Baker Hughes Corporation

Baker Hughes, a Ge Compnay, LLC

Baker Hughes Holdings LLC

Bj Services Company Canada

Richard S Wheeler

Brian Benedict Beall

Harold Dean Brannon

Brian N Ward

Roger R Myers

Chandler C Newhall

Jeremy Lynn Weinstein

D V Satyanarayana Gupta

Scott Gregory Nelson

Kay Elaine Cawiezel

Bryan Scott Lambert

Brian B Beall

Kay E Cawiezel

D V Gupta

Chandler Newhall

Brian Ward

A well treatment fluid uses ingredients that include an aqueous base, a non-associative, ionic, synthetic polymer, and optionally, at least one metal crosslinker. The polymer contains a backbone and a functional group that hinders hydrolysis of the backbone. The functional group is distributed at intervals on the backbone. A well treatment method includes forming a well treatment fluid by combining ingredients including a non-associative, ionic, synthetic polymer and a first aqueous base. The first fluid exhibits a first viscosity greater than a viscosity of the first aqueous base. The method includes treating a well during a stage using the first fluid exhibiting the first viscosity. A second well treatment fluid is formed by combining ingredients including the polymer, a second aqueous base, and at least one crosslinker and by crosslinking the synthetic polymer. The method includes treating the well during another stage using the second fluid exhibiting the second viscosity.

Well treatment methods and fluids containing synthetic polymer

Disclosed herein is a foamed fracturing fluid comprising a carrier fluid; a polymer that is soluble in the carrier fluid; the polymer being a synthetic polymer, wherein the synthetic polymer comprises a labile group that is operative to facilitate decomposition of the synthetic polymer upon activation of the labile group; a foaming agent; and a gas constituent, the synthetic polymer, foaming agent and gas constituent being operative to increase the viscosity of the carrier fluid to about 50 centipoise or greater at 100 s, the foamed fracturing fluid being operative to reduce friction during a downhole fracturing operation and to transport a proppant during the downhole fracturing operation. A method for treating a hydrocarbon-bearing formation is also disclosed herein.

Foamed fracturing fluids and methods for treating hydrocarbon bearing formations

A hydration system configured to selectively enable a continuous process or a batch process of an additive for a hydraulic fracturing fluid, the hydration system including a hydration tank having a plurality of compartments, wherein the hydration tank is configured to enable movement of a material through the plurality of compartments in the continuous process. The hydration tank is configured to substantially restrict movement of the material between the plurality of compartments in the batch process. Also included is a method of selectively hydrating an additive in a batch process or a continuous process using a hydration system configured to enable both the batch process and the continuous process.

Hydration system for hydrating an additive and method

In a method of hydraulically fracturing a hydrocarbon-bearing subterranean formation, a proppant stage is introduced into the fracture which contains a gaseous fluid and an ultra lightweight proppant suspended in a viscosified aqueous fluid. The gaseous fluid of the proppant stage contains at least about 90 volume percent of the combination of gaseous fluid and aqueous fluid. A pad fluid may first be introduced into the formation, the pad fluid containing a gaseous fluid and, optionally, an aqueous fluid. The gaseous fluid of the pad fluid mixture typically contains at least 70 volume percent of the mixture.

Method of fracturing using ultra lightweight proppant suspensions and gaseous streams

A well treatment fluid contains a viscoelastic surfactant and a viscosification activator. The viscosification activator enhances the viscosity of the well treatment fluid in contrast to a treatment fluid that does not contain a viscosification activator.

Method of treating a well with viscoelastic surfactant and viscosification activator

Methods and compositions of treating formations using viscoelastic treatment fluids are provided that reduce the amount of fluid loss to the formations due to the lack of polymer backbone in the viscoelastic treatment fluids. The methods and compositions of treating formations include a fluid loss additive that includes a copolymer that includes a hydrophilic monomeric unit and a first anchoring monomeric unit.

Methods for reducing fluid loss of a viscoelastic surfactant gel into a subterranean formation

A well treatment method includes drawing a solvent to a first pump, drawing a wetting liquid to a second pump, pumping the wetting liquid through a polymer mixer using the second pump, combining polymer with the wetting liquid to produce a slurry containing undissolved polymer, and combining the slurry with the solvent upstream from the first pump. Another well treatment method includes increasing dissolution time of the polymer by providing a buffering agent in the wetting liquid before combining the wetting liquid and the polymer. A well treatment system includes a polymer mixing subsystem with a mix loop having a mix loop inlet line from a first pump feed line and a mix loop outlet line back to the first pump feed line, the mix loop outlet line containing a polymer mixer.

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Crosby, TX, United States of America

Richard S Wheeler