Creating fluid injectivity in tar sands formations

• US 8,191,630 B2
• Filed: 04/28/2010
• Issued: 06/05/2012
• Est. Priority Date: 10/20/2006
• Status: Expired due to Fees

• Current Assignee: Shell Oil Company (Shell Plc)
• Original Assignee: Shell Oil Company (Shell Plc)
• Inventors: Stegemeier, George Leo, Beer, Gary Lee, Zhang, Etuan
• Primary Examiner(s): Suchfield, George
• Application Number:
  US12/769,379
• Publication Number:
  US 20100276141A1
• Time in Patent Office: 769 Days
• Field of Search: None
• US Class Current: 166/272.3
• CPC Class Codes: C10G 1/02 by distillation
• CPC Class Codes: C10G 2300/4037 In-situ processes
• CPC Class Codes: E21B 36/04 using electrical heaters
• CPC Class Codes: E21B 43/243 Combustion in situ
• CPC Class Codes: E21B 43/30 Specific pattern of wells, e.g. optimising the spacing of wells
• CPC Class Codes: E21B 47/0228 using electromagnetic energy or detectors therefor

Abstract

Methods for treating a tar sands formation are described herein. Methods for treating a tar sands may include heating a portion of a hydrocarbon layer in the formation from one or more heaters located in the portion. The heat may be controlled to increase the permeability of at least part of the portion to create an injection zone in the portion with an average permeability sufficient to allow injection of a fluid through the injection zone. A drive fluid and/or an oxidizing fluid may be provided into the injection zone. At least some hydrocarbons including mobilized hydrocarbons are produced from the portion.

Claims

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

heating a portion of a hydrocarbon layer in the formation from one or more heaters located in the portion;

controlling the heating to increase the permeability of at least part of the portion to create an injection zone in the portion with an average permeability sufficient to allow injection of a fluid through the injection zone;

controlling the pressure in the portion such that the pressure is below the fracture pressure of the portion;

providing a drive fluid and/or an oxidizing fluid into the injection zone;

controlling the temperature in the portion such that at least a majority of the hydrocarbons in the portion are mobilized; and

producing a fluid comprising at least some of the mobilized hydrocarbons through a production well.

2. The method of claim 1, wherein the drive fluid and/or the oxidizing fluid moves from the injection zone to mobilize at least some hydrocarbons in the portion.

3. The method of claim 1, further comprising providing at least some heat to the portion using the drive fluid and/or the oxidizing fluid.

4. The method of claim 1, further comprising providing at least some heat outside the injection zone with the drive fluid and/or the oxidizing fluid.

5. The method of claim 1, further comprising increasing the permeability of at least part of the portion outside the injection zone with the drive fluid and/or the oxidizing fluid.

6. The method of claim 1, wherein at least some of the heaters are turned down and/or off after increasing the permeability in the injection zone.

7. The method of claim 1, wherein the drive fluid and/or the oxidizing fluid is selected from a group consisting of steam, water, carbon dioxide, carbon monoxide, methane, pyrolyzed hydrocarbons, air, and mixtures thereof.

8. The method of claim 1, wherein the injection zone has little or no initial injectivity.

9. The method of claim 1, wherein increasing the permeability of the injection zone creates a fluid production network between at least one of the heaters and a production well in the injection zone.

10. The method of claim 1, further comprising providing the drive fluid and/or the oxidizing fluid to a part of the injection zone behind a heat front generated by the heaters.

11. The method of claim 10, further comprising producing hydrocarbons from the part behind the heat front.

12. The method of claim 1, further comprising controlling the heating so that the injection zone has a substantially uniform porosity and/or a substantially uniform injectivity.

13. The method of claim 1, wherein the drive fluid and/or the oxidizing fluid is provided from a well having a well length adapted to emit the drive fluid and/or the oxidizing fluid from the well to the injection zone, wherein the provided heat increases injectivity from the well from at most about 10 kg/m/day of drive fluid and/or oxidizing fluid to at least about 100 kg/m/day of drive fluid and/or oxidizing fluid, and wherein injectivity is the mass of drive fluid and/or oxidizing fluid that can be injected per unit well length that is adapted to emit the drive fluid and/or oxidizing fluid from the well, per day.

14. The method of claim 1, wherein the provided heat decreases a viscosity of liquid hydrocarbons in the injection zone to less than about 500 cp for a distance of about 2 m from at least one of the heaters, and wherein the viscosity is measured at 1 atm and 5°

C.

15. The method of claim 1, wherein the provided heat decreases a viscosity of liquid hydrocarbons in the injection zone with an initial viscosity of above about 10000 cp, wherein the viscosity is measured at 1 atm and 5°

C.

16. The method of claim 1, further comprising:

allowing at least some of the hydrocarbons to flow into a second portion of the formation;

providing heat to the second portion of the formation from one or more heaters located in the formation before and/or after allowing at least some of the hydrocarbons to flow into the second portion; and

producing at least some hydrocarbons through an additional production well located in the second portion of the formation.

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

heating a portion of a hydrocarbon layer in the formation from one or more heaters located in the portion;

controlling the heating to increase the permeability of at least part of the portion to create an injection zone in the portion with an average permeability sufficient to allow injection of a fluid through the injection zone;

controlling the pressure in the portion such that the pressure is below the fracture pressure of the portion;

providing a drive fluid into the injection zone;

controlling the temperature in the formation such that a majority of the hydrocarbons are mobilized by the drive fluid; and

producing a fluid comprising mobilized hydrocarbons through a production well.

18. The method of claim 17, further comprising providing at least some heat outside the injection zone with the drive fluid.

19. The method of claim 17, wherein at least some of the heaters are turned down and/or off after increasing the permeability in the injection zone.

20. The method of claim 17, further comprising providing the drive fluid to a part of the injection zone behind a heat front generated by the heaters.

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

heating a portion of a hydrocarbon layer in the formation from one or more heaters located in the portion;

controlling the heating to increase the permeability of at least part of the portion to create an injection zone in the portion with an average permeability sufficient to allow injection of a fluid through the injection zone;

controlling the pressure in the portion such that the pressure is below the fracture pressure of the portion;

providing an oxidizing fluid into the injection zone to oxidize at least some hydrocarbons in the injection zone;

controlling the temperature in the formation such that a majority of the hydrocarbons in the formation are mobilized by heat produced by the oxidation of hydrocarbons in the injection zone; and

producing a fluid comprising mobilized hydrocarbons through a production well.

22. The method of claim 21, further comprising providing at least some heat outside the injection zone with heat produced by the oxidation of hydrocarbons in the injection zone.

23. The method of claim 21, further comprising providing the oxidizing fluid to a part of the injection zone behind a heat front generated by the heaters.