Multi-interval wellbore treatment method

• US 8,887,803 B2
• Filed: 04/09/2012
• Issued: 11/18/2014
• Est. Priority Date: 04/09/2012
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: East, Loyd Eddie Jr., Lindsay, Sharlene Dawn, Gardiner, Nicholas Hubert
• Primary Examiner(s): SUCHFIELD, GEORGE A
• Application Number:
  US13/442,411
• Publication Number:
  US 20130264054A1
• Time in Patent Office: 953 Days
• Field of Search: 166/50, 166/250.01, 166/280.1, 166/281, 166/300, 166/305.1, 166/308.1, 166/308.2, 166/386
• US Class Current: 166/250.01
• CPC Class Codes: E21B 29/08 Cutting or deforming pipes to control fluid flow
• CPC Class Codes: E21B 33/12 Packers; Plugs used for cementing E21B33/134, E21B33/16
• CPC Class Codes: E21B 34/14 operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools E21B34/066 takes precedence
• CPC Class Codes: E21B 43/114 Perforators using direct fluid action on the wall to be perforated, e.g. abrasive jets
• CPC Class Codes: E21B 43/14 Obtaining from a multiple-zone well
• CPC Class Codes: E21B 43/162 Injecting fluid from longitudinally spaced locations in injection well
• CPC Class Codes: E21B 43/267 reinforcing fractures by propping
• CPC Class Codes: E21B 47/00 Survey of boreholes or wells monitoring pressure or flow of drilling fluid E21B21/08

Abstract

A method of servicing a subterranean formation comprising providing a wellbore penetrating the subterranean formation and having a casing string disposed therein, the casing string comprising a plurality of points of entry, wherein each of the plurality of points of entry provides a route a fluid communication from the casing string to the subterranean formation, introducing a treatment fluid into the subterranean formation via a first flowpath, and diverting the treatment fluid from the first flowpath into the formation to a second flowpath into the formation.

Claims

1. A method of servicing a subterranean formation comprising:

providing a wellbore penetrating the subterranean formation and having a casing string disposed therein, the casing string comprising a plurality of points of entry, wherein each of the plurality of points of entry provides a route of fluid communication from the casing string to the subterranean formation;

introducing a treatment fluid into the subterranean formation via a first flowpath; and

diverting the treatment fluid from the first flowpath into the formation to a second flowpath into the formation, wherein diverting the treatment fluid from the first flowpath into the formation to the second flowpath into the formation comprises introducing a diverting fluid into the first flowpath into the formation, wherein the diverting fluid comprises a diverter, wherein the diverter comprises a degradable material.

2. The method of claim 1, wherein one or more of the points of entry comprises a perforation.

3. The method of claim 1, wherein one or more of the point of entry comprises a casing window.

4. The method of claim 1, wherein providing a wellbore having the casing string comprising the plurality of points of entry comprises:

positioning a fluid jetting apparatus within the casing string, wherein the fluid jetting apparatus is attached to a work string;

configuring the fluid jetting apparatus to emit a perforating fluid; and

operating the fluid jetting apparatus so as to introduce one or more perforations within the casing string.

5. The method of claim 1, wherein providing a wellbore having the casing string comprising the plurality of points of entry comprises:

shifting a casing window assembly from a first configuration in which the casing window assembly does not provide a route of fluid communication from the casing string to the subterranean formation to a second configuration in which the casing window assembly provides a route of fluid communication from the casing string to the subterranean formation, wherein the casing window assembly is incorporated within the casing string.

6. The method of claim 5, wherein shifting the casing window assembly from the first configuration to the second configuration comprises:

positioning a mechanical shifting tool within the casing string, wherein the mechanical shifting tool is attached to a work string;

actuating the mechanical shifting tool, wherein actuating the mechanical shifting tool causes the mechanical shifting tool to engage a sliding sleeve of the casing window assembly; and

moving the sliding sleeve so as to unobscure one or more fluid ports of the casing window assembly.

7. The method of claim 1, wherein the treatment fluid comprises a composite treatment fluid, and further comprising forming the composite treatment fluid within the wellbore.

8. The method of claim 7, wherein forming the composite treatment fluid within the wellbore comprises:

introducing a first fluid component into the wellbore via a first flowpath into the wellbore;

introducing a second fluid component into the wellbore via a second flowpath into the wellbore; and

mixing the first component and the second component within the wellbore.

