# US 10,767,104 B2 · Compositions for enhanced oil recovery

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- Number: US 10,767,104 B2
- Document ID: US10767104B2
- Status: Granted
- Kind: B2
- Application number: 16/004,889
- Filed: 2018-06-11
- Published: 2018-11-01
- Granted: 2020-09-08
- Earliest claimed: 2015-02-27
- Assignees: Ecolab USA Inc.
- Applicants: Ecolab USA Inc.
- Inventors: Linh Do; Brian Mueller; Duy T. Nguyen
- Web page: https://patentgrep.com/patent/US10767104B2

## CPC

- C09K 8/584: characterised by the use of specific surfactants
- C09K 8/602: {containing surfactants}
- C09K 8/68: containing organic compounds
- C09K 8/86: containing organic compounds
- C09K 8/885: {obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds}
- E21B 43/26: by forming crevices or fractures
- 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

Disclosed herein are compositions and methods for increasing recovery of hydrocarbon compounds from hydrocarbon-containing subterranean fractured rock formations. Novel emulsions and fracturing fluids are provided. The fracturing fluids convert oil-wet rocks to water-wet, yet exhibit a low tendency of composition components to sorb to the rock. The fracturing fluids do not cause formation of emulsions with hydrocarbon compounds within the subterranean fractured rock formations.

## Claims

### Claim 1

A method of increasing recovery of crude oil from a subterranean hydrocarbon-containing formation, the method consisting essentially of:
forming an emulsion, the emulsion consisting of
(i) one or more coupling agents,
(ii) one or more water soluble or dispersible nonionic surfactants having an HLB greater than about 10,
(iii) one or more zwitterionic surfactants,
(iv) one or more anionic surfactants, and
(v) water;
optionally combining the emulsion with one or more oil field additives selected from the group consisting of viscosifying agents, solvents, alkali, non-emulsifiers, corrosion inhibitors, biocides, friction reducers, emulsion breakers, and proppants;
contacting the emulsion with a high total dissolved solids water source comprising at least about 4 wt % nonpolymeric solids dissolved therein to form a fracturing fluid, the fracturing fluid comprising about 98 wt % to 99.99 wt % of the high total dissolved solids water source;
injecting the fracturing fluid into a subterranean hydrocarbon-containing formation; and
collecting a hydrocarbon from the subterranean hydrocarbon-containing formation.

### Claim 2 (depends on 1)

The method of claim 1 wherein at least a portion of the subterranean hydrocarbon containing formation is at a temperature of about 60° C. to 120° C.

### Claim 3 (depends on 1)

The method of claim 1 wherein the water source comprises about 5 wt % to 30 wt % total dissolved solids.

### Claim 4 (depends on 1)

The method of claim 1 wherein the contacting is carried out contemporaneously with the injecting.

### Claim 5 (depends on 1)

The method of claim 1 wherein the contacting is carried out prior to the injecting.

### Claim 6 (depends on 1)

The method of claim 1 wherein the injecting is into a first wellbore connected to the subterranean hydrocarbon-containing formation, and the collecting is from a second wellbore that is connected to the subterranean hydrocarbon-containing formation.

### Claim 7 (depends on 1)

The method of claim 1 wherein the injecting is into a wellbore connected to the subterranean hydrocarbon-containing formation, and the collecting is from the same wellbore.