Use of fiber optics in deviated flows

• US 6,997,256 B2
• Filed: 12/17/2002
• Issued: 02/14/2006
• Est. Priority Date: 12/17/2002
• Status: Expired due to Fees

• Current Assignee: Sensor Highway Limited (SLB)
• Original Assignee: Sensor Highway Limited (SLB)
• Inventors: Forbes, Kevin J, Brown, George A, Williams, Glynn R, Hartog, Arthur H, Koeniger, Christian
• Primary Examiner(s): Bagnell, David
• Assistant Examiner(s): Stephenson, Daniel P.
• Application Number:
  US10/321,216
• Publication Number:
  US 20040112596A1
• Time in Patent Office: 1,155 Days
• Field of Search: 166/250.02, 166/250.03, 166/66, 385/12, 732/041.1, 732/042.2, 731/521.8, 731/523.3, 732/042.3, 356/43, 250/269.1, 374/136, 374/137
• US Class Current: 166/250.03
• CPC Class Codes: E21B 47/07 Temperature
• CPC Class Codes: E21B 47/09 Locating or determining the position of objects in boreholes or wells , e.g. the position of an extending arm; Identifying the free or blocked portions of pipes
• CPC Class Codes: E21B 47/103 using thermal measurements
• CPC Class Codes: E21B 47/135 using light waves, e.g. infrared or ultraviolet waves

Abstract

A system to determine the mixture of fluids in the deviated section of a wellbore comprising at least one distributed temperature sensor adapted to measure the temperature profile along at least two levels of a vertical axis of the deviated section. Each distributed temperature sensor can be a fiber optic line functionally connected to a light source that may utilize optical time domain reflectometry to measure the temperature profile along the length of the fiber line. The temperature profiles at different positions along the vertical axis of the deviated wellbore enables the determination of the cross-sectional distribution of fluids flowing along the deviated section. Together with the fluid velocity of each of the fluids flowing along the deviated section, the cross-sectional fluid distribution enables the calculation of the flow rates of each of the fluids. The system may also be used in conjunction with a pipeline, such as a subsea pipeline, to determine the flow rates of fluids flowing therethrough.

Claims

1. A method for determining the cross-sectional distribution of fluids along a deviated wellbore, comprising:

measuring a temperature profile along at least two levels of a vertical axis of a deviated section of a wellbore using at least one fiber optic line;

deploying a heating element along the at least one fiber optic line;

identifying the orientation of the at least one fiber optic line by activating the heating element; and

comparing the temperature profiles to determine whether different fluids are present in each of the levels.

2. The method of claim 1, wherein the measuring step comprises measuring a temperature profile proximate a top area of the deviated section using a first fiber optic line and measuring a temperature profile proximate a bottom area of the deviated section using a second fiber optic line.

3. The method of claim 2, further comprising measuring at least one temperature profile intermediate the top area and the bottom area by using at least one additional fiber optic line and wherein the comparing step comprises comparing each of the temperature profiles to determine whether different fluids are present along a vertical axis of the deviated section.

4. The method of claim 2, wherein the at least one fiber optic line has a U-shape and extends from a surface towards the deviated section and at least partially back towards the surface.

5. The method of claim 2, further comprising:

deploying the first and second fiber optic lines on a conveyance device; and

orienting the conveyance device so that the first fiber optic line is proximate the top area and the second fiber optic line is proximate the bottom area.

6. The method of claim 1, wherein each of the measuring steps comprises launching a pulse of optical energy into the at least one fiber optic line and measuring at least one temperature sensitive spectrum of the backscattered light from the at least one fiber optic line.

7. The method of claim 1, further comprising coiling at least a portion of the at least one fiber optic line around a conveyance device used for deployment into the wellbore.

8. The method of claim 1, further comprising providing at least one conduit to house the at least one fiber optic line.

9. The method of claim 8, further comprising pumping the at least one fiber optic line into the at least one conduit by use of fluid drag.

10. The method of claim 8, further comprising attaching the at least one conduit to a conveyance device used for deployment.

11. The method of claim 1, further comprising deploying the at least one fiber optic line on a conveyance device, wherein the conveyance device is one of a production tubing or a coiled tubing.

12. The method of claim 1, further comprising determining the presence of hold up based on the comparing step.

13. A system for determining the cross-sectional distribution of fluids along a deviated wellbore, comprising:

at least one fiber optic line adapted to measure a temperature profile along at least two levels of a vertical axis of a deviated section of a wellbore; and

a heating element adapted to be deployed into the deviated section wherein the activation of the heating element enables the identification of the orientation of the at least one fiber optic line.

