Downhole sensing with fiber in the formation

• US 6,978,832 B2
• Filed: 09/09/2002
• Issued: 12/27/2005
• Est. Priority Date: 09/09/2002
• Status: Expired due to Fees

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Shah, Vimal V., Rodney, Paul F., Gardner, Wallace R., Skinner, Neal G.
• Primary Examiner(s): Bagnell, David
• Assistant Examiner(s): WRIGHT, GIOVANNA COLLINS
• Application Number:
  US10/238,005
• Publication Number:
  US 20040045705A1
• Time in Patent Office: 1,205 Days
• Field of Search: 166/380, 166/250.01, 166/250.02, 166/250.16, 166/252.2, 166/113, 166/384, 166/308, 166/250.1, 166/305.1
• US Class Current: 166/250.1
• CPC Class Codes: E21B 43/26 by forming crevices or fractures
• CPC Class Codes: E21B 47/06 Measuring temperature or pressure
• CPC Class Codes: E21B 47/135 using light waves, e.g. infrared or ultraviolet waves
• CPC Class Codes: E21B 49/00 Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells

Abstract

A portion of at least one fiber is moved from a wellbore into a formation such that the portion is placed to conduct a signal responsive to at least one parameter in the formation. One particular implementation uses fiber optic cable with a process selected from the group consisting of a fracturing process, an acidizing process, and a conformance process.

Claims

1. A method of sensing at least one parameter in a formation communicating with a wellbore, comprising the step of moving a portion of at least one fiber optic cable from the wellbore into the formation by flowing a fluid into the formation, and carrying by the flowing fluid the portion of at least one fiber optic cable into the formation such that the portion is placed to conduct an optical signal responsive to the at least one parameter in the formation.

2. The method as defined in claim 1, wherein the step of flowing the fluid into the formation includes the steps of:

creating a fracture in the formation with the fluid; and

transporting proppant into the fracture as part of the fluid.

3. The method as defined in claim 2, wherein the at least one fiber optic cable has an outer diameter smaller than an outer diameter of whole particles of the proppant.

4. The method as defined in claim 1, wherein the step of carrying the portion of at least one fiber optic cable includes the step of pulling fiber optic cable from a spool thereof by using the force of the flowing fluid engaging the at least one fiber optic cable.

5. The method as defined in claim 4, wherein the spool of fiber optic cable is disposed in the wellbore.

6. The method as defined in claim 4, wherein the spool of fiber optic cable is outside the wellbore.

7. The method as defined in claim 1, wherein the step of flowing a fluid into the formation comprises:

flowing a fluid into a fracture in the formation; and

carrying by the flowing fluid the portion of at least one fiber optic cable into the fracture.

8. The method as defined in claim 1, wherein the step of moving the portion of at least one fiber optic cable includes the steps of:

moving a carrier conduit into the formation; and

carrying the portion of at least one fiber optic cable into the formation in the carrier conduit.

9. The method as defined in claim 1, wherein the at least one fiber optic cable includes at least one sensor to measure at least one of a physical characteristic, chemical composition, material property, or disposition of the formation.

10. A method of sensing at least one parameter in a formation intersected by a wellbore, comprising the steps of:

moving a fiber optic sensor from the wellbore into the formation outside the wellbore;

conducting light to the fiber optic sensor from a light source; and

receiving an optical signal from the fiber optic sensor in response to the conducted light and at least one parameter in the formation.

11. The method as defined in claim 10, wherein the step of moving the fiber optic sensor includes the step of pumping a fluid into the wellbore, wherein the fluid is selected from the group consisting of a fracturing fluid, an acidizing fluid, and a conformance fluid.

12. The method as defined in claim 10, wherein the step of moving the fiber optic sensor includes the steps of:

moving a carrier conduit into the formation; and

carrying the fiber optic sensor into the formation in the carrier conduit.

13. The method as defined in claim 10, wherein the light source is disposed in the wellbore.

14. The method as defined in claim 10, wherein the light source is disposed outside the wellbore.

15. The method as defined in claim 10, wherein the optical signal is received in the wellbore.

16. The method as defined in claim 10, wherein the optical signal is received outside the wellbore.

17. The method as defined in claim 10, wherein the fiber optic sensor is hydraulically moved through a perforation in a casing or lining disposed in the wellbore.

