Remotely deployed optical fiber circulator

• US 6,933,491 B2
• Filed: 12/12/2002
• Issued: 08/23/2005
• Est. Priority Date: 12/12/2002
• Status: Active Grant

• Current Assignee: Optoplan AS (Nokia Corporation)
• Original Assignee: Weatherford/Lamb Incorporated (Weatherford International PLC)
• Inventors: Maida, John L. Jr.
• Primary Examiner(s): Allen, Stephone B.
• Application Number:
  US10/317,703
• Publication Number:
  US 20040113104A1
• Time in Patent Office: 985 Days
• Field of Search: 25022714-22718, 250/227.24, 250573-574, 385/39, 385/41, 385/42, 356/317, 356/320, 600/317
• US Class Current: 250/227.14
• CPC Class Codes: E21B 47/135 using light waves, e.g. infrared or ultraviolet waves
• CPC Class Codes: G01N 21/774 the reagent being on a grating or periodic structure
• CPC Class Codes: G01N 2201/084 Fibres for remote transmission
• CPC Class Codes: G01N 33/2823 raw oil, drilling fluid or polyphasic mixtures hydrocarbon content of earth materials G01N33/241; prospecting G01V; drilling per se E21B
• CPC Class Codes: G01V 11/002 Details, e.g. power supply systems for logging instruments, transmitting or recording data, specially adapted for well logging, also if the prospecting method is irrelevant means for transmitting well survey signals E21B47/12; signal transmission systems in general G08C; transmission in general H04B
• CPC Class Codes: G02B 6/2746 comprising non-reciprocal devices, e.g. isolators, FRM, circulators, quasi-isolators magneto-optic non-reciprocal devices G02F1/093
• CPC Class Codes: H04B 10/2589 Bidirectional transmission

Abstract

Fiber-optic-based systems and methods for monitoring physical parameters using a remotely deployed circulator are disclosed. In a preferred embodiment the circulator is remotely deployed with respect to an optical source/detector and coupled thereto by two dedicated fiber optical cables: a forward line for passing light from the source through the circulator to fiber-optic-based sensors, and a return line for passing light reflected from the sensors through the circulator back to the detector. By using separate forward and return lines in conjunction with the circulator, backscattering phenomenon experienced on the forward line will not interfere with the reflected light signals coming from the sensors. The circulator, and hence the sensors, may therefore be remotely deployed from the source/detector present at a monitoring station, greatly expanding distances which optical sensing systems can span.

Claims

1. A system for monitoring at least one parameter, comprising:

an optical source coupled to at least one forward optical waveguide for transmitting incident light onto the forward optical waveguide;

an optical detector coupled to at least one return optical waveguide for receiving reflected light from the return optical waveguide;

at least one optical circulator remotely deployed from at least the optical source, wherein the forward optical waveguide and the return optical waveguide are coupled to the circulator; and

at least one fiber-optic based sensor coupled to the circulator and responsive to the parameter, wherein the sensor is deployed down a borehole within the earth, is interrogated by the incident light, and produces the reflected light.

2. The system of claim 1, wherein the circulator is also remotely deployed from the optical detector.

3. The system of claim 1, wherein the source and the detector are proximate to each other.

4. The system of claim 1, wherein the source and the detector are integrated within a component.

5. The system of claim 1, wherein the forward and return waveguides are integrated within a cable.

6. The system of claim 1, wherein the sensor comprises at least one Bragg grating.

7. The system of claim 1, wherein the at least one fiber-optic based sensor comprises a plurality of sensors which are not multiplexed and which are each coupled to the circulator.

8. The system of claim 1, wherein the at least one circulator comprises a plurality of circulators, wherein each circulator is coupled to a forward and return optical waveguide, and wherein at least one sensor is coupled to each circulator.

9. The system of claim 1, further comprising a mine, and wherein the sensor comprises a toxic gas sensor, and wherein the sensor is deployed within the mine.

10. The system of claim 1, wherein the sensor detects a seismic event.

11. The system of claim 1, wherein the circulator comprises a splitter/combiner.

12. The system of claim 1, wherein the circulator is housed in a well head.

13. The system of claim 12, wherein the well head is positioned on a sea bed.

14. The system of claim 1, wherein the borehole comprises an oil/gas well.

15. The system of claim 14, further comprising a production pipe deployed within the oil/gas well, and wherein the sensor is coupled to the production pipe.

