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A method for treating a relatively low permeability formation containing heavy hydrocarbons in situ may include providing heat from one or more heat sources to a portion of the formation. The heat may be allowed to transfer from the heat sources to a selected section of the formation. The transferre

A method for treating a relatively low permeability formation containing heavy hydrocarbons in situ may include providing heat from one or more heat sources to a portion of the formation. The heat may be allowed to transfer from the heat sources to a selected section of the formation. The transferred heat may pyrolyze at least some hydrocarbons within the selected section. A mixture of hydrocarbons may be produced from the selected section. In some embodiments, the permeability of a portion of the formation may be increased relative to an initial permeability of the portion.

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1. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising:providing heat from one or more heaters to at least a section of the formation;allowing the heat to transfer from the one or more heaters to a part of the formation such that a permeabil

1. A method of treating a relatively low permeability formation containing heavy hydrocarbons in situ, comprising:providing heat from one or more heaters to at least a section of the formation;allowing the heat to transfer from the one or more heaters to a part of the formation such that a permeability of a majority of at least some of the part of the formation increases substantially uniformly; andcontrolling 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. 2. The method of claim 1, 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. 3. The method of claim 1, further comprising maintaining a temperature in the part of the formation in a pyrolysis temperature range. 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 section of the formation comprises:heating a selected volume (V) of the relatively low permeability formation containing heavy hydrocarbons 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; andwherein heating energy/day (Pwr) provided to the selected volume is equal to or less than h*V*C v *ρ B , wherein μ B 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 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.). 12. The method of claim 1, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons having an API gravity of at least about 25 °. 13. The method of claim 1, further comprising producing a mixture from the formation, 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, further comprising producing a mixture from the formation, 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. 15. The method of claim 1, further comprising producing a mixture from the formation, 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. 16. The method of claim 1, further comprising producing a mixture from the formation, 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. 17. The method of claim 1, further comprising producing a mixtu re from the formation, 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. 18. The method of claim 1, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein greater than about 20% by weight of the condensable hydrocarbons are aromatic compounds. 19. The method of claim 1, further comprising 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. 20. The method of claim 1, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein less than about 0.3% by weight of the condensable hydrocarbons are asphaltenes. 21. The method of claim 1, further comprising producing a mixture from the formation, wherein the produced mixture comprises condensable hydrocarbons, and wherein about 5% by weight to about 30% by weight of the condensable hydrocarbons are cycloalkanes. 22. The method of claim 1, further comprising producing a mixture from the formation, 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. 23. The method of claim 1, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein greater than about 0.05% by weight of the produced mixture is ammonia. 24. The method of claim 1, further comprising producing a mixture from the formation, wherein the produced mixture comprises ammonia, and wherein the ammonia is used to produce fertilizer. 25. The method of claim 1, 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. 26. The method of claim 1, further comprising controlling formation conditions to produce a mixture from the formation, wherein a partial pressure of H 2 in the mixture is greater than about 0.5 bars. 27. The method of claim 1, further comprising producing a mixture from the formation, wherein a partial pressure of H 2 in the mixture is measured when the mixture is at a production well. 28. 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. 29. The method of claim 1, further comprising producing a mixture from the formation and controlling formation conditions by recirculating a portion of hydrogen from the mixture into the formation. 30. 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; andheating a portion of the part of the formation with heat from hydrogenation. 31. 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. 32. 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. 33. The method of claim 1, further comprising producing a mixture in a production well, wherein at least about 7 heaters are disposed in the formation for each production well. 34. The method of claim 33, wherein at least about 20 heaters are disposed in the formation for each production well. 35. 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. 36. 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. 37. The method of claim 1, further comprising providing hydrogen (H 2 ) to at least a portion of the formation.