Single packer system for use in heavy oil environments

• US 8,439,110 B2
• Filed: 07/25/2011
• Issued: 05/14/2013
• Est. Priority Date: 01/23/2008
• Status: Active Grant

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Corre, Pierre-Yves, Yeldell, Stephen, Sonne, Carsten, Goodwin, Anthony Robert Holmes, Briquet, Stephane, Zazovsky, Alexander F.
• Primary Examiner(s): HUTCHINS, CATHLEEN R
• Application Number:
  US13/190,340
• Publication Number:
  US 20110277999A1
• Time in Patent Office: 659 Days
• Field of Search: 166/264, 166/188, 166/250.17, 166/60, 166/61, 166/57, 731/522.6
• US Class Current: 166/250.17
• CPC Class Codes: E21B 33/127 with inflatable sleeve E21B33/122, E21B33/124 take precedence
• CPC Class Codes: E21B 36/006 Combined heating and pumping means
• CPC Class Codes: E21B 36/04 using electrical heaters
• CPC Class Codes: E21B 49/08 Obtaining fluid samples or testing fluids, in boreholes or wells
• CPC Class Codes: E21B 49/10 using side-wall fluid samplers or testers

Abstract

A technique involves collecting formation fluids through a single packer having at least one drain located within the single packer. The single packer comprises an outer seal layer, and the at least one drain is positioned in the outer seal layer. A viscosity system also is incorporated and enables the viscosity of a surrounding fluid to be selectively lowered for sampling.

Claims

1. A system for use in a wellbore comprising:

a single packer having;

an outer structural layer expandable in a wellbore across an expansion zone, the outer structural layer comprising at least one drain within the expansion zone;

an inflatable bladder disposed within the outer structural layer;

a fluid injection system to inject a substance into the expansion zone via the least one drain to lower the viscosity of a fluid being sampled.

2. The system as recited in claim 1, wherein the substance comprises a diluting agent, and further wherein the fluid is formation fluid.

3. The system as recited in claim 1, wherein the substance is steam.

4. The system as recited in claim 1, wherein the outer structural layer comprises at least two drains and further wherein the fluid injection system injects the substance into the at least two drains.

5. The system as recited in claim 1, wherein the fluid injection system comprises an electrical resistor to heat the substance.

6. The system as recited in claim 5, wherein the electrical resistor is positioned within a flowline connected to the at least one drain.

7. The system as recited in claim 1, wherein the fluid injection system comprises an exothermic chemical reaction to heat the substance.

8. The system as recited in claim 7, wherein the exothermic chemical reaction occurs by mixing the substance and at least one chemical in a flowline connected to the at least one drain.

9. The system as recited in claim 7, wherein the outer structural layer comprises at least two drains, and further wherein the exothermic chemical reaction occurs at a location between the at least two drains.

10. A method, comprising:

deploying a single packer into a wellbore, the single packer having a first drain for receiving formation fluid;

expanding the single packer against a wall of the wellbore to create a seal to substantially prevent fluid communication between an area above the single packer and an area below the single packer; and

injecting a substance through the first drain or a second drain to lower a viscosity of formation fluid about the wellbore.

11. The method as recited in claim 10, further comprising positioning an inflatable bladder within an outer structural layer to enable selective expansion of the single packer.

12. The method as recited in claim 10 wherein the substance is a diluting agent, water or steam.

13. The method as recited in claim 10 further comprising heating the substance prior to injecting the substance through the first drain or the second drain.

14. The method as recited in claim 10 wherein the first drain and the second drain are formed in an outer layer of the single packer and each connected to a respective flowline and further wherein the first drain and the second drain receive formation fluid.

15. The method as recited in claim 10 further comprising detecting a property of the formation fluid with a sensor positioned in the first drain or the second drain.

16. A method, comprising:

providing a single expandable packer with a drain in an outer seal layer;

delivering the single expandable packer downhole into a wellbore;

expanding the single expandable packer against a surrounding wellbore wall;

lowering the viscosity of a fluid to be sampled by injecting a substance into the wellbore; and

intaking the fluid through the drain.

17. The method as recited in claim 16, wherein lowering comprises delivering the substance through the drain to dilute an oil in a formation adjacent to the drain.

18. The method as recited in claim 16, wherein lowering comprises delivering the substance through the drain to heat an oil in a formation adjacent to the drain.

19. The method of claim 16 wherein the substance is injected through the drain that intakes the fluid.

20. The system as recited in claim 16 further comprising heating the substance prior to injecting the substance into the wellbore.