18. The method as defined in claim 10, wherein the fiber optic sensor is hydraulically moved into a fracture formed in the formation.

19. The method as defined in claim 10, wherein the fiber optic sensor is carried in a carrier conduit that is moved through a perforation in a casing or lining disposed in the wellbore.

20. The method as defined in claim 10, wherein the fiber optic sensor is carried in a carrier conduit that is moved into a fracture formed in the formation.

21. The method as defined in claim 10, wherein the step of moving the fiber optic sensor includes the step of transporting proppant into the formation with the fiber optic sensor, wherein the fiber optic sensor has an outer diameter smaller than an outer diameter of whole particles of the proppant.

22. The method as defined in claim 10, wherein the step of moving the fiber optic sensor includes the step of pulling fiber optic cable from a spool thereof by using the force of flowing fluid engaging the fiber optic cable.

23. The method as defined in claim 22, wherein the spool of fiber optic cable is disposed in the wellbore.

24. The method as defined in claim 22, wherein the spool of fiber optic cable is outside the wellbore.

25. The method as defined in claim 10, wherein the step of moving the fiber optic sensor includes the steps of:

fracturing the formation with a fluid under pressure; and

moving the fiber optic sensor with the fluid.

26. The method as defined in claim 10, wherein the step of moving the fiber optic sensor includes the step of pumping a fluid such that the fluid fractures the formation and the fluid engages and pulls the fiber optic sensor.

27. A method of treating a well, comprising the step of:

using, during a treatment time period, a process selected from the group consisting of a fracturing process, an acidizing process, and a conformance process;

moving a fiber optic sensor into a formation undergoing the treatment; and

sensing with the fiber optic sensor at least one parameter of the formation.

28. The method as defined in claim 27, further comprising the step of leaving the fiber optic sensor in the formation after the treatment time period to degrade such that the fiber optic sensor has a useful life only during the treatment time period.

29. The method as defined in claim 27, wherein the step of moving the fiber optic sensor includes pumping the fiber optic sensor with a fluid used in the process.

30. The method as defined in claim 27, wherein the step of moving the fiber optic sensor includes the step of transporting the fiber optic sensor within a carrier conduit that is moved into the formation with the fiber optic sensor.

31. A method of sensing at least one parameter in a formation communicating with a wellbore, comprising the step of moving a portion of at least one conductive fiber from the wellbore into the formation by flowing a fluid into the formation, and carrying by the flowing fluid the portion of at least one conductive fiber into the formation such that the portion is placed to conduct a signal responsive to the at least one parameter in the formation.

32. The method as defined in claim 31, wherein the step of flowing a fluid into the formation includes the steps of:

creating a fracture in the formation with the fluid; and

transporting proppant into the fracture as part of the fluid.

33. The method as defined in claim 32, wherein the at least one conductive fiber has an outer diameter smaller than an outer diameter of whole particles of the proppant.

34. The method as defined in claim 31, wherein the step of carrying the portion of at least one conductive fiber includes the step of pulling fiber optic cable from a spool thereof by using the force of the flowing fluid engaging the fiber optic cable.

35. The method as defined in claim 34, wherein the spool of fiber optic cable is disposed in the wellbore.

36. The method as defined in claim 34, wherein the spool of fiber optic cable is outside the wellbore.

37. The method as defined in claim 31, wherein the step of flowing a fluid into the formation comprises:

flowing a fluid into a fracture in the formation; and

carrying by the flowing fluid the portion of at least one conductive fiber into the fracture.

38. The method as defined in claim 31, wherein the step of moving the portion of at least one conductive fiber includes the steps of:

moving a carrier conduit into the formation; and

carrying the portion of at least one conductive fiber into the formation in the carrier conduit.

39. The method as defined in claim 31, wherein the at least one conductive fiber includes at least one sensor to measure at least one of a physical characteristic, chemical composition, material property, or disposition of the formation.

40. The method as defined in claim 31, wherein the at least one conductive fiber includes an optical fiber.

41. The method as defined in claim 31, wherein the at least one conductive fiber includes an electrical conductor.

42. The method as defined in claim 31, wherein the at least one conductive fiber includes conductive carbon nanotubes.

43. The method as defined in claim 31, wherein the at least one conductive fiber includes an acoustical conductor.