Systems and methods for distributed interferometric acoustic monitoring

• US 7,946,341 B2
• Filed: 11/02/2007
• Issued: 05/24/2011
• Est. Priority Date: 11/02/2007
• Status: Active Grant

• Current Assignee: Schlumberger Technology Corporation (SLB)
• Original Assignee: Schlumberger Technology Corporation (SLB)
• Inventors: Brown, J. Ernest, Johnson, Ashley Bernard, Hammond, Paul S., Cook, John Mervyn, Elphick, Jonathan, Hartog, Arthur H.
• Primary Examiner(s): Stephenson; Daniel P
• Assistant Examiner(s): Ro; Yong-Suk
• Application Number:
  US11/934,551
• Publication Number:
  US 20090114386A1
• Time in Patent Office: 1,299 Days
• Field of Search: 166/250.01, 166/250.11, 166/66, 367/25
• US Class Current: 166/254.1
• CPC Class Codes: E21B 41/0064 Carbon dioxide sequestration storing fluids in porous layers B65G5/005
• 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: G01V 1/226 Optoseismic systems
• CPC Class Codes: G01V 8/02 Prospecting
• CPC Class Codes: G01V 8/16 using optical fibres
• CPC Class Codes: Y02C 20/40 of CO2

Abstract

Acoustic monitoring of a conduit, a wellbore or a reservoir associated with hydrocarbon production or transportation and/or carbon dioxide sequestration is carried out using a fibre optic cable extending along or appurtenant to it as a distributed interferometer. Coherent Raleigh noise generated by the transmission of the coherent beam of radiation through the fiber optic is detected and processed to identify an acoustic occurrence.

Claims

1. A method for monitoring a wellbore, a reservoir or a pipeline for occurrences which generate acoustic perturbations therein, comprising:

transmitting a monitoring signal through a fiber optic cable, wherein the monitoring signal comprises a pulse of a coherent beam of electromagnetic radiation and a coherence time of the coherent beam of electromagnetic radiation is equal to or longer than a duration of the pulse, and wherein the fiber optic cable is disposed along or is disposed appurtenant to at least a section of the wellbore, the reservoir or the pipeline;

detecting coherent Rayleigh noise generated by the transmission of the coherent beam of radiation through the fiber optic; and

processing the detected coherent Rayleigh noise to identify a said acoustic occurrence in the section of the wellbore, the reservoir or the pipeline.

2. The method of claim 1, further comprising:

using a time-of-flight of the pulse to identify a location of the acoustic occurrence in the section of the wellbore, the reservoir or the pipeline.

3. The method of claim 1, wherein the step of processing the detected coherent Rayleigh noise to identify an acoustic occurrence comprises comparing the detected coherent Rayleigh noise to an acoustic signature of the acoustic occurrence.

4. The method of claim 3, wherein the acoustic signature is determined by at least one of theoretical analysis, modeling, experimentation and previous acoustic monitoring analysis.

5. The method of claim 3, wherein the reference comprises the coherent Rayleigh noise generated by transmission of one of the pulses of the coherent beam of electromagnetic radiation under baseline conditions.

6. The method of claim 1, wherein:

the step of transmitting a monitoring signal through the fiber optic cable comprises repeatedly transmitting the pulse of the coherent beam of electromagnetic radiation through the fiber optic cable;

the step of detecting coherent Rayleigh noise comprises detecting the coherent Rayleigh noise generated by each of the transmitted pulses; and

the step of processing the detected coherent Rayleigh noise to identify the acoustic occurrence comprises comparing the coherent Rayleigh noise generated by one of the repeated pulses with a previous pulse or a reference.

7. The method of claim 1, further comprising:

disposing one or more acoustic transducers along the fiber optic cable.

8. The method of claim 1, further comprising:

monitoring temperatures at one or more locations in the wellbore, the reservoir or the pipeline.

9. The method of claim 1, further comprising:

monitoring temperature at locations distributed along a section of wellbore or pipeline and identifying a leak in the wellbore or the pipeline by determining an occurrence of an acoustic anomaly and a temperature anomaly at a same location in the pipeline or the wellbore.

10. The method of claim 1, further comprising:

measuring a frequency of an acoustic output generated by fluid flow and using the measured frequency to determine a velocity of the fluid flow.

11. The method of claim 10, further comprising:

using a time of flight measurement to determine a fluid flow rate of the fluid flow in the pipe or wellbore.

20. The method of claim 1 wherein the occurrences which generate acoustic noise are impacts by sand grains.

12. A system for monitoring a wellbore or a pipeline for events which generate acoustic perturbations therein, comprising:

a fiber optic coupled with or disposed adjacent to a section of the wellbore or the pipeline;

a source of coherent electromagnetic radiation coupled with the fiber optic and configured to inject a pulse of the coherent electromagnetic radiation into the fiber optic, wherein the source of coherent electromagnetic radiation is configured to produce a coherent electromagnetic beam with a coherence time that is equal to or greater than a duration of the pulse;

a detector coupled with the fiber optic and configured to detect coherent Rayleigh noise generated in the fiber optic by the pulse of coherent electromagnetic radiation; and

a processor coupled with the detector and configured to process an output from the detector corresponding to detected coherent Rayleigh noise to identify said acoustic events in the wellbore or pipeline.

13. The system of claim 12, wherein the source of coherent electromagnetic radiation is a laser.

14. The system of claim 12, wherein the fiber optic has a non-reflecting end.

15. The system of claim 12, wherein said detector comprises a photo-detector.

16. The system of claim 12, wherein the detector comprises a signal analyzer.

17. The system of claim 12, further comprising:

one or more acoustic transducers coupled with the fiber optic.

18. The system of claim 12, further comprising:

a distributed temperature measuring system disposed along the wellbore or the pipeline.

19. A method for monitoring a wellbore, a reservoir or a pipeline for occurrences which generate acoustic perturbations therein, comprising:

providing a fiber optic cable is disposed along or disposed appurtenant to at least a section of the wellbore, the reservoir or the pipeline;

transmitting a pair of mutually coherent beams of electromagnetic radiation through the fiber-optic cable, wherein a first frequency of a first beam of the pair of mutually coherent beams is not equal to a second frequency of a second beam of the pair of mutually coherent beams;

detecting coherent Rayleigh noise generated by the transmission of the pair of mutually coherent beams through the fiber optic cable; and

processing the detected coherent Rayleigh noise to identify a said acoustic occurrence in the section of the wellbore, the reservoir or the pipeline.

21. A method for monitoring a wellbore or pipeline for occurrences which generate acoustic perturbations therein comprising:

providing a fiber optic cable disposed along or disposed appurtenant to at least a section of the wellbore or pipeline;

repeatedly transmitting a coherent beam of electromagnetic radiation along the fiber optic cable in a series of pulses, wherein a coherence time of the coherent beam of electromagnetic radiation is equal to or longer than a duration of each of the pulses;

detecting coherent Rayleigh noise backscattered from scattering sites distributed along the fiber optic cable; and

processing the detected coherent Rayleigh noise to identify changes in the relative location of said scattering sites and thereby identify a said acoustic occurrence in the section of the wellbore or the pipeline.