Methods of preparing treatment fluids comprising anhydrous ammonia for use in subterranean formation operations

Patent metadata

Field	Value
Publication number	US-10501686-B2
Application number	US-201515549125-A
Country	US
Kind code	B2
Filing date	Mar 10, 2015
Priority date	Mar 10, 2015
Publication date	Dec 10, 2019
Grant date	Dec 10, 2019

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.

First claim

The invention claimed is:

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.

2. 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.

3. 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.

4. 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.

5. 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.

6. 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.

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

8. 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.

9. 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.

Assignees

• Halliburton Energy Services Inc

Inventors

• Mccabe Michael A
• Weaver Jim D

Classifications

• C09K2208/22

  Hydrates inhibition by using well treatment fluids containing inhibitors of hydrate formers · CPC title

• C09K8/54

  Compositions for in situ inhibition of corrosion in boreholes or wells · CPC title

• C09K8/62

  Compositions for forming crevices or fractures · CPC title

• C09K8/5045

  containing inorganic compounds · CPC title

• C09K2208/20

  Hydrogen sulfide elimination · CPC title