Heater assisted fluid treatment of a subsurface formation

• US 8,851,170 B2
• Filed: 04/09/2010
• Issued: 10/07/2014
• Est. Priority Date: 04/10/2009
• Status: Expired due to Fees

• Current Assignee: Shell Oil Company (Shell Plc)
• Original Assignee: Shell Oil Company (Shell Plc)
• Inventors: Ayodele, Oluropo Rufus, Colmenares, Tulio Rafael, Dindoruk, Deniz Sumnu, Karanikas, John Michael, Pino, Henry Eduardo Sr.
• Primary Examiner(s): Bates, Zakiya W
• Application Number:
  US12/757,621
• Publication Number:
  US 20100258309A1
• Time in Patent Office: 1,642 Days
• Field of Search: None
• US Class Current: 166/272.3
• CPC Class Codes: E21B 36/04 using electrical heaters
• CPC Class Codes: E21B 43/2401 by means of electricity
• CPC Class Codes: E21B 43/243 Combustion in situ
• CPC Class Codes: H05B 2214/03 Heating of hydrocarbons

Abstract

A method for treating a tar sands formation includes providing heat from a first heater located between a steam injection well and a production well in a hydrocarbon containing layer. The first heater, the steam injection well, and the production well are located substantially horizontally in the layer. Heat is provided from a second heater horizontally offset from the first heater. The second heater is located vertically above an injection/production well and substantially horizontally in the layer. Steam is injected into the layer through the steam injection well after a selected amount of heat is provided from the first heater. Hydrocarbons are produced from the layer through the production well. Steam is injected and hydrocarbons are produced alternately through the injection/production well after a selected amount of heat is provided from the second heater.

Claims

1. A method for treating a tar sands formation, comprising:

providing heat from a substantially horizontal portion of a first heater, wherein the substantially horizontal portion of the first heater is located between a substantially horizontal portion of a steam injection well and a substantially horizontal portion of a production well in a hydrocarbon containing layer of the formation;

providing heat from a substantially horizontal portion of a second heater horizontally offset from the first heater, the substantially horizontal portion of the second heater being located vertically above an injection/production well in the hydrocarbon containing layer;

injecting steam into the hydrocarbon containing layer through the substantially horizontal portion of the steam injection well after a selected amount of heat is provided from the substantially horizontal portion of the first heater;

producing hydrocarbons from the layer through the substantially horizontal portion of the production well; and

alternately injecting additional steam and producing additional hydrocarbons through the injection/production well after a selected amount of heat is provided from the substantially horizontal portion of the second heater.

2. The method of claim 1, wherein the substantially horizontal portion of the first heater is approximately vertically equidistant between the substantially horizontal portion of the steam injection well and the substantially horizontal portion of the production well.

3. The method of claim 1, wherein the steam is injected through the substantially horizontal portion of the steam injection well at a pressure that is above the formation fracturing pressure and below the overburden fracture pressure of the formation.

4. The method of claim 1, wherein the steam is injected through the injection/production well at a pressure that is above the formation fracturing pressure and below the overburden fracture pressure of the formation.

5. The method of claim 1, wherein the steam injected through the substantially horizontal portion of the steam injection well is at least 0.5 MPa below the pressure of the additional steam injected through the inj ection/production well.

6. The method of claim 1, wherein the first heater and/or the second heater are electric heaters.

7. The method of claim 1, wherein the substantially horizontal portion of the first heater and/or the substantially horizontal portion of the second heater provide heat at a heat injection rate of at least about 1000 watts per meter.

8. The method of claim 1, wherein the selected amount of heat provided from the substantially horizontal portion of the first heater creates sufficient steam injectivity between the substantially horizontal portion of the steam injection well and the substantially horizontal portion of the production well for injection of the steam from the substantially horizontal portion of the steam injection well to move hydrocarbons to the substantially horizontal portion of the production well.

9. The method of claim 1, wherein the selected amount of heat provided from the substantially horizontal portion of the first heater is reached after about one year of heating using the substantially horizontal portion of the first heater.

10. The method of claim 1, wherein the selected amount of heat provided from the substantially horizontal portion of the second heater creates sufficient steam injectivity around the injection/production well for injection of the additional steam from the injection/production well.

11. The method of claim 1, wherein the selected amount of heat provided from the substantially horizontal portion of the second heater is reached after about one year of heating using the substantially horizontal portion of the second heater.

