Breaker coated particulates for use in subterranean formation operations

Patent metadata

Field	Value
Publication number	US-10428264-B2
Application number	US-201415525940-A
Country	US
Kind code	B2
Filing date	Dec 12, 2014
Priority date	Dec 12, 2014
Publication date	Oct 1, 2019
Grant date	Oct 1, 2019

Abstract

Methods of preparing a viscosified treatment fluid comprising a base fluid, a gelling agent, and breaker coated particulates (“BCPs”). The BCPs comprise particulates at least partially coated with a first layer of a stabilization agent followed by a second layer of a breaker. The viscosified treatment fluid may be introduced into a subterranean formation, the breaker activated to reduce a viscosity thereof, and a particulate pack formed in the subterranean formation with the BCPs.

First claim

The invention claimed is:

1. A method comprising:
preparing a viscosified treatment fluid comprising a base fluid, a gelling agent, and breaker coated particulates (BCPs),
wherein the BCPs comprise particulates at least partially coated with a first layer of a stabilization agent followed by a second layer of a breaker, wherein the second layer of the breaker forms a chemical bond with the first layer of the stabilization agent, and
wherein the stabilization agent is present in the range of about 0.1% to about 5% v/w % of the particulates;

introducing the viscosified treatment fluid into a subterranean formation;
activating the breaker to reduce a viscosity of the viscosified treatment fluid; and
forming a particulate pack in the subterranean formation with the BCPs.

2. The method of claim 1 , wherein the gelling agent in the viscosified treatment fluid at least partially contacts the BCPs prior to activating the breaker, and wherein activating the breaker substantially removes the gelling agent from contact with the BCPs.

3. The method of claim 1 , wherein the breaker comprises at least one breaker selected from the group consisting of an oxidative breaker, an acid breaker, a delayed release acid breaker, a delayed release enzyme breaker, a temperature activated breaker, a hydrolysable ester breaker, and any combination thereof.

4. The method of claim 1 , wherein the stabilization agent is selected from the group consisting of an aqueous tackifying agent, a non-aqueous tackifying agent, a silyl-modified polyamide compound, and any combination thereof.

5. The method of claim 1 , wherein the viscosified treatment fluid further comprises a free-floating breaker.

6. The method of claim 1 , wherein the particulate pack is selected from the group consisting of a proppant pack, a gravel pack, and any combination thereof.

7. The method of claim 1 , wherein the viscosified treatment fluid is introduced into the subterranean formation at a rate and pressure sufficient to create or enhance a fracture therein, and wherein the particulate pack is formed in the fracture.

8. The method of claim 1 , further comprising a wellhead with a tubular extending therefrom and into a subterranean formation; and
a pump fluidly coupled to the tubular, the tubular comprising the viscosified treatment fluid.

9. A method comprising:
preparing a viscosified treatment fluid comprising a base fluid, a gelling agent, and breaker coated particulates (BCPs) encapsulated in an encapsulating material,
wherein the BCPs comprise particulates at least partially coated with a first layer of a stabilization agent followed by a second layer of a breaker, wherein the second layer of the breaker forms a chemical bond with the first layer of the stabilization agent, and
wherein the stabilization agent is present in the range of about 0.1% to about 5% v/w % of the particulates;

introducing the viscosified treatment fluid into a subterranean formation;
removing the encapsulating material;
activating the breaker to reduce a viscosity of the viscosified treatment fluid; and
forming a particulate pack in the subterranean formation with the BCPs.

10. The method of claim 9 , wherein the gelling agent in the viscosified treatment fluid at least partially contacts the BCPs prior to activating the breaker, and wherein activating the breaker substantially removes the gelling agent from contact with the BCPs.

11. The method of claim 9 , wherein the breaker comprises at least one breaker selected from the group consisting of an oxidative breaker, an acid breaker, a delayed release acid breaker, a delayed release enzyme breaker, a temperature activated breaker, a hydrolysable ester breaker, and any combination thereof.

12. The method of claim 9 , wherein the stabilization agent is selected from the group consisting of an aqueous tackifying agent, a non-aqueous tackifying agent, a silyl-modified polyamide compound, and any combination thereof.

13. The method of claim 9 , wherein the encapsulating material is selected from the group consisting of a corn starch, a wheat starch, a potato starch, a barley starch, a bean starch, a cassava starch, a ground rice, a ground corn, a ground wheat, a ground bean, a ground guar gum, a cellulose, a cellulose derivative, a polyacrylate, a polymethacrylate, a polyacrylamide, a polyvinylpyrrolidone, a polylactic acid, an ethylene propylene diene monomer rubber, a polyvinylidene chloride, a nylon, a wax, a polyurethane, a cross-linked partially hydrolyzed acrylic, a shellac, a calcium sulfate, a calcium chloride, a cementitious material, a salt, barium sulfate, benzoic acid, polyvinyl alcohol, sodium carbonate, sodium bicarbonate, calcium oxide, a degradable polymer, a polyglycolide, a poly(ε-caprolactone), a poly(hydroxybutyrate), a poly(anhydride), an aliphatic polycarbonate, a polyorthoester, a poly(amino acid), a poly(ethylene oxide), a poly(phosphazene), and any combination thereof.

14. The method of claim 9 , wherein the viscosified treatment fluid further comprises a free-floating breaker.

15. The method of claim 9 , wherein the viscosified treatment fluid is introduced into the subterranean formation at a rate and pressure sufficient to create or enhance a fracture therein, and wherein the particulate pack is formed in the fracture.

16. The method of claim 9 , wherein the BCPs encapsulated in an encapsulating material are stored in dry-form prior to the step of: preparing a viscosified treatment fluid.

17. The method of claim 9 , further comprising a wellhead with a tubular extending therefrom and into a subterranean formation; and
a pump fluidly coupled to the tubular, the tubular comprising the viscosified treatment fluid.

18. A viscosified treatment fluid comprising:
a base fluid,
a gelling agent, and
breaker coated particulates (BCPs),
wherein the BCPs comprise particulates at least partially coated with a first layer of a stabilization agent followed by a second layer of a breaker, wherein the second layer of the breaker forms a chemical bond with the first layer of the stabilization agent, and
wherein the stabilization agent is present in the range of about 0.1% to about 5% v/w % of the particulates.

19. The treatment fluid of claim 18 , where the breaker coated particulates are encapsulated in an encapsulating material.

20. The treatment fluid of claim 18 , further comprising non-coated particulates, wherein the BCPs are present in an amount in the range of from about 5% to about 95% of the combined weight of the non-coated particulates and the BCPs.

Assignees

• Halliburton Energy Services Inc

Inventors

• Chopade Prashant D
• Nguyen Philip D

Classifications

• C09K8/706 Primary

  Encapsulated breakers · CPC title

• C09K8/88

  macromolecular compounds · CPC title

• C09K8/68

  containing organic compounds · CPC title

• C09K2208/26

  Gel breakers other than bacteria or enzymes · CPC title

• C09K8/805

  Coated proppants · CPC title