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Kafe 바로가기국가/구분 | United States(US) Patent 등록 |
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국제특허분류(IPC7판) |
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출원번호 | US-0841430 (2001-04-24) |
발명자 / 주소 |
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출원인 / 주소 |
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인용정보 | 피인용 횟수 : 169 인용 특허 : 379 |
A coal 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. Pressure within the
A coal 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. Pressure within the formation may be controlled as a function of temperature or temperature within the formation may be controlled as a function of pressure to yield a desired mixture.
1. A method of treating a coal 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 and a temperature in at least a majority of the p
1. A method of treating a coal 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 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; maintaining the controlled pressure of at least about 2.0 bars absolute; and producing a mixture from the formation. 2. The method of claim 1, wherein the one or more heaters comprise at least two heaters, and wherein controlled superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons in the part of the formation.3. 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.4. The method of claim 1, wherein at least one of the heaters comprises an electrical heater.5. The method of claim 1, wherein at least one of the heaters comprises a surface burner.6. The method of claim 1, wherein at least one of the heaters comprises a flameless distributed combustor.7. The method of claim 1, wherein at least one of the heaters comprises a natural distributed combustor.8. 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 of about 270° C. to about 400° C.9. 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 (Cν), 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*Cν*ρB, wherein ρB is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10° C./day. 10. The method of claim 1, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.11. The method of claim 1, wherein allowing the heat to transfer from the one or more heaters increases a thermal conductivity of at least a portion of the part of the formation to greater than about 0.5 W/(m° C.).12. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.13. 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.14. The method of claim 1, 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.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 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.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 formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 in the mixture is greater than about 0.5 bar.28. The method of claim 1, wherein a partial pressure of H2 is measured when the mixture is at a production well.29. 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 25.30. The method of claim 1, further comprising recirculating a portion of hydrogen from the mixture into the formation.31. The method of claim 1, further comprising:providing hydrogen (H2) 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. 32. The method of claim 1, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.33. 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.34. 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.35. 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.36. The method of claim 1, 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.37. The method of claim 1, further comprising providing heat from heaters to at least a portion of the formation, wherein the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.38. The method of claim 1, further comprising providing heat from heaters to at least a portion of the formation, wherein 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.39. A method of treating a coal 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 to raise an average temperature in the part of the formation to, or above, a temperature that will pyrolyze hydrocarbons in the part of the formation; producing a mixture from the formation; and controlling API gravity of the produced mixture to be greater than about 25 degrees API by controlling average pressure and average temperature in the part of the formation such that the average pressure in the part of the formation is greater than the pressure (p) set forth in the following equation for an assessed average temperature (T) in the part of the formation: p=e[?44000/T+67]where p is measured in psia and Tis measured in Kelvin.40. The method of claim 39, wherein the API gravity of the produced mixture is controlled to be greater than about 30 degrees API, and wherein the equation is:p=e[?31000/T+51]. 41. The method of claim 39, wherein the API gravity of the produced mixture is controlled to be greater than about 35 degrees API, and wherein the equation is:p=e[?22000/T+38]. 42. 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.43. The method of claim 39, wherein controlling the average temperature comprises maintaining a temperature in the part of the formation in a pyrolysis temperature range of about 270° C. to about 400° C.44. The method of claim 39, wherein at least one of the heaters comprises an electrical heater.45. The method of claim 39, wherein at least one of the heaters comprises a surface burner.46. The method of claim 39, wherein at least one of the heaters comprises a flameless distributed combustor.47. The method of claim 39, wherein at least one of the heaters comprises a natural distributed combustor.48. The method of claim 39, 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.49. 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 of about 270° C. to about 400° C.50. The method of claim 39, 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 (Cν), 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*Cν*ρB wherein ρB is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10° C./day. 51. The method of claim 39, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.52. The method of claim 39, wherein allowing the heat to transfer from the one or more heaters increases a thermal conductivity of at least a portion of the part of the formation to greater than about 0.5 W/(m° C.).53. 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 condensable hydrocarbons are olefins.54. 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.55. 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 0.15.56. The method of claim 39, 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.57. The method of claim 39, 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.58. The method of claim 39, 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.59. 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.60. 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.61. 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.62. 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.63. 