to about 0.15. 17. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is nitrogen. 18. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is oxygen. 19. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur. 20. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weiglit to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols. 21. The meothd of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds. 22. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 5% by weight of the condensable hydrocarbons comprises multi-ring aromatics with more than two rings. 23. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes. 24. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes. 25. The method of claim 1, wherein the produced mixture comprises a non-condensable component, wherein the non-condensable component comprises molecular hydrogen, wherein the molecular hydrogen is greater than about 10% by volume and less than about 80% by volume of the non-condensable component at 25째 C. and one atmosphere absolute pressure. 26. The method of claim 1, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia. 27. The method of claim 1, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer. 28. The method of claim 1, further comprising controlling a pressure within at least a majority of the part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute. 29. The method of claim 1, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H2 within the mixture is greater than about 0.5 bars. 30. The method of claim 1, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well. 31. The method of claim 1, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25. 32. The method of claim 1, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation. 33. The method of claim 1, further comprising: providing hydrogen (H2) to the part of the formation to hydrogenate hydrocarbons within the part of the formation; and heating a portion of the part of the formation with heat from hydrogenation. 34. The method of claim 1, further comprising: producing hydrogen and condensable hydrocarbons from the formation; and hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen. 35. The method of claim 1, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the part of the formation to greater than about 100 millidarcy. 36. The method of claim 1, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the part of the formation. 37. The method of claim 1, wherein the heating is controlled to yield greater than about 60% by weight of condensable hydrocarbons, as measured by Fischer Assay. 38. The method of claim 1, wherein a plurality of the units of heaters are repeated over an area of the formation to form a repetitive pattern of units. 39. A method of treating an oil shale formation in situ, comprising: providing heat from heaters to at least a portion of the formation; allowing the heat to transfer from the heaters to a part of the formation; controlling the heat such that an average heating rate of the part of the formation is less than about 1째 C. per day in a pyrolysis temperature range of about 270째 C. to about 400째 C.; and producing a mixture from the formation through one or more production wells, wherein the heating is controlled such that the mixture can be produced from the formation as a vapor, and wherein at least about 7 heaters are disposed in the formation for each production well. 40. The method of claim 39, wherein at least about 20 heaters are disposed in the formation for each production well. 41. The method of claim 39, wherein superposition of heat from the heaters pyrolyzes least some hydrocarbons in the part of the formation. 42. The method of claim 39, further comprising maintaining a temperature in the part in a pyrolysis temperature range of about 270째 C. to about 400째 C. 43. The method of claim 39, wherein at least one of the heaters comprises an electrical heater. 44. The method of claim 39, further comprising controlling a pressure and a temperature in at least a majority of the part of the formation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure. 45. The method of claim 39, allowing the heat to transfer comprises transferring heat substantially by conduction. 46. The method of claim 39, wherein providing heat from the heaters comprises heating the part of the formation such that a thermal conductivity of at least a portion of the part of the formation is greater than about 0.5 W/(m째 C.). 47. The method of claim 39, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25째. 48. The method of claim 39, further comprising controlling a pressure in at least a majority of the part of the formation, wherein the controlled pressure is at least about 2.0 bars absolute. 49. The method of claim 39, wherein allowing the heat to transfer comprises increasing a permeability of a majority of the part of the formation to greater than about 100 millidarcy. 50. The method of claim 39, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the part of the formation. 51. The method of claim 39, further comprising providing heat from three or more of the heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern. 52. The method of claim 39, further comprising providing heat from three or more of the heaters to at least a portion of the formation, wherein three or more of the heaters are located in the formation in a unit of heaters, wherein the unit of heaters comprises a triangular pattern, and wherein a plurality of the units are repeated over an area of the formation to form a repetitive pattern of units.
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