Injecting polyelecrolyte based sacrificial agents for use in unconventional formations

Patent metadata

Field	Value
Publication number	US-2016222284-A1
Application number	US-201514895854-A
Country	US
Kind code	A1
Filing date	Jul 1, 2015
Priority date	Jul 2, 2014
Publication date	Aug 4, 2016
Grant date	—

Abstract

Compositions and methods for formulating treatment fluids that comprise a surfactant having reduced and delayed adsorption are provided. In one embodiment, the method comprises: introducing a first treatment fluid comprising an aqueous base fluid and a polyelectrolyte into a wellbore penetrating at least a portion of a subterranean formation; contacting at least a portion of the subterranean formation with the polyelectrolyte; and introducing a second treatment fluid comprising an aqueous base fluid and a surfactant into the wellbore penetrating at least the portion of the subterranean formation.

First claim

What is claimed is:

1 . A method comprising:
introducing a first treatment fluid comprising an aqueous base fluid and a polyelectrolyte into a wellbore penetrating at least a portion of a subterranean formation; contacting at least a portion of the subterranean formation with the polyelectrolyte; and introducing a second treatment fluid comprising an aqueous base fluid and a surfactant into the wellbore penetrating at least the portion of the subterranean formation.

2 . The method of claim 1 wherein the second treatment fluid is a fracturing fluid, an acidizing fluid, or a drilling fluid.

3 . The method of claim 1 wherein the surfactant comprises at least one surfactant selected from the group consisting of sodium, potassium, and ammonium salts of long chain alkyl sulfonates and alkyl aryl sulfonates; dialkyl sodium sulfosuccinates; alkyl sulfates; alkyl sulfonates; alkoxylated sulfates; ethoxylated alcohols; polyglucosides; ethoxylated long-chain alcohols; alkyl ammonium bromides; hydroxysultaines; and any combination thereof.

4 . The method of claim 1 wherein the polyelectrolyte comprises at least one polyelectrolyte selected from the group consisting of polyacrylate, poly(styrenesulfonic acid), poly(2-acrylamido-2-methyl-1-propane sulfonic acid), sulfonated poly(ether ether ketone), sulfonated lignin, poly(ethylenesulfonic acid), poly(methacryloxyethylsulfonic acid), poly(acrylic acid), poly(methacrylic acid), HV-sodium alginate, sodium alginate, sodium hyaluronate, heparin sulfate, cellulose sulfate, kappa carrageenan, pentasodium tripolyphosphate, low-esterified pectin(polygalacturonic acid), polyglutamic acid, carboxymethylcellulose, chondroitin sulfate-6, chondroitin sulfate-4, collagen, polyalkylene imines, polyethylene polyamine, polypropylene polyamine, polyvinylamine, polyallylamine, poly(vinylalcohol/vinylamine), chitosan, polylysine, polymyxin, spermine hydrochloride, protamine sulfate, poly(methylene-co-guanidine) hydrochloride, polythethylenimine-ethoxylated, polyethylenimine-ex-ichlorhydrin modified, and any combination thereof.

5 . The method of claim 4 wherein the polyelectrolyte has a molecular weight of about 100 Daltons to about 300,000 Daltons.

6 . The method of claim 1 wherein the polyelectrolyte and the surfactant are both anionic.

7 . The method of claim 1 wherein the subterranean formation is an unconventional formation.

8 . The method of claim 8 wherein the unconventional formation is a shale play.

9 . The method of claim 1 wherein the second treatment fluid further comprises an acid.

10 . The method of claim 1 wherein the second treatment fluid is injected into the wellbore using one or more pumps.

11 . A method comprising:
introducing a first treatment fluid comprising an aqueous base fluid and a polyelectrolyte into a wellbore penetrating at least a portion of a subterranean formation; contacting at least a portion of the subterranean formation with the polyelectrolyte; and introducing a second treatment fluid comprising an aqueous base fluid and a surfactant into the wellbore penetrating at least the portion of the subterranean formation at a pressure sufficient to create or enhance one or more fractures within the subterranean formation.

12 . The method of claim 11 wherein the surfactant comprises at least one surfactant selected from the group consisting of sodium, potassium, and ammonium salts of long chain alkyl sulfonates and alkyl aryl sulfonates; dialkyl sodium sulfosuccinates; alkyl sulfates; alkyl sulfonates; alkoxylated sulfates; ethoxylated alcohols; polyglucosides; ethoxylated long-chain alcohols; alkyl ammonium bromides; hydroxysultaines; and any combination thereof.

13 . The method of claim 11 wherein the polyelectrolyte comprises at least one polyelectrolyte selected from the group consisting of polyacrylate, poly(styrenesulfonic acid), poly(2-acrylamido-2-methyl-1-propane sulfonic acid), sulfonated poly(ether ether ketone), sulfonated lignin, poly(ethylenesulfonic acid), poly(methacryloxyethylsulfonic acid), poly(acrylic acid), poly(methacrylic acid), HV-sodium alginate, sodium alginate, sodium hyaluronate, heparin sulfate, cellulose sulfate, kappa carrageenan, pentasodium tripolyphosphate, low-esterified pectin(polygalacturonic acid), polyglutamic acid, carboxymethylcellulose, chondroitin sulfate-6, chondroitin sulfate-4, collagen, polyalkylene imines, polyethylene polyamine, polypropylene polyamine, polyvinylamine, polyallylamine, poly(vinylalcohol/vinylamine), chitosan, polylysine, polymyxin, spermine hydrochloride, protamine sulfate, poly(methylene-co-guanidine) hydrochloride, polythethylenimine-ethoxylated, polyethylenimine-ex-ichlorhydrin modified, and any combination thereof.

14 . The method of claim 13 wherein the polyelectrolyte has a molecular weight of about 100 Daltons to about 300,000 Daltons.

15 . The method of claim 11 wherein the polyelectrolyte and the surfactant are both anionic.

16 . The method of claim 11 wherein the subterranean formation is an unconventional formation.

17 . The method of claim 16 wherein the unconventional formation is a shale play.

18 . The method of claim 11 wherein the second treatment fluid further comprises an acid.

19 . The method of claim 11 wherein the second treatment fluid further comprises a plurality of proppant particles.

20 . The method of claim 11 wherein the second treatment fluid is injected into the wellbore using one or more pumps.

Assignees

• Halliburton Energy Services Inc

Inventors

• He Kai
• Xu Liang

Classifications

• C09K8/725

  Compositions containing polymers · CPC title

• C09K8/602

  containing surfactants · CPC title

• E21B43/267

  reinforcing fractures by propping · CPC title

• C09K8/68

  containing organic compounds · CPC title

• C09K8/035

  Organic additives · CPC title