최소 단어 이상 선택하여야 합니다.
최대 10 단어까지만 선택 가능합니다.
다음과 같은 기능을 한번의 로그인으로 사용 할 수 있습니다.
NTIS 바로가기다음과 같은 기능을 한번의 로그인으로 사용 할 수 있습니다.
DataON 바로가기다음과 같은 기능을 한번의 로그인으로 사용 할 수 있습니다.
Edison 바로가기다음과 같은 기능을 한번의 로그인으로 사용 할 수 있습니다.
Kafe 바로가기국가/구분 | United States(US) Patent 등록 |
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국제특허분류(IPC7판) |
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출원번호 | US-0841502 (2001-04-24) |
발명자 / 주소 |
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출원인 / 주소 |
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인용정보 | 피인용 횟수 : 255 인용 특허 : 276 |
A hydrocarbon containing formation may be treated using an in situ thermal process. Hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to a first portion of the formation to mobilize hydrocarbons within the formation. Heat may be applied to a seco
A hydrocarbon containing formation may be treated using an in situ thermal process. Hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to a first portion of the formation to mobilize hydrocarbons within the formation. Heat may be applied to a second portion of the formation to raise a temperature of the second portion to a pyrolysis temperature. Vaporized hydrocarbons and pyrolysis fluids may be produced from the formation.
A hydrocarbon containing formation may be treated using an in situ thermal process. Hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to a first portion of the formation to mobilize hydrocarbons within the formation. Heat may be applied to a seco
A hydrocarbon containing formation may be treated using an in situ thermal process. Hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to a first portion of the formation to mobilize hydrocarbons within the formation. Heat may be applied to a second portion of the formation to raise a temperature of the second portion to a pyrolysis temperature. Vaporized hydrocarbons and pyrolysis fluids may be produced from the formation. hroeder; US-3191679, 19650600, Miller; US-3205944, 19650900, Walton; US-3205946, 19650900, Prats et al.; US-3207220, 19650900, Williams; US-3208531, 19650900, Tamplen; US-3209825, 19651000, Alexander et al.; US-3221811, 19651200, Prats; US-3223166, 19651200, Hunt et al.; US-3233668, 19660200, Hamilton et al.; US-3237689, 19660300, Justheim; US-3241611, 19660300, Dougan; US-3244231, 19660400, Grekel et al.; US-3250327, 19660500, Crider; US-3267680, 19660800, Schlumberger; US-3273640, 19660900, Huntington; US-3275076, 19660900, Sharp; US-3284281, 19661100, Thomas; US-3285335, 19661100, Reistle; US-3294167, 19661200, Vogel; US-3310109, 19670300, Marx et al.; US-3316962, 19670500, Lange; US-3338306, 19670800, Cook; US-3349845, 19671000, Holbert et al.; US-3352355, 19671100, Putman; US-3379248, 19680400, Strange; US-3380913, 19680400, Henderson; US-3456721, 19690700, Smith; US-3477058, 19691100, Vedder et al.; US-3497000, 19700200, Hujsak et al.; 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US-4594468, 19860600, Minderhoud; US-4597441, 19860700, Ware et al.; US-4598770, 19860700, Shu et al.; US-4605680, 19860800, Beuther et al.; US-4608818, 19860900, Goebel et al.; US-4613754, 19860900, Vinegar et al.; US-4616705, 19861000, Stegemeier et al.; US-4635197, 19870100, Vinegar et al.; US-4637464, 19870100, Forgac et al.; US-4640352, 19870200, Vanmeurs et al.; US-4644283, 19870200, Vinegar et al.; US-4651825, 19870300, Wilson; US-4658215, 19870400, Vinegar et al.; US-4662438, 19870500, Taflove et al.; US-4662439, 19870500, Puri; US-4662443, 19870500, Puri et al.; US-4663711, 19870500, Vinegar et al.; US-4669542, 19870600, Venkatesan; US-4671102, 19870600, Vinegar et al.; US-4682652, 19870700, Huang et al.; US-4691771, 19870900, Ware et al.; US-4704514, 19871100, Van Egmond et al.; US-4716960, 19880100, Eastlund et al.; US-4719423, 19880100, Vinegar et al.; US-4728892, 19880300, Vinegar et al.; US-4730162, 19880300, Vinegar et al.; US-4737267, 19880400, Pao et al.; US-4743854, 19880500, Vinegar et al.; US-4762425, 19880800, Shakkottai et al.; US-4769602, 19880900, Vinegar et al.; US-4769606, 19880900, Vinegar et al.; US-4772634, 19880900, Farooque; US-4776638, 19881000, Hahn; US-4787452, 19881100, Jennings, Jr.; US-4793656, 19881200, Siddoway et al.; US-4817711, 19890400, Jeambey; US-4818370, 19890400, Gregoli et al.; US-4827761, 19890500, Vinegar et al.; US-4848924, 19890700, Nuspl et al.; US-4856341, 19890800, Vinegar et al.; US-4856587, 19890800, Nielson; US-4860544, 19890800, Krieg et al.; US-4866983, 19890900, Vinegar et al.; US-4884455, 19891200, Vinegar et al.; US-4886118, 19891200, Van Meurs et al.; US-4895206, 19900100, Price; US-4927857, 19900500, McShea, III et al.; US-4928765, 19900500, Nielson; US-4931171, 19900600, Piotter; US-4974425, 19901200, Krieg et al.; US-4982786, 19910100, Jennings, Jr.; US-4983319, 19910100, Gregoli et al.; US-4984594, 19910100, Vinegar et al.; US-4987368, 19910100, Vinegar; US-4994093, 19910200, Wetzel et al.; US-5014788, 19910500, Puri et al.; 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US-5318116, 19940600, Vinegar et al.; US-5339897, 19940800, Leaute; US-5339904, 19940800, Jennings, Jr. et al.; US-5340467, 19940800, Gregoli et al.; US-5349859, 19940900, Kleppe; US-5366012, 19941100, Lohbeck; US-5388640, 19950200, Puri et al.; US-5388641, 19950200, Yee et al.; US-5388642, 19950200, Puri et al.; US-5388643, 19950200, Yee et al.; US-5388645, 19950200, Puri et al.; US-5391291, 19950200, Winquist et al.; US-5392854, 19950200, Vinegar et al.; US-5404952, 19950400, Vinegar et al.; US-5409071, 19950400, Wellington et al.; US-5411089, 19950500, Vinegar et al.; US-5411104, 19950500, Stanley; US-5415231, 19950500, Northrop et al.; US-5431224, 19950700, Laali; US-5433271, 19950700, Vinegar et al.; US-5437506, 19950800, Gray; US-5439054, 19950800, Chaback et al.; US-5454666, 19951000, Chaback et al.; US-5497087, 19960300, Vinegar et al.; US-5498960, 19960300, Vinegar et al.; US-5517593, 19960500, Nenniger et al.; US-5525322, 19960600, Willms; US-5541517, 19960700, Hartmann et al.; US-5553189, 19960900, Stegemeier et al.; US-5554453, 