16. The system of claim 1, further comprising a reservoir, wherein the sensor is deployed within the reservoir to monitor a change in the reservoir.

17. The system of claim 16, wherein the reservoir comprises a tank, and wherein the change comprises leakage from the tank.

18. The system of claim 16, wherein the reservoir comprises an underground storage reservoir, and wherein the change comprises leakage from the reservoir.

19. A system for monitoring at least one parameter, comprising:

an optical source coupled to at least one forward optical waveguide for transmitting incident light onto the forward optical waveguide;

an optical detector coupled to at least one return optical waveguide for receiving reflected light from the return optical waveguide;

at least one optical circulator remotely deployed from at least the optical source, wherein the forward optical waveguide and the return optical waveguide are coupled to the circulator; and

at least one fiber-optic based sensor coupled to the circulator and responsive to the parameter, wherein the at least one fiber-optic based sensor comprises a plurality of sensors multiplexed on a single optical waveguide that are interrogated by the incident light and produce the reflected light.

20. The system of claim 19, wherein the at least one sensor is deployed on the seabed to measure at least one hydrostatic pressure.

21. A method for monitoring at least one parameter, comprising:

deploying at least one sensor down a borehole in the earth;

transmitting an incident light from a optical source onto at least one first optical waveguide;

receiving the incident light from the first optical waveguide at least one node remotely deployed from the optical source;

transmitting the incident light from the node to the least one sensor;

receiving reflected light from the sensor at the node; and

transmitting the reflected light from the node to an optical detector through a second optical waveguide different from the first optical waveguide.

22. The method of claim 21, wherein the node is also remotely deployed from the optical detector.

23. The method of claim 21, wherein the source and the detector are proximate to each other.

24. The method of claim 21, wherein the source and the detector are integrated within a component.

25. The method of claim 21, wherein the first and second waveguides are integrated within a cable.

26. The method of claim 21, wherein the at least one sensor comprises a plurality of sensors multiplexed on a single optical waveguide.

27. The method of claim 21, wherein the at least one sensor comprises a plurality of sensors which are not multiplexed and which are each coupled to the node.

28. The method of claim 21, wherein the at least one node comprises a plurality of nodes, wherein each node is coupled to a first and second optical waveguide, and wherein at least one sensor is coupled to each node.

29. The method of claim 21, further comprising deploying the sensor within a mine, and wherein the reflected light is indicative of the presence of toxic gas within the mine.

30. The method of claim 21, wherein the reflected light is indicative of a seismic event.

31. The method of claim 21, wherein the node comprises an optical circulator.

32. The method of claim 21, wherein the node comprises a splitter/combiner.

33. The method of claim 21, wherein the node is housed in a well head.

34. The method of claim 33, wherein the well head is positioned on a sea bed.

35. The method of claim 21, wherein the borehole comprises an oil/gas well.

36. The method of claim 35, further comprising deploying a production pipe within the oil/gas well, and wherein the sensor is coupled to the production pipe.

37. The method of claim 21, further comprising deploying the sensor within a reservoir, wherein the reflected light is indicative of a change within the reservoir.

38. The method of claim 37, wherein the reservoir comprises a tank, and wherein the change comprises leakage from the tank.

39. The method of claim 37, wherein the reservoir comprises an underground storage reservoir, and wherein the change comprises leakage from the reservoir.

40. A method for monitoring at least one parameter, comprising:

transmitting an incident light from a optical source onto at least one first optical waveguide;

receiving the incident light from the first optical waveguide at least one node remotely deployed from the optical source;

transmitting the incident light from the node to at least one sensor, wherein the sensor comprises at least one Bragg grating;

receiving reflected light from the sensor at the node; and

transmitting the reflected light from the node to an optical detector through a second optical waveguide different from the first optical waveguide.

41. The method of claim 40, further comprising deploying the at least one sensor on the sea bed, and wherein the reflected light is indicative of hydrostatic pressure.