Apparatus and methods for characterizing a reservoir

• US 8,991,245 B2
• Filed: 05/27/2009
• Issued: 03/31/2015
• Est. Priority Date: 07/15/2008
• Status: Active Grant

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Pop, Julian, Barriol, Yves, Brockmeier, Oivind, Desroches, Jean, Harrigan, Edward, Karuppoor, Srinand, Hill, Bunker M., Fensky, Charles, Del Campo, Christopher S., Fields, Troy, Majkut, Frederik, Eghbali, Ali
• Primary Examiner(s): FITZGERALD, JOHN P
• Application Number:
  US13/054,236
• Publication Number:
  US 20110107830A1
• Time in Patent Office: 2,134 Days
• Field of Search: 731/520.5, 731/524.1, 166/264, 166/55, 166/100, 166/298
• US Class Current: 73/152.41
• CPC Class Codes: E21B 33/12 Packers; Plugs used for cementing E21B33/134, E21B33/16
• CPC Class Codes: E21B 49/008 by injection test; by analysing pressure variations in an injection or production test, e.g. for estimating the skin factor measuring pressure E21B47/06
• CPC Class Codes: E21B 49/06 using side-wall drilling tools pressing or scrapers
• CPC Class Codes: E21B 49/10 using side-wall fluid samplers or testers
• CPC Class Codes: E21B 7/061 the tool shaft advancing relative to a guide, e.g. a curved tube or a whipstock

Abstract

An apparatus comprising a downhole tool configured for conveyance within a borehole penetrating a subterranean formation, wherein the downhole tool comprises: a probe assembly configured to seal a region of a wall of the borehole; a perforator configured to penetrate a portion of the sealed region of the borehole wall by projecting through the probe assembly; a fluid chamber comprising a fluid; and a pump configured to inject the fluid from the fluid chamber into the formation through the perforator.

Claims

1. An apparatus for conveyance within a borehole extending into a subsurface formation, the apparatus comprising:

a probe assembly disposed in a first portion of a tool body;

an actuator configured to move the probe assembly between a retracted position and a deployed position, wherein the probe assembly is configured to seal a region of the borehole wall when in the deployed position;

a perforator configured to penetrate the borehole wall at a plurality of azimuthal locations within the borehole by projecting through the probe assembly;

a swivel coupled to the probe assembly to rotate the perforator to the plurality of azimuthal locations within the borehole, wherein the swivel is configured to rotate the probe assembly azimuthally with respect to a second portion of the tool body and the borehole wall, wherein the swivel is coupled between the first portion of the tool body housing the probe assembly and the second portion of the tool body housing an anchor assembly, and wherein the swivel permits rotation of the probe assembly azimuthally within the borehole with respect to the anchor assembly;

a flex joint disposed in the first portion of the tool body to permit non-coaxial alignment between the anchor assembly and the probe assembly;

a flow line fluidly communicating with the perforator; and

a pump carried within the tool body and operatively coupled to the flow line to inject fluid into the subsurface formation through the perforator at the plurality of azimuthal locations within the borehole.

2. The apparatus of claim 1 wherein the perforator is configured to penetrate at least one of a consolidated formation, a casing, or cement.

3. The apparatus of claim 1 further comprising a fluid chamber housing the fluid and disposed in fluid communication with the flow line.

4. The apparatus of claim 1 wherein the perforator comprises at least one of an explosive charge, a hydraulic punch, a coring bit, or a combination thereof.

5. The apparatus of claim 1 further comprising an inclinometry device configured to measure a perforation orientation.

6. The apparatus of claim 1, further comprising a powered orienting sub coupled to the anchor assembly to rotate the probe assembly with respect to the anchor assembly.

7. The apparatus of claim 1 wherein the probe assembly comprises a substantially rigid plate and a compressible packer element coupled to the plate.

