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| 국가/구분 | United States(US) Patent 등록 |
|---|---|
| 국제특허분류(IPC7판) |
|
| 출원번호 | US-0128700 (2002-04-24) |
| 발명자 / 주소 |
|
| 출원인 / 주소 |
|
| 인용정보 | 피인용 횟수 : 229 인용 특허 : 405 |
An oil shale formation may be treated using an in situ thermal process. Heat may be provided to a portion of the formation from one or more heat sources having a horizontal orientation in the formation. Heat may be allowed to transfer from the heat sources to a section of the formation. Hydrocarbons
An oil shale formation may be treated using an in situ thermal process. Heat may be provided to a portion of the formation from one or more heat sources having a horizontal orientation in the formation. Heat may be allowed to transfer from the heat sources to a section of the formation. Hydrocarbons, H2, and/or other formation fluids may be produced from the formation.
1. A method of treating a layer of an oil shale formation in situ, comprising:providing heat from heaters to at least a portion of the layer, wherein one or more of the heaters are positioned proximate an edge of the layer; allowing the heat to transfer from the heaters to a part of the layer such t
1. A method of treating a layer of an oil shale formation in situ, comprising:providing heat from heaters to at least a portion of the layer, wherein one or more of the heaters are positioned proximate an edge of the layer; allowing the heat to transfer from the heaters to a part of the layer such that superimposed heat from the heaters pyrolyzes at least some hydrocarbons in the part of the layer; and producing a mixture from the formation. 2. The method of claim 1, wherein at least one of the heaters is laterally spaced from a center of the layer.3. The method of claim 1, wherein at least one of the heaters is positioned in a staggered line.4. The method of claim 1, wherein heat from the one or more heaters positioned proximate the edge of the layer increases an amount of hydrocarbons produced per unit of energy input to the heaters.5. The method of claim 1, wherein heat from the one or more heaters positioned proximate the edge of the layer increases the volume of formation undergoing pyrolysis per unit of energy input to the heaters.6. The method of claim 1, wherein at least one of the heaters comprises an electrical heater.7. The method of claim 1, wherein at least one of the heaters comprises a surface burner.8. The method of claim 1, wherein at least one of the heaters comprises a flameless distributed combustor.9. The method of claim 1, wherein at least one of the heaters comprises a natural distributed combustor.10. The method of claim 1, further comprising controlling a pressure and a temperature in at least a majority of the part of the layer, wherein the pressure is controlled as a function of temperature, or the temperature is controlled as a function of pressure.11. The method of claim 1, further comprising controlling the heat such that an average heating rate of the part of the layer is less than about 1.0° C. per day in a pyrolysis temperature range from about 270° C. to about 400° C.12. The method of claim 1, wherein providing heat from the heaters to at least the portion of the layer comprises:heating a selected volume (V) of the oil shale formation from the heaters, wherein the formation has an average heat capacity (Cν), and wherein the heating pyrolyzes at least some hydrocarbons 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. 13. The method of claim 1, wherein providing heat from the heaters increases a thermal conductivity of at least some of the part of the layer 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 comprises condensable hydrocarbons, and wherein less than about 1% by weight, when calculated on an atomic basis, of the condensable hydrocarbons is sulfur.20. The method of claim 1, wherein the produced mixture comprises condensable hydrocarbons, wherein about 5% by 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 pressure.26. The method of claim 1, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia.27. The method of claim 1, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer.28. The method of claim 1, further comprising controlling a pressure in at least a majority of the part of the layer, wherein the controlled pressure is at least about 2.0 bars absolute.29. The method of claim 1, further comprising controlling formation conditions to produce a mixture of condensable hydrocarbons and H2, wherein a partial pressure of H2 in the mixture is greater than about 0.5 bar.30. The method of claim 29, wherein the partial pressure of H2 is measured when the mixture is at a production well.31. The method of claim 1, further comprising altering a pressure in the layer to inhibit production of hydrocarbons from the formation having carbon numbers greater than about 25.32. The method of claim 1, further comprising recirculating a portion of hydrogen from the mixture into the layer.33. The method of claim 1, further comprising:providing hydrogen (H2) to the part of the layer to hydrogenate hydrocarbons in the part of the layer; and heating at least some of the part of the layer with heat from hydrogenation. 34. 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.35. The method of claim 1, wherein allowing the heat to transfer increases a permeability of a majority of the part of the layer to greater than about 100 millidarcy.36. The method of claim 1, wherein allowing the heat to transfer increases a permeability of a majority of the part of the layer such that the permeability of the majority of the part is substantially uniform.37. 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.38. 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.39. The method of claim 38, wherein at least about 20 heaters are disposed in the formation for each production well.40. The method of claim 1, further comprising providing heat from heaters to at least a section 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.41. The method of claim 1, further comprising providing heat from heaters to at least a section of the formation, wherein 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.42. The method of claim 1, further comprising controlling a pressure in at least a majority of the part of the layer with a valve coupled to at least one of the heaters.
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