# US 10,501,686 B2 · Methods of preparing treatment fluids comprising anhydrous ammonia for use in subterranean formation operations

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- Number: US 10,501,686 B2
- Document ID: US10501686B2
- Status: Granted
- Kind: B2
- Application number: 15/549,125
- Filed: 2015-03-10
- Published: 2018-02-01
- Granted: 2019-12-10
- Earliest claimed: 2015-03-10
- Assignees: Halliburton Energy Services, Inc.
- Applicants: Halliburton Energy Services, Inc.
- Inventors: Michael A. McCabe; Jim D. Weaver
- Web page: https://patentgrep.com/patent/US10501686B2

## CPC

- C09K 8/845: {containing inorganic compounds}
- C09K 8/03: Specific additives for general use in well-drilling compositions
- C09K 8/5045: {containing inorganic compounds}
- C09K 8/52: Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
- C09K 8/528: inorganic depositions, e.g. sulfates or carbonates
- C09K 8/536: characterised by their form or by the form of their components, e.g. encapsulated material
- C09K 8/54: Compositions for in situ inhibition of corrosion in boreholes or wells
- C09K 8/572: {containing inorganic compounds}
- 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 8/602: {containing surfactants}
- C09K 8/605: {containing biocides}
- C09K 8/607: {specially adapted for clay formations}
- C09K 8/62: Compositions for forming crevices or fractures
- C09K 8/72: Eroding chemicals, e.g. acids
- C09K 8/92: characterised by their form or by the form of their components, e.g. encapsulated material (C09K8/70 takes precedence)
- C09K 8/94: Foams
- C09K 2208/10: Nanoparticle-containing well treatment fluids
- C09K 2208/20: Hydrogen sulfide elimination
- C09K 2208/22: Hydrates inhibition by using well treatment fluids containing inhibitors of hydrate formers
- C09K 2208/26: Gel breakers other than bacteria or enzymes
- C09K 2208/28: Friction or drag reducing additives
- C09K 2208/30: Viscoelastic surfactants [VES]
- C09K 2208/32: Anticorrosion additives
- E21B 21/003: {Means for stopping loss of drilling fluid (plastering the borehole wall E21B33/138)}
- E21B 37/06: using chemical means for preventing or limiting {, e.g. eliminating,} the deposition of paraffins or like substances
- E21B 41/02: in situ inhibition of corrosion in boreholes or wells
- 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

Methods comprising preparing a gelled fluid comprising a base fluid, a first gelling agent, and particulates; introducing the gelled fluid into a process stream, the process stream in fluid communication with a subterranean formation; introducing anhydrous ammonia into the gelled fluid at a downstream location in the process stream, thereby forming a particulate-containing treatment fluid; and introducing the particulate-containing treatment fluid into the subterranean formation from the process stream and through the wellhead.

## Claims

### Claim 1

A method comprising:
preparing a gelled fluid comprising a base fluid, a first gelling agent, and particulates, the base fluid includes a viscoelastic base fluid, a hydrocolloid base fluid, or any combination thereof;
introducing the gelled fluid into a process stream, the process stream in fluid communication with a wellhead, wherein the wellhead is in fluid communication with a subterranean formation;
introducing anhydrous ammonia into the gelled fluid at a downstream location in the process stream prior to the wellhead, thereby forming a particulate-containing treatment fluid; and
introducing the particulate-containing treatment fluid into the subterranean formation from the process stream and through the wellhead.

### Claim 2 (depends on 1)

The method of claim 1, wherein the base fluid is further selected from the group consisting of an aqueous base fluid, an oil base fluid, a solvent base fluid, and any combination thereof.

### Claim 3 (depends on 1)

The method of claim 1, wherein in the step of preparing a gelled fluid, the particulates are present in the gelled fluid in an amount in the range of from about 18% by volume of the gelled fluid to about 65% by volume of the gelled fluid.

### Claim 4 (depends on 1)

The method of claim 1, wherein the anhydrous ammonia is introduced into the gelled fluid in an amount to achieve a final particulate concentration in the particulate-containing treatment fluid in an amount in the range of from about 0.1% to about 48% by volume of the particulate-containing treatment fluid.

### Claim 5 (depends on 1)

The method of claim 1, wherein the anhydrous ammonia is in a phase selected from the group consisting of a liquid phase, a gaseous phase, and any combination thereof.

### Claim 6 (depends on 1)

The method of claim 1, wherein the process stream further comprises a pump in fluid communication therewith at an upstream location from the subterranean formation, and the downstream location in the process stream for introducing the anhydrous ammonia is upstream of the pump.

### Claim 7 (depends on 6)

The method of claim 6, wherein the pump is a high pressure pump.

### Claim 8 (depends on 1)

The method of claim 1, wherein the gelled fluid or the particulate-containing treatment fluid further comprises an oilfield additive selected from the group consisting of a second gelling agent, a salt, a weighting agent, an inert solid, a fluid loss control agent, an emulsifier, a dispersion aid, a corrosion inhibitor, an emulsion thinner, an emulsion thickener, a surfactant, a lost circulation material, a foaming agent, a gas, a pH control additive, a breaker, a biocide, a crosslinker, a stabilizer, a chelating agent, a scale inhibitor, a gas hydrate inhibitor, a mutual solvent, an oxidizer, a reducer, a friction reducer, a clay stabilizing agent, and any combination thereof.

### Claim 9 (depends on 1)

The method of claim 1, wherein the gelled fluid or the particulate-containing treatment fluid further comprises an oilfield additive added thereto by introducing the oilfield additive into the process stream, the oilfield additive selected from the group consisting of a second gelling agent, a salt, a weighting agent, an inert solid, a fluid loss control agent, an emulsifier, a dispersion aid, a corrosion inhibitor, an emulsion thinner, an emulsion thickener, a surfactant, a lost circulation material, a foaming agent, a gas, a pH control additive, a breaker, a biocide, a crosslinker, a stabilizer, a chelating agent, a scale inhibitor, a gas hydrate inhibitor, a mutual solvent, an oxidizer, a reducer, a friction reducer, a clay stabilizing agent, and any combination thereof.