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.64. 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,65. 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.66. The method of claim 39, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.67. The method of claim 39, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 in the mixture is greater than about 0.5 bar.68. The method of claim 39, wherein a partial pressure of H2 is measured when the mixture is at a production well.69. 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 25.70. The method of claim 39, further comprising recirculating a portion of hydrogen from the mixture into the formation.71. The method of claim 39, further comprising:providing hydrogen (H2) 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. 72. The method of claim 39, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.73. 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.74. 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.75. The method of claim 39, wherein the heat is controlled to yield greater than about 60% by weight of condensable hydrocarbons, as measured by Fischer Assay.76. 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.77. The method of claim 39, further comprising providing heat from heaters to at least a portion of the formation, wherein 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 39, further comprising providing heat from heaters to at least a portion of the formation, wherein 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: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 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; maintaining the controlled pressure above about 2 bars absolute; producing a mixture from the formation; and controlling a weight percentage of olefins of the produced mixture to be less than about 20% by weight by controlling average pressure and average temperature in the part of the formation such that the average pressure in the part of the formation is greater than the pressure (p) set forth in the following equation for an assessed average temperature (T) in the part of the formation: p=e[?57000/T+83]where p is measured in psia and T is measured in Kelvin.80. The method of claim 79, wherein the weight percentage of olefins of the produced mixture is controlled to be less than about 10% by weight, and wherein the equation is:p=e[?16000/T+28]. 81. The method of claim 79, wherein the weight percentage of olefins of the produced mixture is controlled to be less than about 5% by weight, and wherein the equation is:p=e[?12000/T+22]. 82. A method of treating a coal 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 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; maintaining the controlled pressure above about 2 bars absolute; producing a mixture from the formation; and controlling hydrocarbons having carbon numbers greater than 25 of the produced mixture to be less than about 25% by weight by controlling average pressure and average temperature in the part of the formation such that the average pressure in the part of the formation is greater than the pressure (p) set forth in the following equation for an assessed average temperature (T) in the part of the formation: p=e[?14000/T+25]where p is measured in psia and T is measured in Kelvin.83. The method of claim 82, wherein the hydrocarbons having carbon numbers greater than 25 of the produced mixture are controlled to be less than about 20% by weight, and wherein the equation is:p=e[?16000/T+28]. 84. The method of claim 82, wherein the hydrocarbons having carbon numbers greater than 25 of the produced mixture are controlled to be less than about 15% by weight, and wherein the equation is:p=e[?18000/T+32]. 85. The method of claim 82, 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.86. The method of claim 82, wherein at least one of the heaters comprises an electrical heater.87. The method of claim 82, wherein at least one of the heaters comprises a surface burner.88. The method of claim 82, wherein at least one of the heaters comprises a flameless distributed combustor.89. The method of claim 82, wherein at least one of the heaters comprises a natural distributed combustor.90. The method of claim 82, 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.91. The method of claim 82, wherein controlling the temperature comprises maintaining a temperature in the part of the formation in a pyrolysis temperature range of about 270° C. to about 400° C.92. The method of claim 82, 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 of about 270° C. to about 400° C.93. The method of claim 82, 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 (Cν), 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*CνρB, wherein ρB is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10° C./day. 94. The method of claim 82, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.95. The method of claim 82, wherein allowing the heat to transfer from the one or more heaters increases a thermal conductivity of at least a portion of the part of the formation to greater than about 0.5 W/(m° C.).96. The method of claim 82, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25° C.97. The method of claim 82, 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.98. The method of claim 82, 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 0.15.99. The method of claim 82, 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.100. The method of claim 82, 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.101. The method of claim 82, 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.102. The method of claim 82, 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.103. The method of claim 82, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.104. The method of claim 82, 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.105. The method of claim 82, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.106. The method of claim 82, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.107. The method of claim 82, 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.108. The method of claim 82, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia,109. The method of claim 82, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.110. The method of claim 82, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 in the mixture is greater than about 0.5 bar.111. The method of claim 82, wherein a partial pressure of H2 is measured when the mixture is at a production well.112. The method of claim 82, further comprising altering a pressure in the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.113. The method of claim 82, further comprising:providing hydrogen (H2) 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. 