Baker Hughes Corporation

Baker Hughes Holdings LLC

Baker Hughes Oilfield Operations LLC

Frances H DeBenedictis

Qi Qu

Hong Sun

Sumit Bhaduri

D V Satyanarayana Gupta

Lirio Quintero

Scott Gregory Nelson

Jia Zhou

Naima Bestaoui-Spurr

Paul S Carman

Harold Gene Hudson

Sandra L Berry

Dv Satyanarayana Gupta

Ahmed S Zakaria

Tom N Royce

Marty J Usie

Gianna Pietrangeli

Dustin Palm

A polymer-free fluid may be used to delay reaction of hydrofluoric acid with a subterranean formation. The fluid contains an organic compound having a bifunctional group, HF or a HF-generating compound, urea and an organophosphonate.

Method of treating a subterranean formation with delayed acid system

The disclosure relates to an aqueous acidizing fluid. In addition to an acid, the fluid contains an organophosphorus surfactant and/or an acid retarder. The organophosphorus surfactant may be an amino phosphonate or a phosphino carboxylate. The acid retarder comprises the combination of urea or a urea derivative and a bifunctional organic compound. Suitable bifunctional organic compounds contain at least one quaternary ammonium or phosphonium and at least one alcohol as well as salts of nitrogen containing heterocyclic rings.

Aqueous delayed acid system for well stimulation

A system for slowly releasing an oil-soluble well treatment agent into a well or a subterranean formation includes a composite of the oil-soluble well treatment agent associated with a second component. The amount of the oil-soluble well treatment agent in the composite is from 20 to 35 weight percent and the average particle size of the oil-soluble well treatment agent in the composite is less than or equal to 1 micrometer. The composite may further contain a water-soluble well treatment agent.

Delivery system for oil-soluble well treatment agents and methods of using the same

A method of treating a well or a subterranean formation with an aqueous treatment fluid containing one or more oil-soluble, water-insoluble well treatment agents. The fluid includes an aqueous dispersion containing the well treatment agent in an amount from 25 to 60 weight percent. The volume average particle diameter of the oil-soluble well treatment agent in the fluid may be less than or equal to 2.5 microns. The fluid may further contain a water-soluble well treatment agent.

Treatment methods using aqueous fluids containing oil-soluble treatment agents

A composite for controlling the release of a well treatment agent or for inhibiting or preventing the formation of contaminants into a fluid or a surface within a reservoir contains a well treatment agent immobilized on a surface of the support or into the pores of a porous support. The composite is at least partially coated with an organic polymer or inorganic material. The composite exhibits sufficient strength for the composite to be used as a proppant or in conjunction with a proppant.

Method of using coated composites containing delayed release agent in a well treatment operation

Disclosed herein is a fracturing fluid comprising a carrier fluid; a polymer that is soluble in the carrier fluid; the polymer being a synthetic polymer; the synthetic polymer being operative to increase the viscosity of the carrier fluid to about 5 to about 50 centipoise; the fracturing fluid being operative to reduce friction during a downhole fracturing operation and to transport a proppant during the downhole fracturing operation.

Fracturing fluids and methods for treating hydrocarbon-bearing formations

Incorporating at least oil-soluble organic peroxide into a mixture of an aqueous phase and at least one surfactant creates a breaker fluid that is a microemulsion or a nanoemulsion that can then perform as an internal breaker for reducing the viscosity of aqueous fluids gelled with a polymer, such as a crosslinked polysaccharide. One phase of the breaker fluid is water or water-based, e.g. brine, containing at least one oil-soluble organic peroxide as a non-aqueous internal phase that will, over time and optionally with heat, break the polymer-gelled portion of the gel. The overall breaking using the breaker fluid is slower as compared to introducing the organic peroxide breaker in a non-microemulsified or non-nanoemulsified form.

Microemulsion and nanoemulsion breaker fluids with organic peroxides

The production of hydrocarbons from a subterranean formation is enhanced by use of a well treatment fluid which contains a carboxylated guar which may be prepared by reacting a guar source and a derivatizing agent of the formula X(CH)COOH or alkali salts thereof, wherein X is selected from the group consisting of &#x2014;OSOCH; &#x2014;OSOCH; &#x2014;OTs, &#x2014;Br, and &#x2014;I and n is between from 1 to 4. The intrinsic viscosity of the carboxylated guar in 2% KCl at 27&#xb0; C. is at least 750 mL/g and the degree of substitution (DS) of the carboxylated guar is typically between from about 0.02 to about 0.15.

Growing community of inventors

Spring, TX, United States of America

Frances H DeBenedictis