In situ thermal processing of an oil shale formation using a pattern of heat sources
A oil shale formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H 2 , 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. Heat sources may be used to heat the formation. The heat sources may be positioned within the formation in a selected pattern.
1. A method of treating an oil shale formation in situ, comprising:
providing heat from heaters to at least a portion of the formation through one or more open wellbores in the formation;
allowing the heat to transfer from the heaters to a part of the formation; and
producing a mixture from the formation through one or more production wells, wherein the heating is controlled such that the mixture can be produced from the formation as a vapor, wherein at least about 7 heaters are disposed in the formation for each production well, wherein three or more of the heaters are located in the formation in a unit of heaters, and wherein the unit of heaters comprises an equilateral triangular pattern.
2. The method of claim 1 , wherein at least about 20 heaters are disposed in the formation for each production well.
3. The method of claim 1 , wherein superposition of heat from at least two of the heaters pyrolyzes at least some hydrocarbons within the part of the formation.
4. The method of claim 1 , further comprising maintaining a temperature within the part within a pyrolysis temperature range of about 270° C. to about 400°
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 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.
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 of about 270° C. to about 400° C.
11. The method of claim 1 , wherein providing heat from the heaters to at least the portion of the formation comprises:
heating a selected volume (V) of the oil shale formation from the heaters, wherein the formation has an average heat capacity (C ν ), and wherein the heating pyrolyzes at least some hydrocarbons within the selected volume of the formation; and
wherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C ν *ρ B , wherein ρ B is 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 providing heat from the 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.).
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 weiglit to about 30% by weight of the condensable hydrocarbons comprise oxygen containing compounds, and wherein the oxygen containing compounds comprise phenols.
21. The meothd 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 and 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 a pressure within at least a majority of the part of the formation, 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 the mixture, wherein a partial pressure of H 2 within the mixture is greater than about 0.5 bars.
30. The method of claim 1 , wherein the partial pressure of H 2 within the mixture is measured when the mixture is at a production well.
31. 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.
32. The method of claim 1 , further comprising controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation.
33. The method of claim 1 , further comprising:
providing hydrogen (H 2 ) to the part of the formation to hydrogenate hydrocarbons within the part of the formation; and
heating a portion of the part of the formation with heat from hydrogenation.
34. The method of claim 1 , further comprising:
producing hydrogen and condensable hydrocarbons from the formation; and
hydrogenating a portion of the produced condensable hydrocarbons with at least a portion of the produced hydrogen.
35. 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.
36. The method of claim 1 , wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the part of the formation.
37. The method of claim 1 , wherein the heating is controlled to yield greater than about 60% by weight of condensable hydrocarbons, as measured by Fischer Assay.
38. The method of claim 1 , wherein a plurality of the units of heaters are repeated over an area of the formation to form a repetitive pattern of units.
39. A method of treating an oil shale formation in situ, comprising:
providing heat from heaters to at least a portion of the formation;
allowing the heat to transfer from the heaters to a part of the formation;
controlling the heat such that an average heating rate of the part of the formation is less than about 1° C. per day in a pyrolysis temperature range of about 270° C. to about 400° C.; and
producing a mixture from the formation through one or more production wells, wherein the heating is controlled such that the mixture can be produced from the formation as a vapor, and wherein at least about 7 heaters are disposed in the formation for each production well.
40. The method of claim 39 , wherein at least about 20 heaters are disposed in the formation for each production well.
41. The method of claim 39 , wherein superposition of heat from the heaters pyrolyzes least some hydrocarbons in the part of the formation.
42. The method of claim 39 , further comprising maintaining a temperature in the part in a pyrolysis temperature range of about 270° C. to about 400° C.
43. The method of claim 39 , wherein at least one of the heaters comprises an electrical heater.
44. The method of claim 39 , further comprising 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.
45. The method of claim 39 , allowing the heat to transfer comprises transferring heat substantially by conduction.
46. The method of claim 39 , wherein providing heat from the 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.).
47. The method of claim 39 , wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25°.
48. The method of claim 39 , further comprising 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.
49. The method of claim 39 , 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.
50. The method of claim 39 , wherein allowing the heat to transfer comprises substantially uniformly increasing a permeability of a majority of the part of the formation.
51. The method of claim 39 , further comprising providing heat from three or more of the 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.
52. The method of claim 39 , further comprising providing heat from three or more of the 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.