114. The method of claim 82, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.115. The method of claim 82, wherein allowing the heat to transfer increases a permeability of a majority of the part of the formation to greater than about 100 millidarcy.116. The method of claim 82, wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the part of the formation.117. The method of claim 82, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by Fischer Assay.118. The method of claim 82, 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.119. The method of claim 82, further comprising providing heat from 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.120. The method of claim 82, further comprising providing heat from heaters to at least a portion of the formation, wherein the beaters 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.121. A method of treating a coal 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 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; maintaining the controlled pressure above about 2 bars absolute; producing a mixture from the formation; and controlling an atomic hydrogen to carbon ratio of the produced mixture to be greater than about 1.7 by controlling average pressure and average temperature in the part of the formation such that the average pressure in the part of the formation is greater than the pressure (p) set forth in the following equation for an assessed average temperature (T) in the part of the formation: p=e[?38000/T+61]where p is measured in psia and T is measured in Kelvin.122. The method of claim 121, wherein the atomic hydrogen to carbon ratio of the produced mixture is controlled to be greater than about 1.8, and wherein the equation is:p=e[?13000/T+24]. 123. The method of claim 121, wherein the atomic hydrogen to carbon ratio of the produced mixture is controlled to be greater than about 1.9, and wherein the equation is:p=e[?8000/T+18]. 124. The method of claim 82, 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.125. The method of claim 79, wherein at least one of the heaters comprises an electrical heater.126. The method of claim 79, wherein at least one of the heaters comprises a surface burner.127. The method of claim 79, wherein at least one of the heaters comprises a flameless distributed combustor.128. The method of claim 79, wherein at least one of the heaters comprises a natural distributed combustor.129. The method of claim 121, 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.130. The method of claim 121, wherein at least one of the heaters comprises an electrical heater.131. The method of claim 121, wherein at least one of the heaters comprises a surface burner.132. The method of claim 121, wherein at least one of the heaters comprises a flameless distributed combustor.133. The method of claim 121, wherein at least one of the heaters comprises a natural distributed combustor.134. The method of claim 121, 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.135. The method of claim 121, wherein controlling the temperature comprises maintaining a temperature in the part of the formation in a pyrolysis temperature range of about 270° C. to about 400° C.136. The method of claim 121, 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 of about 270° C. to about 400° C.137. The method of claim 121, 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 (Cν), 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*Cν*ρB, wherein ρB is formation bulk density, and wherein an average heating rate (h) of the selected volume is about 10° C./day. 138. The method of claim 121, wherein allowing the heat to transfer comprises transferring heat substantially by conduction.139. The method of claim 121, wherein allowing the heat to transfer from the one or more heaters increases a thermal conductivity of at least a portion of the part of the formation to greater than about 0.5 W/(m° C.).140. The method of claim 121, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25° C.141. The method of claim 121, 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.142. The method of claim 121, 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 0.15.143. The method of claim 121, 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.144. The method of claim 121, 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.145. The method of claim 121, 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.146. The method of claim 121, 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.147. The method of claim 121, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds.148. The method of claim 121, 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.149. The method of claim 121, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes.150. The method of claim 121, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes.151. The method of claim 121, 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.152. The method of claim 121, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.153. The method of claim 121, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.154. The method of claim 121, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 in the mixture is greater than about 0.5 bar.155. The method of claim 121, wherein a partial pressure of H2 is measured when the mixture is at a production well.156. The method of claim 121, further comprising altering a pressure in the formation to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.157. The method of claim 121, further comprising:providing hydrogen (H2) 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. 158. The method of claim 121, wherein the produced mixture comprises hydrogen and condensable hydrocarbons, the method further comprising hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.159. The method of claim 121, wherein allowing the heat to transfer increases a permeability of a majority of the part of the formation to greater than about 100 millidarcy.160. The method of claim 121, 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.161. The method of claim 121, further comprising controlling the heat to yield greater than about 60% by weight of condensable hydrocarbons, as measured by Fischer Assay.162. The method of claim 121, 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.163. The method of claim 121, further comprising providing heat from heaters to at least a portion of the formation, wherein the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises a triangular pattern.164. The method of claim 121, further comprising providing heat from heaters to at least a portion of the formation, wherein 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.165. The method of claim 79, wherein the one or more heaters comprise at least two heaters, and wherein controlled superposition of heat from at least the two heaters pyrolyzes at least some hydrocarbons in the part of the formation.166. The method of claim 79, 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.167. The method of claim 79, further comprising providing hydrogen (H2) to the part of the formation.168. The method of claim 79, further comprising providing hydrogen (H2) to the part of the formation to hydrogenate hydrocarbons in the formation.
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