19960900, Steinfeld et al.; US-5566756, 19961000, Chaback et al.; US-5624188, 19970400, West; US-5632336, 19970500, Notz et al.; US-5656239, 19970800, Stegemeier et al.; US-5676212, 19971000, Kuckes; US-RE35696, 19971200, Mikus; US-5713415, 19980200, Bridges; US-5751895, 19980500, Bridges; US-5861137, 19990100, Edlund; US-5862858, 19990100, Wellington et al.; US-5868202, 19990200, Hsu; US-5899269, 19990500, Wellington et al.; US-5968349, 19991000, Duyvesteyn et al.; US-5984010, 19991100, Elias et al.; US-5985138, 19991100, Humphreys; US-5997214, 19991200, de Rouffignac et al.; US-6015015, 20000100, Luft et al.; US-6016867, 20000100, Gregoli et al.; US-6016868, 20000100, Gregoli et al.; US-6019172, 20000200, Wellington et al.; US-6023554, 20000200, Vinegar et al.; US-6056057, 20000500, Vinegar et al.; US-6079499, 20000600, Mikus et al.; US-6085512, 20000700, Agee et al.; US-6094048, 20000700, Vinegar et al.; US-6102122, 20000800, de Rouffignac; US-6102622, 20000800, Vinegar et al.; US-6112808, 20000900, Isted; US-6152987, 20001100, Ma et al.; US-6172124, 20010100, Wolflick et al.; US-6173775, 20010100, Elias et al.; US-6187465, 20010200, Galloway; US-6328104, 20011200, Graue; US-6354373, 20020300, Vercaemer et al.; US-6485232, 20021100, Vinegar et al.; US-20020018697, 20020200, Vinegar et al. mation, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.9. 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 during pyrolysis within a pyrolysis temperature range of about 270° C. to about 400° C.10. The method of claim 1, wherein providing heat from the one or more heaters to at least the portion of the formation comprises:heating a selected volume (V) of the coal 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; andwherein heating energy/day (Pwr) provided to the selected volume is equal to or less thanh*V*C v*ρBwherein ρBis formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10° C./day.11. The method of claim 1, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.12. The method of claim 1, 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° C.).13. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.14. 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.15. 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 0.15.16. 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.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 oxygen.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 sulfur.19. 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.20. 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.21. 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.22. 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.23. 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.24. 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, and wherein the molecular hydrogen is less than about 80% by volume of the non-condensa ble component at 25° C. and one atmosphere absolute pressure.25. 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.26. The method of claim 1, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.27. 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 bar absolute.28. The method of claim 1, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H2within the mixture is greater than about 0.5 bar.29. The method of claim 20, wherein the partial pressure of H2within the mixture is measured when the mixture is at a production well.30. 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 25.31. The method of claim 1, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.32. The method of claim 1, further comprising:providing hydrogen (H2) to the heated part of the formation to hydrogenate hydrocarbons within the part of the formation; andheating a portion of the part of the formation with heat from hydrogenation.33. The method of claim 1, further comprising:producing hydrogen and condensable hydrocarbons from the formation; andhydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.34. 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.35. The method of claim 1, wherein allowing the heat to transfer further comprises substantially uniformly increasing a permeability of a majority of the part of the formation.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 Fischer Assay.37. The method of claim 1, wherein producing the mixture comprises producing the mixture in a production well, and wherein the heaters are positioned such that the ratio of heaters to the production well is at least about 7 to 1.38. The method of claim 1, 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.39. The method of claim 1, 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.40. A method of treating a coal formation in situ, comprising: assessing an atomic oxygen weight percentage of at least some hydrocarbons in the formation;selecting a part of the formation for heating, wherein at least some hydrocarbons in the part have an initial atomic oxygen weight percentage of less than about 15%;providing heat from one or more heaters to the part of the formation;allowing the heat to transfer from the one or more heaters to the part of the formation to pyrolyze at least some hydrocarbons within the part of the formation; andproducing a mixture from the formation.41. The method of claim 40, wherein the one or more heaters comprise at least two heaters, and wherein superposition of heat from at least th e two heaters pyrolyzes at least some hydrocarbons within the part of the formation.42. The method of claim 40, further comprising maintaining a temperature within the part of the formation within a pyrolysis temperature range.43. The method of claim 40, wherein one or more of the heaters comprise electrical heaters.44. The method of claim 40, wherein one or more of the heaters comprise surface burners.45. The method of claim 40, wherein one or more of the heaters comprise flameless distributed combustors.46. The method of claim 40, wherein one or more of the heaters comprise natural distributed combustors.47. The method of claim 40, 