OPTICAL MONITORING OF FLUID FLOW

• US 20100207019A1
• Filed: 02/15/2010
• Published: 08/19/2010
• Est. Priority Date: 02/17/2009
• Status: Abandoned Application

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Hartog, Arthur H., Wilson, Colin A.
• Application Number:
  US12/705,767
• Publication Number:
  US 20100207019A1
• Time in Patent Office: Days
• US Class Current: 250/269.100
• CPC Class Codes: E21B 47/107 using acoustic means

Abstract

A distributed vibration sensor is positioned in a wellbore to measure fluid flow. The output of the sensor is monitored to acquire a distribution of vibration along a region of interest in the wellbore. An indication of the effectiveness of a well treatment to stimulate fluid flow in the wellbore may be provided based on the acquired vibration distribution. In some embodiments, the well treatment may be adjusted based on the indication of effectiveness.

Claims

1. A system comprising:

a fiber optic cable deployed in a wellbore proximate a region of interest;

an optical source to launch an optical pulse into the fiber optic cable;

an optical receiver to receive a backscattered optical signal produced from the fiber optic cable in response to the light pulse; and

a processing system configured to determine a distribution of vibration with respect to location along the fiber optic cable based on the backscattered signal.

2. The system as recited in claim 1, comprising:

a well treatment system to perform a well treatment in the wellbore to stimulate fluid flow, wherein the processing system is further configured to provide a determination of an effectiveness of the well treatment based on the distribution of vibration.

3. The system as recited in claim 2, further comprising a second optical cable deployed in the wellbore to sense a distribution of temperature in the region of interest

4. The system as recited in claim 2, wherein the well treatment system is configured to deploy a conduit into the wellbore to transport a material for performing the well treatment.

5. The system as recited in claim 4, wherein the fiber optic cable is deployed in the conduit.

6. The system as recited in claim 2, wherein the well treatment system is configured to convey a treatment material into the wellbore to perform the well treatment.

7. The system as recited in claim 6, wherein the fiber optic cable is deployed in the treatment material.

8. A method for monitoring a fluid flow in a wellbore, comprising:

providing in the wellbore a distributed vibration sensor, wherein the distributed vibration sensor is positioned to sense a distribution of vibration along a section of the well;

performing a well treatment involving transporting a material into the well;

monitoring output of the distributed vibration sensor for the section of the well; and

providing an indication of a level of effectiveness of the well treatment from the output.

9. The method as recited in claim 8, further comprising adjusting the well treatment based on the indication of the level of effectiveness.

10. The method as recited in claim 9, wherein adjusting the well treatment comprises at least one of terminating the treatment, initiating a different treatment, varying a treatment material, and varying a flow rate of a treatment material.

11. The method as recited in claim 8, wherein monitoring the output of the distributed vibration sensor is performed during performance of the well treatment.

12. The method as recited in claim 8, wherein performing the well treatment comprises deploying in the wellbore a conduit to transport the treatment material.

13. The method as recited in claim 12, wherein the distributed vibration sensor is deployed in the conduit.

14. The method as recited in claim 8, further comprising providing in the wellbore a distributed temperature sensor to provide a temperature distribution in the region of interest.

15. The method as recited in claim 14, wherein providing the indication of the level of effectiveness comprises correlating the temperature distribution with the distribution of vibration.

16. A method usable in a wellbore, comprising:

positioning a distributed vibration sensor to measure vibration in a region of interest in a well;

acquiring from the distributed vibration sensor a distribution of vibration along the region of interest resulting from a well treatment process; and

providing a determination of a level of effectiveness of the well treatment process based on the distribution of vibration.

17. The method as recited in claim 16, wherein the distributed vibration sensor comprises an optical fiber, and wherein acquiring the distribution of vibration comprises:

launching an optical signal into the optical fiber;

detecting a backscattered signal produced by the optical fiber in response to the optical signal; and

determining the distribution of vibration based on the detected backscattered signal.

18. The method as recited in claim 17, wherein the launched optical signal is a pulse of light, and wherein detecting the backscattered signal comprises detecting Rayleigh backscatter produced in response to the pulse of light.

19. The method as recited in claim 16, further comprising:

performing the well treatment process; and

adjusting performance of the well treatment process based on the indication of the effectiveness of the well treatment process.

20. The method as recited in claim 19, further comprising acquiring the distribution of vibration during performance of the well treatment process.