8. The apparatus of claim 7 wherein the actuator comprises:

a plurality of pistons connected to the plate and configured to move the probe assembly between the retracted and deployed positions; and

a controllable energy source configured to power the pistons.

9. A method of characterizing a subsurface formation, comprising:

conveying a tool within a borehole penetrating the subsurface formation, wherein the tool comprises;

a probe assembly;

an actuator configured to move the probe assembly between a retracted position and a deployed position; and

a perforator;

sealing a first azimuthal location of the borehole wall using the probe assembly;

projecting the perforator through the probe assembly to penetrate the borehole wall at the first azimuthal location;

rotating the probe assembly azimuthally within borehole to a second azimuthal location of the borehole wall, wherein the first and second azimuthal locations are disposed around the tool in substantially the same plane;

sealing the second azimuthal location of the borehole wall using the probe assembly;

projecting the perforator through the probe assembly to penetrate the borehole wall at the second azimuthal location;

injecting fluid into the formation through the perforator at the first and second azimuthal locations; and

measuring a closure stress for each of first and second azimuthal locations and determining, based on the closure stresses for the first and second azimuthal locations, at least one of a minimum horizontal stress value, a maximum horizontal stress value, or a horizontal stress orientation relative to a reference.

10. The method of claim 9 wherein projecting the perforator through the probe assembly to penetrate the borehole wall at the first azimuthal location comprises projecting the perforator to penetrate at least one of a consolidated formation, a casing, or cement.

11. The method of claim 9 further comprising determining mobility of the injected fluid.

12. The method of claim 9 further comprising performing a leak-off test on the subterranean formation.

13. The method of claim 9 wherein injecting fluid into the formation comprises injecting at least one of an injection fluid, a formation fluid, or a mixture thereof from a sample chamber disposed within the tool.

14. The method of claim 9 wherein conveying the tool within the borehole comprises conveying the tool via at least one of a wireline or a drill string.

15. A method of characterizing a subsurface formation, comprising:

conveying a tool within a borehole penetrating the subsurface formation, wherein the tool comprises;

a probe assembly;

an actuator configured to move the probe assembly between a retracted position and a deployed position; and

a perforator;

sealing a first azimuthal location of the borehole wall using the probe assembly;

projecting the perforator through the probe assembly to penetrate the borehole wall at the first azimuthal location;

rotating the probe assembly azimuthally within borehole to a second azimuthal location of the borehole wall, wherein the first and second azimuthal locations are disposed around the tool in substantially the same plane;

sealing the second azimuthal location of the borehole wall using the probe assembly;

projecting the perforator through the probe assembly to penetrate the borehole wall at the second azimuthal location;

injecting fluid into the formation through the perforator at the first and second azimuthal locations, wherein injecting fluid into the formation comprises injecting fracturing fluid into the first azimuthal location prior to rotating the probe assembly azimuthally within borehole to the second azimuthal location.

16. A method of characterizing a subsurface formation, comprising:

conveying a tool within a borehole penetrating the subsurface formation, wherein the tool comprises;

a probe assembly;

an actuator configured to move the probe assembly between a retracted position and a deployed position; and

a perforator;

sealing a first azimuthal location of the borehole wall using the probe assembly;

projecting the perforator through the probe assembly to penetrate the borehole wall at the first azimuthal location;

rotating the probe assembly azimuthally within borehole to a second azimuthal location of the borehole wall, wherein the first and second azimuthal locations are disposed around the tool in substantially the same plane;

sealing the second azimuthal location of the borehole wall using the probe assembly;

projecting the perforator through the probe assembly to penetrate the borehole wall at the second azimuthal location;

injecting fluid into the formation through the perforator at the first and second azimuthal locations;

measuring orientations of perforations formed at the first and second azimuthal locations and

measuring a fracture closure stress as a function of the orientations.

17. The method of claim 16 wherein injecting fluid into the formation comprises injecting at least one of an injection fluid, a formation fluid, or a mixture thereof from a sample chamber disposed within the tool.