In situ heat treatment of a tar sands formation after drive process treatment

• US 7,798,220 B2
• Filed: 04/18/2008
• Issued: 09/21/2010
• Est. Priority Date: 04/20/2007
• Status: Expired due to Fees

• Current Assignee: Shell Oil Company (Shell Plc)
• Original Assignee: Shell Oil Company (Shell Plc)
• Inventors: Stanecki, John, Vinegar, Harold J.
• Primary Examiner(s): SUCHFIELD, GEORGE A
• Application Number:
  US12/106,035
• Publication Number:
  US 20090095480A1
• Time in Patent Office: 886 Days
• Field of Search: 166/245, 166/272.1, 166/272.3, 166/263, 166/402, 166/403
• US Class Current: 166/272.3
• CPC Class Codes: C09K 8/845 containing inorganic compounds
• CPC Class Codes: C09K 8/86 containing organic compounds
• CPC Class Codes: C10G 1/008 Controlling or regulating of liquefaction processes
• CPC Class Codes: C10G 1/02 by distillation
• CPC Class Codes: C10G 1/04 by extraction
• CPC Class Codes: C10G 1/042 by the use of hydrogen-donor solvents
• CPC Class Codes: E21B 36/04 using electrical heaters
• CPC Class Codes: E21B 43/16 Enhanced recovery methods for obtaining hydrocarbons
• CPC Class Codes: E21B 43/24 using heat, e.g. steam injection
• CPC Class Codes: E21B 43/2401 by means of electricity
• CPC Class Codes: Y10T 29/49083 Heater type

Abstract

A method for treating a tar sands formation includes providing a drive fluid to a hydrocarbon containing layer of the tar sands formation to mobilize at least some hydrocarbons in the layer. At least some first hydrocarbons from the layer are produced. Heat is provided to the layer from one or more heaters located in the formation. At least some second hydrocarbons are produced from the layer of the formation. The second hydrocarbons include at least some hydrocarbons that are upgraded compared to the first hydrocarbons produced by using the drive fluid.

Claims

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

providing a drive fluid to a hydrocarbon containing layer of the tar sands formation to mobilize at least some hydrocarbons in the layer;

producing at least some first hydrocarbons from the layer;

providing heat to the layer from one or more heaters located in a first portion and a second portion of the layer, wherein the first portion has a substantially different hydrocarbon recovery than the second portion after producing the first hydrocarbons using the drive fluid; and

producing at least some second hydrocarbons from the layer of the formation, the second hydrocarbons comprising at least some hydrocarbons that are upgraded compared to the first hydrocarbons produced by using the drive fluid.

2. The method of claim 1, wherein the drive fluid is steam.

3. The method of claim 1, wherein at most about 20% of the hydrocarbons in place are produced from the formation as first hydrocarbons using the provided drive fluid.

4. The method of claim 1, wherein at least about 25% of the hydrocarbons in place are produced after providing heat to the layer from the one or more heaters.

5. The method of claim 1, further comprising heating the layer to a temperature between about 150°

C. and about 270°

C. using the drive fluid.

6. The method of claim 1, wherein the heaters used to provide heat are placed in at least one of the portions of the layer after the production of the first hydrocarbons using the drive fluid is at least 50% complete.

7. The method of claim 1, further comprising activating the heaters after the production of hydrocarbons using the drive fluid is at least 50% complete.

8. The method of claim 1, wherein the drive fluid is not uniformly provided throughout the layer.

9. The method of claim 1, further comprising continuing to provide the drive fluid while providing heat to the layer from the one or more heaters.

10. The method of claim 1, wherein the first portion has a recovery of at most about 10% of the hydrocarbons in place and the second portion has a recovery of at least about 30% of the hydrocarbons in place.

11. The method of claim 10, further comprising providing more heat to the portion with the lower recovery than to the portion with the higher recovery.

12. The method of claim 1, wherein the layer is left dormant for at least about 1 year after production of the first hydrocarbons using the drive fluid and before heat is provided from the one or more heaters.

13. The method of claim 1, further comprising installing at least one of the heaters in a wellbore that has previously been used to provide the drive fluid into the layer.

14. The method of claim 1, further comprising heating the layer to a first average temperature using the drive fluid, and then heating the layer to a second average temperature using the one or more heaters, wherein the second average temperature is higher than the first average temperature.

15. The method of claim 14, wherein the second average temperature is at least about 250°

C.

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

providing heat to a hydrocarbon containing layer in the tar sands formation from one or more heaters located in the formation, wherein the hydrocarbon containing layer has been previously treated using a steam injection and production process;

producing at least some hydrocarbons from the layer of the formation, the produced hydrocarbons comprising at least some hydrocarbons that are upgraded compared to hydrocarbons produced by the steam injection and production process; and

resuming the steam injection and production process while providing heat to the formation from the one or more heaters.

17. The method of claim 16, wherein at most about 20% of the hydrocarbons in place are produced from the formation using the steam injection and production process.

18. The method of claim 16, wherein at least about 25% of the hydrocarbons in place are produced after providing heat to the formation.

19. The method of claim 16, further comprising heating the layer to a temperature between about 150°

C. and about 270°

C. using the steam injection and production process.

20. The method of claim 16, wherein the heaters used to provide heat are placed in the formation after the steam injection and production process is at least 50% complete.

21. The method of claim 16, further comprising energizing the heaters after the steam injection and production process is at least 50% complete.

22. The method of claim 16, wherein hydrocarbons in the layer are not uniformly removed using the steam injection and production process.

23. The method of claim 16, wherein the layer comprises at least two portions with different recoveries after the steam injection and production process.

24. The method of claim 23, wherein at least one of the portions has a recovery of at most about 10% of the hydrocarbons in place and at least a second one of the portions has a recovery of at least about 30% of the hydrocarbons in place.

25. The method of claim 24, further comprising providing more heat to the portion with the lower recovery than the portion with the higher recovery.

26. The method of claim 16, wherein the layer is left dormant for at least about 1 year after the steam injection and production process and before heat is provided from the one or more heaters.

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

providing a drive fluid to a hydrocarbon containing layer of the tar sands formation to mobilize at least some hydrocarbons in the layer;

producing at least some first hydrocarbons from the layer;

providing heat to the layer from one or more heaters located in the formation, wherein at least one of the heaters comprises a temperature limited heater; and

producing at least some second hydrocarbons from the layer of the formation, the second hydrocarbons comprising at least some hydrocarbons that are upgraded compared to the first hydrocarbons produced by using the drive fluid.

28. The method of claim 27, wherein at least about 25% of the hydrocarbons in place are produced after providing heat to the layer from the one or more heaters.