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Kafe 바로가기국가/구분 | United States(US) Patent 등록 |
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국제특허분류(IPC7판) |
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출원번호 | US-0131122 (2002-04-24) |
발명자 / 주소 |
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출원인 / 주소 |
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인용정보 | 피인용 횟수 : 196 인용 특허 : 354 |
An 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 desired temperature. In some embodim
An 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 desired temperature. In some embodiments, the formation to be treated may be selected based on formation characteristics.
What is claimed is: 1. A method of treating an oil shale formation in situ, comprising: providing heat from one or more heaters to at least a portion of the formation; allowing the heat to transfer from the one or more heaters to a part of the formation; controlling the heat such that an average
What is claimed is: 1. A method of treating an oil shale formation in situ, comprising: providing heat from one or more heaters to at least a portion of the formation; allowing the heat to transfer from the one or more 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.; wherein the part of the formation has been selected for heating using an atomic hydrogen weight percentage of at least a portion of hydrocarbons in the part of the formation, and wherein at least the portion of the hydrocarbons in the part of the formation comprises an atomic hydrogen weight percentage, when measured on a dry, ash-free basis, of greater than about 4.0 %; and producing a mixture from the formation. 2. A method of treating an oil shale formation in situ, comprising: providing heat from one or more heaters to at least a portion of the formation; allowing the heat to transfer from the one or more heaters to a part of the formation; providing hydrogen (H2) to the part of the formation to hydrogenate hydrocarbons in the part of the formation, and heating at least some of the part of the formation with heat from hydrogenation; wherein at least some hydrocarbons within the part of the formation have an initial atomic hydrogen weight percentage of greater than about 4.0%; and producing a mixture from the formation. 3. A method of treating an oil shale formation in situ, comprising: providing heat from one or more heaters to at least a section of the formation; allowing the heat to transfer from the one or more heaters to a part of the formation; 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; wherein the part of the formation has been selected for heating using vitrinite reflectance of at least some hydrocarbons in the part of the formation, and wherein at least a portion of the hydrocarbons in the part of the formation comprises a vitrinite reflectance of greater than about 0.3%; wherein at least a portion of the hydrocarbons in the part of the formation comprises a vitrinite reflectance of less than about 4.5%; and producing a mixture from the formation. 4. The method of claim 3, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons within the part of the formation. 5. The method of claim 3, further comprising maintaining a temperature within the part of the formation within a pyrolysis temperature from about 270째 C. to about 400째 C. 6. The method of claim 3, wherein the vitrinite reflectance of at least the portion of hydrocarbons within the part of the formation is between about 0.47% and about 1.5% such that a majority of the produced mixture comprises condensable hydrocarbons. 7. The method of claim 3, wherein the vitrinite reflectance of at least the portion of hydrocarbons within the part of the formation is between about 1.4% and about 4.2% such that a majority of the produced mixture comprises non-condensable hydrocarbons. 8. The method of claim 3, wherein at least one of the one or more heaters comprises an electrical heater. 9. The method of claim 3, wherein at least one of the one or more heaters comprises a surface burner. 10. The method of claim 3, wherein at least one of the one or more heaters comprises a flameless distributed combustor. 11. The method of claim 3, wherein at least one of the one or more heaters comprises a natural distributed combustor. 12. The method of claim 3, 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. 13. The method of claim 3, 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. 14. The method of claim 3, wherein providing heat from the one or more heaters to at least the section of the formation comprises: heating a selected volume (V) of the oil shale formation from the one or more heaters, wherein the formation has an average heat capacity (Cv), 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*Cv*ρB, wherein ρB is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10째 C./day. 15. The method of claim 3, wherein allowing the heat to transfer comprises transferring heat substantially by conduction. 16. The method of claim 3, wherein providing heat from the one or more 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/(m 째 C.). 17. The method of claim 3, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25째. 18. The method of claim 3, 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. 19. The method of claim 3, 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. 20. The method of claim 3, 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. 21. The method of claim 3, 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. 22. The method of claim 3, 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. 23. The method of claim 3, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols. 24. The method of claim 3, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds. 25. The method of claim 3, 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. 26. The method of claim 3, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes. 27. The method of claim 3, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes. 28. The method of claim 3, 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 of the non-condensable component at 25째 C. and one atmosphere absolute pressure, and wherein the molecular hydrogen is less than about 80% by volume of the non-condensable component at 25째 C. and one atmosphere absolute pressure. 29. The method of claim 3, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia. 30. The method of claim 3, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer. 31. The method of claim 3, 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. 32. The method of claim 3, wherein the partial pressure of H2 within the mixture is measured when the mixture is at a production well. 33. The method of claim 3, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25. 34. The method of claim 3, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation. 