9. The method of claim 8, wherein the first flowpath into the wellbore comprises a flowbore defined by a workstring and the second flowpath into the wellbore comprises an annular space between the casing string and the workstring.

10. The method of claim 9, wherein the first fluid component comprises a concentrated proppant-laden slurry, wherein the second fluid component comprises a diluent, and wherein the composite treatment fluid comprises a fracturing fluid.

11. The method of claim 1, wherein the diverter comprises a degradable polymer, a dehydrated salt, or combinations thereof.

12. The method of claim 1, wherein the diverter comprises poly(lactic acid).

13. The method of claim 1, wherein introducing the diverting fluid into the first flowpath into the formation causes the formation of a plug of diverter within the first flowpath into the formation.

14. The method of claim 13, wherein the first flowpath into the formation comprises one of the plurality of points of entry, wherein the plug forms within the point of entry of the first flowpath into the formation.

15. The method of claim 14, wherein the second flowpath into the formation comprises a point of entry different from the point of entry of the first flowpath into the formation.

16. The method of claim 13, wherein the plug forms within the formation.

17. The method of claim 16, wherein the second flowpath into the formation comprises a fracture within the same zone of the subterranean formation as the first flowpath into the formation.

18. The method of claim 1, further comprising monitoring the subterranean formation as the treatment fluid is introduced therein.

19. The method of claim 18, wherein the subterranean formation is monitored using microseismic analysis.

20. The method of claim 1, further comprising:

introducing the treatment fluid into the subterranean formation via the second flowpath; and

diverting the treatment fluid from the second flowpath into the formation to a third flowpath into the formation.

21. The method of claim 1, further comprising:

recovering at least a portion of the diverting fluid from the first flowpath into the formation; and

introducing an additional quantity of the treatment fluid into the first flowpath into the formation.

22. A method of servicing a subterranean formation comprising:

providing a plurality of points of entry into the subterranean formation associated with a first stage of a wellbore servicing operation;

introducing a composite treatment fluid into the subterranean formation via a first of the plurality of points of entry into the formation associated with the first stage;

introducing a diverting fluid into the first of the plurality of points of entry into the formation, wherein introducing a diverting fluid into the first of the plurality of points of entry into the formation associated with the first stage causes the composite treatment fluid to be diverted from the first of the plurality of points of entry associated with the first stage to a second of the plurality of points of entry associated with the first stage, wherein the diverting fluid comprises a diverter, wherein the diverter comprises a degradable material; and

introducing the composite treatment fluid into the subterranean formation via the second of the plurality of points of entry into the formation associated with the first stage.

23. The method of claim 22, wherein the diverter comprises a degradable polymer, a dehydrated salt, or combinations thereof.

24. The method of claim 22, further comprising isolating the plurality of points of entry into the subterranean formation associated with the first stage from a plurality of points of entry into the subterranean formation associated with a second stage.

25. The method of claim 24, further comprising introducing a composite treatment fluid into the subterranean formation via a first of the plurality of points of entry into the subterranean formation associated with the second stage;

and

introducing a diverting fluid into the first of the plurality of points of entry into the formation associated with the second stage, wherein introducing a diverting fluid into the first of the plurality of points of entry into the formation associated with the second stage causes the composite treatment fluid to be diverted from the first of the plurality of points of entry associated with the second stage to a second of the plurality of points of entry associated with the second stage.

26. The method of claim 24, wherein isolating the plurality of points of entry into the subterranean formation associated with the first stage from the plurality of points of entry into the subterranean formation associated with the second stage comprises setting a particulate plug.

27. The method of claim 22, wherein introducing a composite treatment fluid into the subterranean formation comprises forming the composite treatment fluid in a wellbore, wherein forming the composite treatment fluid within the wellbore comprises:

introducing a first fluid component into the wellbore via a first flowpath into the wellbore;

introducing a second fluid component into the wellbore via a second flowpath into the wellbore; and

mixing the first component and the second component within the wellbore.

28. The method of claim 27, wherein the first flowpath into the wellbore comprises a flowbore defined by a workstring and the second flowpath into the wellbore comprises an annular space between the casing string and the workstring.

29. The method of claim 22, wherein the diverter comprises poly(lactic acid).