# US 9,752,071 B2 · Composition and method for remediation of near wellbore damage

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- Number: US 9,752,071 B2
- Document ID: US9752071B2
- Status: Granted
- Kind: B2
- Application number: 14/208,685
- Filed: 2014-03-13
- Published: 2014-09-18
- Granted: 2017-09-05
- Earliest claimed: 2013-03-15
- Assignees: Chevron U.S.A. Inc.
- Applicants: Chevron U.S.A. Inc.
- Inventors: Varadarajan Dwarakanath; Robert Matthew Dean; Will S. Slaughter; Dustin Luke Walker; Sophany Thach
- Web page: https://patentgrep.com/patent/US9752071B2

## CPC

- C09K 8/58: Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K 8/032: {Inorganic additives}
- C09K 8/52: Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
- E21B 43/16: Enhanced recovery methods for obtaining hydrocarbons
- C09K: MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS

## Abstract

Aspects of the invention relate to compositions and methods that are used for remediation of near-wellbore damage. A specific aspect is a composition comprising an olefin sulfonate, a sulfosuccinate, and a chemical selected from the group consisting of an alcohol alkoxylated sulfate, an alcohol alkoxylated carboxylate, or a combination thereof.

## Claims

### Claim 1

A method for remediation of existing damage in a region near an injection wellbore in communication with a subterranean reservoir wherein the injection wellbore is not intended for receiving hydrocarbons and wherein the existing damage is caused by previous injection of a composition containing a polymer emulsion into the injection wellbore, the method comprising injecting into the subterranean reservoir a composition comprising an emulsion polymer, a C20 internal olefin sulfonate, a C15-18 internal olefin sulfonate, and an alcohol alkoxylated carboxylate, thereby dissolving, cleaning and/or flushing the polymer emulsion away from the injection wellbore.

### Claim 2 (depends on 1)

The method of claim 1, wherein the injection of the composition stimulates the region near the injection wellbore in communication with the subterranean reservoir.

### Claim 3 (depends on 1)

The method of claim 1, wherein the injection improves the relative permeability of the region near the injection wellbore in communication with the subterranean reservoir.

### Claim 4 (depends on 3)

The method of claim 3, wherein the relative permeability of the region near the injection wellbore in communication with the subterranean reservoir is increased by at least 250 percent.

### Claim 5 (depends on 1)

The method of claim 1, wherein the temperature of the region near the injection wellbore in communication with the subterranean reservoir is above 55° C.

### Claim 6 (depends on 5)

The method of claim 5, wherein the composition further comprises an alkali.

### Claim 7 (depends on 1)

The method of claim 1, further comprising a co-solvent.