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Kafe 바로가기국가/구분 | United States(US) Patent 등록 |
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국제특허분류(IPC7판) |
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출원번호 | US-0841491 (2001-04-24) |
발명자 / 주소 |
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출원인 / 주소 |
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인용정보 | 피인용 횟수 : 257 인용 특허 : 276 |
A hydrocarbon containing 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. A
A hydrocarbon containing 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. A pressure within a majority of the portion may be controlled and/or maintained to alter a composition of the produced mixture.
1. A method of treating a hydrocarbon containing formation in situ, comprising: providing heat from heaters to at least a section of the formation; allowing the heat to transfer from at least two of the heaters to a part of the formation such that superposition of heat from at least the two hea
1. A method of treating a hydrocarbon containing formation in situ, comprising: providing heat from heaters to at least a section of the formation; allowing the heat to transfer from at least two of the heaters to a part of the formation such that superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons in 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; and producing a mixture from the formation. 2. The method of claim 1, wherein controlling the pressure comprises controlling the pressure with a valve coupled to at least one of the heaters.3. The method of claim 1, wherein controlling the pressure comprises controlling the pressure with a valve coupled to a production well located in the formation.4. The method of claim 1, further comprising controlling formation conditions, wherein controlling formation conditions comprises maintaining a temperature in the part of the formation in a pyrolysis temperature range of about 270° C. to about 400° C.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 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.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 1° C. per day in a pyrolysis temperature range from about 270° C. to about 400° C.11. The method of claim 1, wherein providing heat from the heaters to at least the section of the formation comprises: heating a selected volume (V) of the hydrocarbon containing formation from the heaters, wherein the formation has an average heat capacity (C V), and wherein the heating pyrolyzes at least some hydrocarbons in 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*C V*ρB, wherein ρBis formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10° 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 allowing the heat to transfer from at least two of the heaters to the part of the formation increases a thermal conductivity of at least a portion of the part of the formation to greater than about 0.5 W/(m ° C.).14. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.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 co mprises 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 weight to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.21. The method 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 of the non-condensable component at 25° C. and one atmosphere absolute pressure, and wherein the molecular hydrogen is less than about 80% by volume of the non-condensable component at 25° 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 formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2in the mixture is greater than about 0.5 bar.29. The method of claim 28, wherein a partial pressure of H2is measured when the mixture is at a production well.30. The method of claim 1, further comprising altering a pressure in the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.31. The method of claim 1, further comprising controlling formation conditions, wherein controlling formation conditions comprises recirculating at least some of hydrogen from the mixture into the formation.32. The method of claim 1, further comprising: providing hydrogen (H 2) to the part of the formation to hydrogenate hydrocarbons in the part of the formation; and heating a portion of the part of the formation with heat from hydrogenation. 33. The method of claim 1, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, and hydrogenating at least some of the produced condensable hydrocarbons with at least some of the produced hydrogen.34. The method of claim 1, wherein allowing the heat to transfer increases a permeability of a majority of the part of the formation to greater than about 100 millidarcy.35. The method of claim 1, wherein allowing the heat to transfer increases a permeability of a majority of the part of the formation such that the permeability of the majority of the part of the formation is substantially uniform.36. The method of claim 1, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by the Fischer Assay.37. The method of claim 1, wherein producing the mixture from the formation comprises producing the mixture in a production well, and wherein at least about 7 heaters are disposed in the formation for each production well.38. A method of treating a hydrocarbon containing formation in situ, comprising: providing heat from heaters to at least a section of the formation; allowing the heat to transfer from two or more of the heaters to a part of the formation such that superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons in 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; controlling the heat from two or more of the heaters such that an average temperature in at least a majority of the part of the formation is less than about 375° C.; and producing a mixture from the formation. 39. A method of treating a hydrocarbon containing formation in situ, comprising: providing heat from one or more heaters to at least a section of the formation; allowing the heat to transfer directly from the one or more heaters to a part of the formation; maintaining a pressure in at least a majority of the part of the formation above 2.0 bars absolute; and producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity higher than an API gravity of condensable hydrocarbons in a mixture producible from the formation at the same temperature and at atmospheric pressure. 40. The method of claim 39, 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 in the part of the formation.41. The method of claim 39, further comprising controlling formation conditions, wherein controlling formation conditions comprises maintaining a temperature in the part of the formation in a pyrolysis temperature range from about 270° C. to about 400° C.42. The method of claim 39, wherein at least one of the heaters comprises an electrical heater.43. The method of claim 39, wherein at least one of the heaters comprises a surface burner.44. The method of claim 39, wherein at least one of the heaters comprises a flameless distributed combustor.45. The method of claim 39, wherein at least one of the heaters comprises a natural distributed combustor.46. The method of claim 39, further comprising controlling the 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.47. The method of claim 39, further comprising controlling the heat such that an average heating rate of the part of the formation is less than about 1° C. per day in a pyrolysis temperature range from about 270° C. to about 400° C.48. The method of claim 39, wherein providing heat from the one or more heaters to at least the section of the formation comprises: heating a select volume (V) of the hydrocarbon containing formation from the one or more heaters, wherein the formation has an average heat capacity (C V), and wherein the heating pyrolyzes at least some hydrocarbons in 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*C V*ρB, wherein ρBis formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10° C./day.49. The method of claim 39, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.50. The method of claim 39, wherein allowing the heat to transfer from the one or more heaters to the part of the formation increases a thermal conductivity of at least a portion of the part of the formation to greater than about 0.5 W/(m ° C.).51. The method of claim 39, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.52. The method of claim 39, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the condens able hydrocarbons are olefins.53. The method of claim 39, wherein the produced mixture comprises non-condensable hydrocarbons, and wherein about 0.1% by weight to about 15% by weight of the non-condensable hydrocarbons are olefins.54. The method of claim 39, 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 0.15.55. The method of claim 39, 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.56. The method of claim 39, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.57. The method of claim 39, 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.58. The method of claim 39, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.59. The method of claim 39, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.60. The method of claim 39, 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 25° C. and one atmosphere absolute pressure, and wherein the molecular hydrogen is less than about 80% by volume of the non-condensable component at 25 ° C. and one atmosphere absolute pressure.61. The method of claim 39, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.62. The method of claim 39, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.63. The method of claim 39, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2in the mixture is greater than about 0.5 bar.64. The method of claim 39, wherein a partial pressure of H2is measured when the mixture is at a production well.65. The method of claim 39, further comprising altering a pressure in the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.66. The method of claim 39, further comprising controlling formation conditions, wherein controlling formation conditions comprises recirculating at least some hydrogen from the mixture into the formation.67. The method of claim 39, further comprising: providing hydrogen (H 2) to the part of the formation to hydrogenate hydrocarbons in the part of the formation; and heating a portion of the part of the formation with heat from hydrogenation. 68. The method of claim 39, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, and hydrogenating at least some of the produced condensable hydrocarbons with at least some of the produced hydrogen.69. The method of claim 39, wherein allowing the heat to transfer increases a permeability of a majority of the part of the formation to greater than about 100 millidarcy.70. The method of claim 39, wherein allowing the heat to transfer increases a permeability of a majority of the part of the formation such that the permeability of the majority of the part of the formation is substantially uniform.71. The method of claim 39, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as mea sured by the Fischer Assay.72. The method of claim 39, 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.73. The method of claim 39, 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.74. The method of claim 39, 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.75. The method of claim 37, wherein at least about 20 heaters are disposed in the formation for each production well.76. The method of claim 72, wherein at least about 20 heaters are disposed in the formation for each production well.77. The method of claim 38, wherein at least one of the heaters comprises a natural distributed combustor.78. The method of claim 38, further comprising controlling the heat such that an average heating rate of the part of the formation is less than about 1° C. per day in a temperature range from about 270° C. to about 375° C.79. The method of claim 38, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.80. The method of claim 38, 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 0.15.81. The method of claim 38, 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.82. The method of claim 38, wherein at least some of the mixture comprises hydrogen (H2), and recirculating at least some of the hydrogen from the mixture in the formation.83. The method of claim 38, further comprising providing hydrogen (H2) to the part of the formation.84. The method of claim 38, wherein the produced mixture comprises hydrogen (H2) and condensable hydrocarbons, and hydrogenating at least some of the produced condensable hydrocarbons with at least some of the produced hydrogen.85. A method of treating a hydrocarbon containing formation in situ, comprising: providing heat from one or more heaters to at least a section of the formation; allowing the heat to transfer directly from the one or more heaters to a part of the formation; maintaining a pressure in at least a majority of the part of the formation above 2.0 bars absolute when an average temperature in the part is in a range from about 270° C. to about 400° C.; providing hydrogen (H 2) to the part of the formation; and producing a mixture from the formation. 86. The method of claim 85, wherein at least one of the heaters comprises a natural distributed combustor.87. The method of claim 85, wherein at least some of the mixture comprises hydrogen (H2), and recirculating at least some of the hydrogen from the mixture into the formation.88. The method of claim 85 wherein the produced mixture comprises hydrogen (H2) and condensable hydrocarbons, and hydrogenating at least some of the produced condensable hydrocarbons with at least some of the produced hydrogen.89. A method of treating a hydrocarbon containing formation in situ, comprising: providing heat from one or more heaters to at least a section of the formation; allowing the heat to transfer directly from the one or more heaters to a part of the formation; increasing a temperature in the part at a rate of less than about 1° C. per day when an average temperature in the par t is in a range from about 270° C. to about 400° C.; maintaining a pressure in at least a majority of the part of the formation above 2.0 bars absolute when the average temperature is in the range from about 270° C. to about 400° C.; and producing a mixture from the formation. 90. The method of claim 89, wherein at least one of the heaters comprises a natural distributed combustor.91. The method of claim 89, wherein at least some of the mixture comprises hydrogen (H2), and recirculating at least some of the hydrogen from the mixture in the formation.92. The method of claim 89, further comprising providing hydrogen (H2) to the part of the formation.93. The method of claim 89, wherein the produced mixture comprises hydrogen (H2) and condensable hydrocarbons, and hydrogenating at least some of the produced condensable hydrocarbons with at least some of the produced hydrogen.94. A method of treating a hydrocarbon containing formation in situ, comprising: providing heat from one or more heaters to at least a section of the formation; allowing the heat to transfer directly from the one or more heaters to a part of the formation; maintaining a pressure in at least a majority of the part of the formation above 2.0 bars absolute when an average temperature in the part is in a range from about 270° C. to about 400° C.; and producing a mixture from the formation, 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. 95. The method of claim 94, wherein at least one of the heaters comprises a natural distributed combustor.96. The method of claim 94, wherein at least some of the mixture comprises hydrogen (H2), and recirculating at least some of the hydrogen from the mixture in the formation.97. The method of claim 94, further comprising providing hydrogen (H2) to the part of the formation.98. The method of claim 94, wherein the produced mixture comprises hydrogen (H2) and condensable hydrocarbons, and hydrogenating at least some of the produced condensable hydrocarbons with at least some of the produced hydrogen.99. The method of claim 85, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.100. The method of claim 85, further comprising controlling the heat such that an average heating rate of the part of the formation is less than about 1° C. per day in the range from about 270° C. to about 400° C.101. The method of claim 89, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.102. The method of claim 85, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
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