Chemical packer composition and methods of using same for isolation of water/gas zones

Patent metadata

Field	Value
Publication number	US-10982126-B2
Application number	US-201916574552-A
Country	US
Kind code	B2
Filing date	Sep 18, 2019
Priority date	Sep 18, 2019
Publication date	Apr 20, 2021
Grant date	Apr 20, 2021

Abstract

A method of treating a subterranean formation penetrated by a wellbore, comprising introducing a chemical packer composition into the wellbore, wherein the chemical packer composition comprises water, a suspending agent, a gelling agent, and a sealant composition and wherein the chemical packer composition has a pH greater than 9, and allowing the chemical packer composition to form a plug, wherein a portion of the wellbore below the plug is isolated from fluid communication with a portion of the wellbore above the plug.

First claim

What is claimed is:

1. A method of treating a subterranean formation penetrated by a wellbore, comprising:
placing a tubular having an outlet into a non-vertical portion of the wellbore, wherein the tubular provides a flow path from the surface to the outlet;
introducing a chemical packer composition into a non-vertical portion of the wellbore via the tubular outlet, wherein the chemical packer composition comprises water, a suspending agent, a gelling agent, and a sealant composition and wherein the chemical packer composition has a pH greater than 9, wherein the chemical packer maintains contact with a 360° surface of the non-vertical portion of the wellbore; and
allowing the chemical packer composition to form a plug, wherein a portion of the wellbore below the plug is isolated from fluid communication via the wellbore with a portion of the wellbore above the plug.

2. The method of claim 1 wherein the suspending agent comprises diutan.

3. The method of claim 2 wherein the gelling agent comprises hydroxypropyl guar (HPG).

4. The method of claim 3 wherein the sealant composition comprises a water-soluble copolymer and a cross-linker and wherein the water-soluble copolymer comprises acrylamide and an acrylate ester and the cross-linker comprises polyethyleneimine.

5. The method of claim 1 wherein the tubular comprises coiled tubing.

6. The method of claim 1 wherein the non-vertical portion of the wellbore is cased.

7. A method of treating a subterranean formation penetrated by a wellbore, comprising:
introducing a chemical packer composition into the wellbore, wherein the chemical packer composition comprises water, a suspending agent, a gelling agent, and a first sealant composition and wherein the chemical packer composition has a pH greater than 9;
allowing the chemical packer composition to form a plug, wherein a first portion of the wellbore below the plug is isolated from fluid communication with a second portion of the wellbore above the plug;
penetrating the plug with a conduit; and

flowing a treatment fluid from the conduit into the first portion of the wellbore.

8. The method of claim 7 wherein the suspending agent comprises diutan, the gelling agent comprises hydroxypropyl guar, and the first sealant composition comprises polyethyleneimine and a polymer comprising acrylamide and an acrylate ester.

9. The method of claim 8 wherein the conduit is drill pipe or coiled tubing.

10. The method of claim 9 wherein the first portion of the wellbore is uncased.

11. A method of treating a subterranean formation penetrated by a wellbore, comprising:
introducing a first amount of a chemical packer composition into the wellbore at a first location that is below a treatment interval in the wellbore, wherein the chemical packer composition comprises water, a suspending agent, a gelling agent, and a sealant composition and wherein the chemical packer composition has a pH greater than 9;
introducing an amount of a treatment fluid into the wellbore at a second location that is above the first amount of the chemical packer composition and proximate the treatment interval;
introducing a second amount of the chemical packer composition into the wellbore at a third location that is above the treatment fluid and above the treatment interval; and
applying pressure to the wellbore to squeeze the treatment fluid into one or more flow paths present within the treatment interval, wherein the one or more flow paths provide fluid communication between the treatment interval of the wellbore and the subterranean formation.

12. The method of claim 11 wherein the first location, the second location, and the third location are located within a horizontal portion of the wellbore.

13. The method of claim 11 wherein the first and second amounts of the chemical packer composition are allowed to form plugs that straddle the treatment fluid and inhibit slumping of the treatment fluid.

14. The method of claim 11 wherein the suspending agent comprises diutan, the gelling agent comprises hydroxypropyl guar, and the sealant composition comprises polyethyleneimine and a polymer comprising acrylamide and an acrylate ester.

15. The method of claim 11 wherein the treatment fluid comprises cement, an epoxy resin, or combinations thereof.

16. The method of claim 11 wherein the first amount of the chemical packer composition is allowed to form a plug prior to introducing the second amount of the chemical packer composition into the wellbore.

17. The method of claim 16 wherein the first amount of the chemical packer composition crosslinks to form a rigid gel plug.

18. The method of claim 16 wherein a portion of the wellbore below the first location comprises one or more flow paths providing fluid communication between the portion of the wellbore below the first location and the formation.

19. The method of claim 18 wherein the one or more flow paths comprise perforations, fractures, or both.

20. The method of claim 18 wherein the one or more flow paths in the portion of the wellbore below the first location comprise a plurality of perforations and associated formation fractures and wherein the flow paths present within the treatment interval comprise a second plurality of perforations and associated formation fractures.

21. The method of claim 20 wherein the wellbore is lined with casing and the first and second plurality of perforations penetrate the casing.

22. The method of claim 11 wherein the wellbore is lined with casing and wherein the one or more flow paths present within the treatment interval provide for fluid from an interior of the casing to an exterior of the casing and adjacent subterranean formation.

23. The method of claim 22 wherein the one or more flow paths comprise a leak in the casing.

24. The method of claim 23 wherein the leak in the casing comprises a leaking casing collar.

25. The method of claim 22 wherein the one or more flow paths are formed as a result of loss of structural integrity of the casing.

26. The method of claim 25 wherein the one or more flow paths are formed as a result of casing corrosion.

Assignees

• Halliburton Energy Services Inc

Inventors

• Escobar Victor Daniel
• Eoff Larry Steven
• Laufer Jacob Wayne

Classifications

• E21B33/134

  Bridging plugs · CPC title

• E21B33/1208

  characterised by the construction of the sealing or packing means (E21B33/1277 takes precedence) · CPC title

• C04B26/28

  Polysaccharides or derivatives thereof · CPC title

• C04B26/04

  obtained by reactions only involving carbon-to-carbon unsaturated bonds · CPC title

• C04B26/10

  obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds · CPC title