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.48. The method of claim 40, 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 during pyrolysis within a pyrolysis temperature range of about 270° C. to about 400° C.49. The method of claim 40, wherein providing heat from the one or more heaters to the part of the formation comprises:heating a selected volume (V) of the coal 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; andwherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*Cv*ρB, wherein ρBis formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10° C./day.50. The method of claim 40, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.51. The method of claim 40, 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° C.).52. The method of claim 40, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.53. The method of claim 40, 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.54. The method of claim 40, 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 40, 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.56. The method of claim 40, 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.57. The method of claim 40, 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.58. The method of claim 40, 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.59. The method of claim 40, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.60. The method of claim 40, 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 tw o rings.61. The method of claim 41, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.62. The method of claim 40, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.63. The method of claim 40, 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 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.64. The method of claim 40, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.65. The method of claim 40, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.66. The method of claim 40, 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 bar absolute.67. The method of claim 40, further comprising controlling formation conditions to produce the mixture, wherein a partial pressure of H2within the mixture is greater than about 0.5 bar.68. The method of claim 40, wherein the partial pressure of H2within the mixture is measured when the mixture is at a production well.69. The method of claim 40, further comprising altering a pressure within the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.70. The method of claim 40, further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.71. The method of claim 40, further comprising:providing hydrogen (H2) to the heated part of the formation to hydrogenate hydrocarbons within the part of the formation; andheating a portion of the part of the formation with heat from hydrogenation.72. The method of claim 40, further comprising:producing hydrogen and condensable hydrocarbons from the formation; andhydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.73. The method of claim 40, 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.74. The method of claim 40, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of at least a majority of the part of the formation.75. The method of claim 40, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by Fischer Assay.76. The method of claim 40, wherein producing the mixture comprises producing the mixture in a production well, and wherein the heaters are positioned such that the ratio of heaters to the production well is at least about 7 to 1.77. The method of claim 40, 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.78. The method of claim 40, 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.79. A method of treating a coal formation in situ, comprising: assessing an atomic oxygen to carbon ratio of at least a portion of the hydrocarbons in the formation;selecting a part of the formation for heating, wherein at least a portion of the hydrocarbons in the part have an atomic oxygen to carbon ratio within a range from about 0.025 to about 0.15;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 the part of the formation; andproducing a mixture from the formation.80. The method of claim 79, 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.81. The method of claim 79, further comprising maintaining a temperature within the part of the formation within a pyrolysis temperature range from about 270° C. to about 400° C.82. The method of claim 79, wherein one or more of the heaters comprise electrical heaters.83. The method of claim 79, wherein one or more of the heaters comprise surface burners.84. The method of claim 79, wherein one or more of the heaters comprise flameless distributed combustors.85. The method of claim 79, wherein one or more of the heaters comprise natural distributed combustors.86. The method of claim 79, 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.87. The method of claim 79, 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 during pyrolysis.88. The method of claim 79, wherein providing heat from the one or more heaters to at least the portion of the formation comprises:heating a selected volume (V) of the coal 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; andwherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*Cv*ρB, wherein ρBis formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10° C./day.89. The method of claim 79, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.90. The method of claim 79, 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° C.).91. The method of claim 79, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.92. The method of claim 79, 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.93. The method of claim 79, 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 0.15.94. The method of claim 79, 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.95. The method of claim 79, 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.96. The method of claim 79, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable
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