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

• US 10,501,686 B2
• Filed: 03/10/2015
• Issued: 12/10/2019
• Est. Priority Date: 03/10/2015
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: McCabe, Michael A., Weaver, Jim D.
• Primary Examiner(s): Bhushan, Kumar R
• Application Number:
  US15/549,125
• Publication Number:
  US 20180030340A1
• Time in Patent Office: 1,736 Days
• CPC Class Codes: C09K 2208/10 Nanoparticle-containing well treatment fluids
• CPC Class Codes: C09K 2208/20 Hydrogen sulfide elimination
• CPC Class Codes: C09K 2208/22 Hydrates inhibition by using well treatment fluids containing inhibitors of hydrate formers
• CPC Class Codes: C09K 2208/26 Gel breakers other than bacteria or enzymes
• CPC Class Codes: C09K 2208/28 Friction or drag reducing additives
• CPC Class Codes: C09K 2208/30 Viscoelastic surfactants [VES]
• CPC Class Codes: C09K 2208/32 Anticorrosion additives
• CPC Class Codes: C09K 8/03 Specific additives for general use in well-drilling compositions
• CPC Class Codes: C09K 8/5045 containing inorganic compounds
• CPC Class Codes: C09K 8/52 Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
• CPC Class Codes: C09K 8/528 inorganic depositions, e.g. sulfates or carbonates
• CPC Class Codes: C09K 8/536 characterised by their form or by the form of their components, e.g. encapsulated material
• CPC Class Codes: C09K 8/54 Compositions for in situ inhibition of corrosion in boreholes or wells
• CPC Class Codes: C09K 8/572 containing inorganic compounds
• CPC Class Codes: C09K 8/58 Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
• CPC Class Codes: C09K 8/602 containing surfactants
• CPC Class Codes: C09K 8/605 containing biocides
• CPC Class Codes: C09K 8/607 specially adapted for clay formations
• CPC Class Codes: C09K 8/62 Compositions for forming crevices or fractures
• CPC Class Codes: C09K 8/72 Eroding chemicals, e.g. acids
• CPC Class Codes: C09K 8/845 : containing inorganic compounds
• CPC Class Codes: C09K 8/92 : characterised by their form or by the form of their components, e.g. encapsulated material C09K8/70 takes precedence
• CPC Class Codes: C09K 8/94 : Foams
• CPC Class Codes: E21B 21/003 : Means for stopping loss of drilling fluid plastering the borehole wall E21B33/138
• CPC Class Codes: E21B 37/06 : using chemical means for preventing or limiting , e.g. eliminating, the deposition of paraffins or like substances
• CPC Class Codes: E21B 41/02 : in situ inhibition of corrosion in boreholes or 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

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.