Fiberoptic systems and methods for formation monitoring

• US 9,091,785 B2
• Filed: 01/08/2013
• Issued: 07/28/2015
• Est. Priority Date: 01/08/2013
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Donderici, Burkay, Samson, Etienne M., Leblanc, Michel J.
• Primary Examiner(s): Gaworecki, Mark R
• Application Number:
  US13/736,324
• Publication Number:
  US 20140191120A1
• Time in Patent Office: 931 Days
• Field of Search: 250/254, 250/256, 250/265
• US Class Current: 1/1
• CPC Class Codes: E21B 47/135 using light waves, e.g. infrared or ultraviolet waves
• CPC Class Codes: G01V 3/34 Transmitting data to recording or processing apparatus; Recording data

Abstract

A formation monitoring system includes a casing. An array of electromagnetic field sensors is positioned in the annular space and configured to communicate with the surface via a fiberoptic cable. A computer coupled to the fiberoptic cable receives measurements from the array and responsively derives the location of any fluid fronts in the vicinity such as an approaching flood front to enable corrective action before breakthrough. A formation monitoring method includes: injecting a first fluid into a reservoir formation; producing a second fluid from the reservoir formation via a casing in a borehole; collecting electromagnetic field measurements with an array of fiberoptic sensors in an annular space, the array communicating measurements to a surface interface via one or more fiberoptic cables; and operating on the measurements to locate a front between the first and second fluids.

Claims

1. A formation monitoring system that comprises:

a casing that defines an annular space within a borehole;

an array of electromagnetic field sensors in the annular space;

an optical waveguide that conveys optical signals to and from the array of electromagnetic field sensors;

a power source to generate a distribution of current flow into formations penetrated by said borehole;

a surface interface coupled to the optical waveguide to receive optical signals from the array of electromagnetic field sensors, said received optical signals representing electromagnetic field measurements collected by the array of electromagnetic field sensors in response to the current flow; and

a computer that operates on electromagnetic field measurement data corresponding to the received optical signals to calculate at least one parameter associated with an approaching flood front.

2. The system of claim 1, wherein the at least one parameter comprises a flood front location.

3. The system of claim 1, wherein the computer calculates the at least one parameter at different times.

4. The system of claim 3, further comprising a valve that controls a flow rate from at least one production zone in said borehole, wherein the computer provides a new setting for said valve based at least in part on said at least one parameter.

5. The system of claim 3, further comprising a pump that controls a flow rate to at least one zone in an injection well, wherein the computer provides a new pump rate for said pump based at least in part on said at least one parameter.

6. The system of claim 3, further comprising a valve that controls a flow rate to at least one injection zone, wherein the computer provides a new setting for said valve based at least in part on said at least one parameter.

7. The system of claim 1, wherein the power source is coupled to the casing to generate the distribution of current flow into formations penetrated by said borehole.

8. The system of claim 7, wherein the power source is electrically connected to said casing above ground.

9. The system of claim 7, wherein the power source is electrically connected to a tool suspended on a cable, control line, tubing, or coiled tubing inside the casing.

10. The system of claim 7, wherein the power source is electrically connected to a casing in a second borehole.

11. The system of claim 7, wherein the power source is electrically connected to a tool suspended on a cable, control line, tubing, or coiled tubing in a second borehole for cross-well monitoring.

12. The system of claim 7, wherein at least one of said electromagnetic field sensors measures a radial electric field component.

13. The system of claim 1, wherein the optical waveguide comprises a fiberoptic cable.

14. The system of claim 13, wherein the fiberoptic cable includes one or more electrical conductors coupled to the power source to generate the distribution of current into formations penetrated by said borehole.

15. The system of claim 13, wherein the fiberoptic cable includes one or more electrical conductors that are uninsulated near regions of interest and insulated in other regions to direct current from the power source to said regions of interest.

16. The system of claim 13, further comprising a second fiberoptic cable coupled to electromagnetic field sensors in the annular space that are in an axial range overlapping with an axial range of the array of electromagnetic sensors coupled to the optical waveguide.

17. The system of claim 1, further comprising at least one electric dipole source antenna positioned in the annular space and powered by the power source.

18. The system of claim 1, further comprising at least one magnetic dipole source antenna positioned in the annular space and powered by the power source.

19. The system of claim 1, wherein the computer derives a multidimensional model of formation resistivity or conductivity based at least in part on said received optical signals to track a flood front location as a function of time.

20. A formation monitoring method that comprises:

injecting a first fluid into a reservoir formation;

producing a second fluid from the reservoir formation via a casing in a borehole;

collecting electromagnetic field measurements with an array of fiberoptic sensors in an annular space between said casing and said borehole, said array communicating measurements to a surface interface via one or more fiberoptic cables; and

operating on said measurements to locate a front between the first and second fluids.

21. The method of claim 20, further comprising repeating said collecting and operating to track the front as a function of time.

22. The method of claim 20, further comprising reducing production from one or more zones upon detecting said front near said borehole.

23. The method of claim 20, further comprising reducing injection into one or more zones upon detecting said front near said borehole.

24. The method of claim 20, further comprising injecting an electrical current into the reservoir formation via said casing.

25. The method of claim 20, further comprising generating an electromagnetic field via an electrical dipole source in said annular space.

26. The method of claim 20, further comprising generating an electromagnetic field via a magnetic dipole source in said annular space.