12. The method of claim 1, wherein the injection/production well is located substantially horizontally in the hydrocarbon containing layer.

13. The method of claim 1, wherein the substantially horizontal portion of the first heater is turned off on or about the time injection of steam through the substantially horizontal portion of the steam injection well is started.

14. The method of claim 1, wherein the substantially horizontal portion of the second heater is turned off on or about the time steam injection interconnectivity between the injection/production well and the substantially horizontal portion of the production well is achieved.

15. The method of claim 1, wherein the initial vertical matrix permeability in the hydrocarbon containing layer is at most about 300 millidarcy.

16. The method of claim 1, wherein the initial horizontal matrix permeability in the hydrocarbon containing layer is at most about 1 darcy.

17. The method of claim 1, wherein the initial viscosity of fluid in the hydrocarbon containing layer is at least about 1×

10⁶ centipoise.

18. The method of claim 1, wherein the hydrocarbon containing layer has an initial permeability that is heterogenous.

19. The method of claim 1, wherein providing heat to the hydrocarbon containing layer from the substantially horizontal portion of the first heater and/or the substantially horizontal portion of the second heater increases steam injectivity in the layer.

20. The method of claim 1, wherein the substantially horizontal portion of the second heater is horizontally displaced from the substantially horizontal portion of the first heater in the hydrocarbon containing layer.

21. The method of claim 1, wherein the substantially horizontal portion of the first heater is located in a wellbore.

22. The method of claim 1, wherein the substantially horizontal portion of the second heater is located in a wellbore.

23. The method of claim 1, wherein the substantially horizontal portion of the first heater, the substantially horizontal portion of the steam injection well, and the substantially horizontal portion of the production well are spaced apart in the hydrocarbon containing layer.

24. A method for treating a tar sands formation, comprising:

providing heat from a substantially horizontal portion of a heater located in a wellbore between a substantially horizontal portion of a steam injection well and a substantially horizontal portion of a production well in a hydrocarbon containing layer of the formation, wherein the substantially horizontal portion of the heater is approximately vertically equidistant between the substantially horizontal portion of the steam injection well and the substantially horizontal portion of the production well;

injecting steam into the hydrocarbon containing layer through the substantially horizontal portion of the steam injection well after a selected amount of heat is provided from the substantially horizontal portion of the heater; and

producing hydrocarbons from the layer through the substantially horizontal portion of the production well.

25. The method of claim 24, wherein the steam is injected through the substantially horizontal portion of the steam injection well at a pressure that is above the formation fracturing pressure and below the overburden fracture pressure of the formation.

26. The method of claim 24, wherein the substantially horizontal portion of the heater is an electric heater.

27. The method of claim 24, wherein the substantially horizontal portion of the heater provides heat at a heat injection rate of at least about 1000 watts per meter.

28. The method of claim 24, wherein the selected amount of heat provided from the substantially horizontal portion of the heater creates sufficient steam injectivity between the substantially horizontal portion of the steam injection well and the substantially horizontal portion of the production well for injection of the steam from the steam injection well to move hydrocarbons to the substantially horizontal portion of the production well.

29. The method of claim 24, wherein the selected amount of heat provided from the substantially horizontal portion of the heater is reached after about one year of heating using the substantially horizontal portion of the heater.

30. The method of claim 24, wherein the substantially horizontal portion of the heater is turned off on or about the time injection of steam through the substantially horizontal portion of the steam injection well is started.

31. The method of claim 24, wherein the initial vertical matrix permeability in the hydrocarbon containing layer is at most about 300 millidarcy.

32. The method of claim 24, wherein the initial horizontal matrix permeability in the hydrocarbon containing layer is at most about 1 darcy.

33. The method of claim 24, wherein the initial viscosity of fluid in the hydrocarbon containing layer is at least about 1×

10⁶ centipoise.

34. The method of claim 24, wherein the hydrocarbon containing layer has an initial permeability that is heterogenous.

35. The method of claim 24, wherein providing heat to the hydrocarbon containing layer from the substantially horizontal portion of the heater increases steam injectivity in the layer.

36. The method of claim 24 wherein the substantially horizontal portion of the heater, the substantially horizontal portion of the steam injection well, and the substantially horizontal portion of the production well are spaced apart in the hydrocarbon containing layer.