Baker Hughes Corporation

Baker Hughes, a Ge Compnay, LLC

Bj Services Company

Baker Hughes Holdings LLC

Paul S Carman

D V Satyanarayana Gupta

Madhukar Chetty

Hong Sun

Harold Dean Brannon

Scott Gregory Nelson

Alyssa Michelle Volk

Leiming Li

Jeffrey Carl Dawson

Jia Zhou

Sumit Bhaduri

Harold Gene Hudson

Rupa Venugopal

Dv Satyanarayana Gupta

Frances H DeBenedictis

Thomas Ray Starks, Ii

Magnus Legemah

Ahmed S Zakaria

John Mayor

Michael R Farris

Minh Vo

Johnny Chapman

Jennifer L Cutler

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 fines-fixing agent that has improved compatibility with organic complexed borate fracturing fluids is disclosed. Existing fines fixing agents have a high concentration of unreacted caustic that results in a product pH of approximately 12. This high pH affects the crosslinker and the overall fracturing fluid system stability, promoting precipitation of the organic crosslinker. These effects can be mitigated by neutralizing the fines fixing agents with an acid such as hydrochloric or acetic acid to a pH of 6 or lower.

Fines fixing agent having improved compatibility with organic complexed borate fracturing fluids

A method of servicing a well is disclosed. The method comprises mixing ingredients to form a well servicing fluid. The ingredients comprise (i) at least one surfactant chosen from alcohol ethoxylates, Cto Cprimary alcohols and ethoxylated propoxylated alcohols, (ii) a zwitterionic polymer prepared by inverse emulsion polymerization of at least one monomer Acomprising a betaine group and optionally one or more nonionic monomers B, and (iii) a saline based aqueous solution. The well servicing fluid is introduced into a hydrocarbon well.

Oil field treatment fluids

A hydraulic fracturing process comprises combining an aqueous carrier with a superabsorbent polymer and a plurality of proppant particles to form a fracturing fluid; and disposing the fracturing fluid in a downhole environment. When the aqueous carrier has a total dissolved solid content of equal to or less than 400 parts per million and a hardness of less than 100 parts per million as calcium carbonate, the superabsorbent polymer comprises particles having a size of about 145 microns to about 600 microns. When the aqueous carrier has a total dissolved solid content of greater than 400 parts per million to less than 8,000 parts per million and a hardness of greater than 100 parts per million to less than 2,500 parts per million as calcium carbonate, the superabsorbent polymer comprises particles having a size of about 145 microns to about 300 microns.

Hydraulic fracturing using super absorbent polymer having controlled particle size

A method of hydraulically fracturing a subterranean formation penetrated by a wellbore comprises: providing a diverting fluid comprising a carrier fluid, a first superabsorbent polymer and a second superabsorbent polymer, the second superabsorbent polymer having a shape, or a composition, or a combination thereof different from that of the first superabsorbent polymer; injecting the diverting fluid into the subterranean formation; and injecting a fracturing fluid into the formation after injecting the diverting fluid. A viscosity modifying agent can be present in the diverting fluid. Superabsorbent polymers can also be used to develop a temporary filter cake at the formation face to reduce or eliminate the fluid leakoff out of the wellbore.

Use of superabsorbent polymers for pressure control and diversion applications

A method of fracturing a subterranean formation penetrated by a well comprises: combining an aqueous carrier with a superabsorbent polymer and a borated galactomannan to form a hydraulic fracturing composition; and pumping the hydraulic fracturing composition into the well.

Using borated galactomannan to enhance swelling of superabsorbents for fracturing applications

A gel composition for use in treating subterranean formations is provided. The gel composition is a non-aqueous based oil gel system that can include a hydrocarbon liquid capable of gelation, a phosphate ester, and a cross-linking agent. The gel composition can include the oil gel which results from adding a phosphate ester, a crosslinking agent and a delay additive to the hydrocarbon liquid.

Delay additive for oil gels

A well treatment method includes forming a well treatment fluid by combining ingredients including a polymer, a crosslinker, an acidifying substance, and a base fluid. Crosslinking increases viscosity of the fluid during a development time. A pH decrease is controlled during the development time using the acidifying substance. The method also includes delaying the development time of the viscosity increase by controlling the pH decrease. A well treatment method includes forming a well treatment fluid by combining ingredients including a hydratable polymer, a crosslinker, an acidifying substance, and a base fluid. The method includes delaying development time of a viscosity increase by controlling a pH decrease without adding further acidifying substance after combining the polymer, crosslinker, acidifying substance, and base fluid. A well treatment fluid formulated with ingredients include a base fluid, a polymer, a crosslinker, and an acidifying substance. The acidifying substance is configured to delay development time.

Delayed viscosity well treatment methods and fluids

A fracturing fluid containing a hydratable viscosifying polymer and a zirconium acetylacetonate crosslinker provides a green alternative to conventional systems. The zirconium aceylacetonate is dissolved in benzyl alcohol or in a mixture of benzyl alcohol and 2,2-dimethyl-1,3-dioxolan-4(yl)-methanol. The pH of the fracturing fluid may be between from about 3.5 to about 11.5. The fracturing fluid may contain an acidic buffering agent or a basic buffering agent. The fracturing fluid may be pumped into a well in order to initiate or enlarge a fracture within a subterranean formation penetrated by the well.

Stimulation method using biodegradable zirconium crosslinker

Well treatment fluids and methods of treating high temperature subterranean formations of up to about 500&#xb0; F. (260&#xb0; C.) are provided. The well treatment fluids and methods utilize a high molecular weight synthetic copolymer and a pH buffer than maintains a pH in a range of about 4.5 to about 5.25 for the fluids. The high molecular weight synthetic copolymer is derived from acrylamide, acrylamidomethylpropanesulfonic acid, and vinyl phosphonates. The well treatment fluids may be energized or foamed.

Method of fracturing with phenothiazine stabilizer

The present disclosure is directed to a method comprising: mixing (i) a zwitterionic polymer prepared by inverse emulsion polymerization of at least one monomer Acomprising a betaine group and optionally one or more nonionic monomers B, (ii) a surfactant and (iii) produced water to form a well servicing fluid. The resulting well servicing fluid is introduced into a hydrocarbon well.

Oil field treatment fluids comprising zwitterionic betaine-group-containing polymers

Compositions and methods of treating high temperature subterranean formations of up to about 500&#xb0; F. (260&#xb0; C.) are provided. The compositions and methods utilize a high molecular weight synthetic copolymer and a pH buffer than maintains a pH in a range of about 4.5 to about 5.25 for the compositions. The high molecular weight synthetic copolymer is derived from acrylamide, acrylamidomethylpropanesulfonic acid, and vinyl phosphonate.

The present disclosure is directed to a method comprising introducing into a well bore a fluid comprising a zwitterionic polymer. The polymer is prepared by inverse emulsion polymerization of at least one monomer Acomprising a betaine group and optionally one or more nonionic monomers B. The well bore is chosen from a natural gas well bore and an oil well bore.

Oil field treatment fluids with viscosified brines

The present invention relates to the use of chalcogen heterocyclic electron donating compounds as thermal decomposition reduction additives for gels used in well treatment fluids such as drilling fluids, fracturing fluids, and well completion and workover fluids.

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Spring, TX, United States of America

Paul S Carman