35. The method of claim 3, 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. 36. The method of claim 3, 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. 37. The method of claim 3, 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. 38. The method of claim 3, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the part of the formation. 39. The method of claim 3, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by Fischer Assay. 40. The method of claim 3, wherein producing the mixture comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well. 41. The method of claim 40, wherein at least about 20 heaters are disposed in the formation for each production well. 42. The method of claim 3, further comprising providing heat from three or more 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. 43. The method of claim 3, further comprising providing heat from three or more 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. 44. A method of treating an oil shale formation in situ, comprising: providing heat from one or more heaters to at least a portion of the formation; allowing the heat to transfer from the one or more 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.; wherein the part of the formation has been selected for heating using a total organic matter weight percentage of at least a portion of the part of the formation, and wherein at least the portion of the part of the formation comprises a total organic matter weight percentage of at least about 5.0%; and producing a mixture from the formation. 45. A method of treating an oil shale formation in situ, comprising: providing heat from one or more heaters to at least a portion of the formation; allowing the heat to transfer from the one or more 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.; wherein at least some hydrocarbons within the part of the formation have an initial total organic matter weight percentage of at least about 5.0%; and producing a mixture from the formation. 46. A method of treating an oil shale formation in situ, comprising: providing heat from one or more heaters to at least a portion of the formation; allowing the heat to transfer from the one or more 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.; wherein the part of the formation has been selected for heating using an atomic oxygen weight percentage of at least a portion of hydrocarbons in the part of the formation, and wherein at least a portion of the hydrocarbons in the part of the formation comprises an atomic oxygen weight percentage of less than about 15% when measured on a dry, ash free basis; and producing a mixture from the formation. 47. A method of treating an oil shale formation in situ, comprising: providing heat from one or more heaters to a part of the formation; allowing the heat to transfer from the one or more heaters to the part of the formation to pyrolyze hydrocarbons within the 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.; wherein at least some of the hydrocarbons within the part of the formation have an initial atomic oxygen weight percentage of less than about 15%; and producing a mixture from the formation. 48. A method of treating an oil shale formation in situ, comprising: providing heat from one or more heaters to at least a portion of the formation; allowing the heat to transfer from the one or more 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.; wherein the part of the formation has been selected for heating using an atomic hydrogen to carbon ratio of at least a portion of hydrocarbons in the part of the formation, wherein at least a portion of the hydrocarbons in the part of the formation comprises an atomic hydrogen to carbon ratio greater than about 0.70, and wherein the atomic hydrogen to carbon ratio is less than about 1.65; and producing a mixture from the formation. 49. A method of treating an oil shale formation in situ, comprising: providing heat from one or more heaters to a part of the formation; allowing the heat to transfer from the one or more heaters to the part of the formation to pyrolyze hydrocarbons within the part of the formation; 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; wherein at least some hydrocarbons within the part of the formation have, an initial atomic hydrogen to carbon ratio greater than about 0.70; wherein the initial atomic hydrogen to carbon ratio is less than about 1.65; and producing a mixture from the formation. 50. A method of treating an oil shale formation in situ, comprising: providing heat from one or more heaters to at least a portion of the formation; allowing the heat to transfer from the one or more heaters to a part of the formation; 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; wherein the part of the formation has been selected for heating using an atomic oxygen to carbon ratio of at least a portion of hydrocarbons in the part of the formation, wherein at least a portion of the hydrocarbons in the part of the formation comprises an atomic oxygen to carbon ratio greater than about 0.025, and wherein the atomic oxygen to carbon ratio of at least a portion of the hydrocarbons in the part of the formation is less than about 0.15; and producing a mixture from the formation. 51. A method of treating an oil shale formation in situ, comprising providing heat from one or more heaters to a part of the formation; allowing the heat to transfer from the one or more heaters to the part of the formation to pyrolyze hydrocarbons within the part of the formation; 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; wherein at least some hydrocarbons within the part of the formation have an initial atomic oxygen to carbon ratio greater than about 0.025; wherein the initial atomic oxygen to carbon ratio is less than about 0.15; and producing a mixture from the formation. 52. A method of treating an oil shale formation in situ, comprising: providing heat from one or more heaters to at least a portion of the formation; allowing the heat to transfer from the one or more heaters to a part of the formation; 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; wherein the part of the formation has been selected for heating using a moisture content in the part of the formation, and wherein at least a portion of the part of the formation comprises a moisture content of less than about 15% by weight; and producing a mixture from the formation. 53. A method of treating an oil shale formation in situ, comprising: providing heat from one or more heaters to a part of the formation; allowing the heat to transfer from the one or more heaters to the part of the formation; 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; wherein at least a portion of the part of the formation has an initial moisture content of less than about 15% by weight; and producing a mixture from the formation.
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