14. The system of claim 13, comprising:

a first fiber optic line proximate a top area of a deviated section of a wellbore adapted to measure a temperature profile; and

a second fiber optic line proximate a bottom area of a deviated section of a wellbore adapted to measure a temperature profile.

15. The system of claim 14, further comprising at least one additional fiber optic line intermediate the top area and the bottom area and adapted to measure a temperature profile.

16. The system of claim 14, further comprising:

a conveyance device connected to the first and second fiber optic lines; and

an orienting device dapted to orient the fiber optic lines so that the first fiber optic line is proximate the top area and the second fiber optic line is proximate the bottom area.

17. The system of claim 13, wherein the temperature profile is derived by launching a pulse of optical energy into the at least one fiber optic line and measuring at least one temperature sensitive spectrum of the backscattered light from the at least one fiber optic line.

18. The system of claim 13, wherein the at least one fiber optic line has a U-shape and extends from a surface towards the deviated section and at least partially back towards the surface.

19. The system of claim 13, wherein at least a portion of the at least one fiber optic line is coiled around a conveyance device used for deployment into the wellbore.

20. The system of claim 13, further comprising at least one conduit housing the at least one fiber optic line.

21. The system of claim 20, wherein the at least one conduit is attached to a conveyance device used for deployment into the wellbore.

22. The system of claim 21, wherein the at least one conduit is proximate a wellbore wall when deployed within the wellbore.

23. The system of claim 13, wherein the at least one fiber optic line is pumped by fluid drag through the at least one conduit.

24. The system of claim 13, further comprising:

a conveyance device associated with the at least one fiber optic line;

the conveyance device including at least one high resolution section; and

the at least one high resolution section including the at least one fiber optic line in a configuration that provides a temperature profile in the at least two levels of the vertical axis.

25. The system of claim 24, wherein the at least one fiber optic line is coiled around the conveyance device.

26. The system of claim 24, wherein the at least one fiber optic line is axially looped at least twice along the length of the at least one high resolution section.

27. The system of claim 26, wherein the axial loops extend around the circumference of the conveyance device.

28. The system of claim 24, further comprising at least one low resolution section including the at least one fiber optic line in a configuration that provides a lesser number of temperature profiles than the at least one high resolution section.

29. The system of claim 28, wherein the at least one low resolution section and the at least one high resolution section are modular.

30. The system of claim 28, wherein the at least one low resolution section and the at least one high resolution section can be removably attached to a low resolution section or a high resolution section.

31. The system of claim 13, further comprising a conveyance device connected to the at least one fiber optic line.

32. The system of claim 31, wherein the conveyance device comprises one of a production tubing or a coiled tubing.

33. The system of claim 13, wherein the at least one fiber optic line is deployed across a hold up in the deviated section.

34. A system for determining the cross-sectional distribution of fluids along a deviated wellbore, comprising:

at least one fiber optic line adapted to measure a temperature profile along at least two levels of a vertical axis of a deviated section of a wellbore;

at least one conduit housing the at least one fiber optic line, the at least one conduit attached to a conveyance device used for deployment into the wellbore;

a plurality of additional fiber optic lines intermediate the top area and the bottom area and adapted to measure a temperature profile, each of the additional fiber optic lines being housed in at least one conduit attached to the conveyance device.

35. A method for identifying the azimuthal location of a thermal event in a subterranean wellbore, comprising:

measuring a temperature profile along a portion of a wellbore using at least one fiber optic line;

establishing the azimuthal location of the at least one fiber optic line by deploying a heating element along the at least one fiber optic line and activating the heating element; and

determining an azimuthal location of a thermal event by analyzing the temperature profile.

36. The method of claim 35, wherein:

the measuring step comprises measuring a temperature profile along at least two positions of a cross-section of the wellbore; and

the determining step comprises determining the azimuthal location of the thermal event by comparing the temperature profiles.

37. The method of claim 36, further comprising deploying at least two fiber optic lines, each fiber optic line associated with one of the temperature profiles.

38. The method of claim 35, wherein the thermal event comprises an inflow into the wellbore.

39. The method of claim 35, wherein the thermal event comprises a leak out of the wellbore.

40. The method of claim 35, wherein the thermal event comprises a temperature difference in fluids flowing in the wellbore.