Baker Hughes Corporation

Bj Services Company

Baker Hughes, a Ge Compnay, LLC

Rhodia Operations

Other

Bj Services Company, U.s.a.

Energy Solutions (us) LLC

Baker Hughes Holdings LLC

Energysolutions, LLC

Qi Qu

Hong Sun

Xiaolan Wang

Hoang Van Le

Naima Bestaoui-Spurr

Sumit Bhaduri

Terry D Monroe

Scott Gregory Nelson

Jia Zhou

Charles David Armstrong

Paul H Javora

Mingjie Ke

Richard F Stevens, Jr

Kimberly Spurlock Lant

Thomas Jason Pisklak

Jian Zhou

Brian Benedict Beall

Frances De Benedictis

David Alleman

Leiming Li

Mark Alan Vorderbruggen

Russell L Maharidge

Michael Guerin

James B Crews

Subramanian Kesavan

Genyao Lin

Frances H DeBenedictis

Elizabeth G Morillo

Christopher John Stephenson

Sandra L Berry

Rupa Venugopal

Ahmed M Gomaa

Magnus Legemah

Lingjuan Shen

Jerry Edwin Pardue

Changmin Jung

Cristian A Lopez

Shaopeng Zhang

D V Satyanarayana Gupta

Harold Dean Brannon

Jeffrey Carl Dawson

Lirio Quintero

Arnaud Cadix

David James Wilson

Marek K Pakulski

Dong Shen

Joel Lynn Boles

Ruela Talingting Pabalan

Harold Gene Hudson

Daniel Patrick Vollmer

Prasad D Dhulipala

Zhihua Zhang

Scott M McCarthy

Stanley Gunawan

Rose Ndong

Dora V Galvan

Gianna Pietrangeli

Tom N Royce

Zhenxing Cheng

Ted B Reed

Jihye Kim

Igor Pimkov

Chang Min Jung

Richard F Stevens

Bharath Rajappa

Thomas J Pislak

Mark A Vorderburggen

C Vipulanandan

Mark H Houston

Brian B Beall

Frances Debenedictis

Mark Allan Vorderburggen

Richard (deceased) Stevens

Ruela Pabalan

Water-in-oil emulsions are provided that include an alkyl propylene diamine and an ethoxylated alcohol as the inverting surfactant, which is present in an amount less than 5 percent by weight of the water-in-oil emulsion.

Inverting surfactants for inverse emulsions

Compositions and methods for fracturing a subterranean formation are presented. Also provided are compositions and methods for reducing friction-related losses in a well treatment fluid. In general, the compositions include a copolymer that includes one or more vinylphosphonic acid ('VPA') monomers.

Polymer blends for stimulation of oil and gas wells

Provided herein, inter alia, are polymeric compositions and systems useful for maintaining particle dispersions for extended periods of time. Also provided are dry polymeric compositions and systems that are able to undergo fast hydration. Methods for using such compositions and systems are also provided.

Polymer compositions having fast hydration rate and use of the same for particle suspension

Polymeric systems useful for maintaining particle dispersions for extended periods of time.

Polymeric systems for particle dispersion

Recovery of fluids from a subterranean formation during a well treatment operation is enhanced by injecting into the formation a treatment fluid comprising a sophorolipid.

Method of using Sophorolipids in well treatment operations

The complexity of a fracture network within a subterranean formation may be enhanced by pumping a high breakdown pressure fluid followed by a low breakdown pressure fluid into the formation. The method increases the Stimulated Reservoir Volume (SRV) of the formation and provides for a network of ancillary fractures within the formation.

Method of enhancing the complexity of a fracture network within a subterranean formation

Fouling caused by contaminants onto a metallic tubular, flow conduit or vessel in an underground reservoir or extending from or to an underground reservoir may be inhibited by applying onto the surface of the metallic tubular, flow conduit or vessel a treatment agent comprising a hydrophobic tail and an anchor. The anchor attaches the treatment agent onto the surface of the metallic tubular, flow conduit or vessel.

Method of inhibiting deposition of contaminants onto a metallic surface with a surface modifying treatment agent

A well treatment fluid contains a surface modifying treatment agent having an anchor and a hydrophobic tail. The surface modifying treatment agent is an organophosphorus acid derivative. After the well treatment fluid is pumped into a well penetrating the subterranean formation, the anchor binds to the surface of the formation. The subterranean formation is a siliceous formation or a metal oxide-containing subterranean formation. The anchor bonds to a Si atom when the formation is a siliceous formation and to the metal of the metal oxide when the formation is a metal oxide-containing formation. After being bound to the surface of the formation, frictional drag within the well is reduced. This allows for faster recovery of formation fluids. The bonding of the surface modifying treatment agent onto the formation may further be enhanced by first pre-treating the formation with a non-aqueous fluid. By increasing the number of sites for the surface modifying treatment agent to bind onto the surface of the subterranean formation, productivity is improved.

Method of using surface modifying treatment agents to treat subterranean formations

A composite having a solid particulate and a surface modifying treatment agent on the solid particulate wherein the surface modifying treatment agent has a hydrophobic tail and an anchor for adhering the hydrophobic tail onto the solid particulate. The anchor is an organophosphorus acid derivative. The composite may be used as a proppant in a hydraulic fracturing operation as well as a sand control particulate in a gravel packing operation. The presence of the surface modifying treatment agent on the surface of the solid particulate reduces the generation of fines and dust as well as the migration of sand during a hydraulic fracturing operation or a sand control operation. The presence of the surface modifying treatment agent on the surface of the solid particulate further enhances the crush resistance of the solid particulate.

Organophosphorus containing composites for use in well treatment operations

A well treatment fluid contains a surface modifying treatment agent having an anchor and a hydrophobic tail. The surface modifying treatment agent is an organophosphorus acid derivative. After the well treatment fluid is pumped into a well penetrating the subterranean formation, the anchor binds to the surface of the formation. The subterranean formation is a siliceous formation or a metal oxide-containing subterranean formation. The anchor bonds to a Si atom when the formation is a siliceous formation and to the metal of the metal oxide when the formation is a metal oxide-containing formation. After being bound to the surface of the formation, frictional drag within the well is reduced. This allows for faster recovery of formation fluids. The bonding of the surface modifying treatment agent onto the formation may further be enhanced by first pre-treating the formation with an aqueous fluid. By increasing the number of sites for the surface modifying treatment agent to bind onto the surface of the subterranean formation, productivity is improved.

Method of pumping aqueous fluid containing surface modifying treatment agent into a well

A method of fracturing a subterranean formation penetrated by a well comprises: forming a fracturing composition comprising a carrier fluid; and a superabsorbent polymer component comprising one or more of the following: a first composite of a proppant and a first superabsorbent polymer in an unhydrated form, the first superabsorbent polymer being at least partially embedded in a void area of the proppant; a coated superabsorbent polymer; a superabsorbent material having a three-dimensional network; or a second composite of a second superabsorbent polymer and a slow-release breaker; and pumping the hydraulic fracturing composition into the subterranean formation to create or enlarge a fracture.

Fracturing fluids and methods of treating hydrocarbon formations

An embodiment of a method of evaluating fluid trapping in an earth formation includes injecting a water-based fluid into at least one fluid channel fabricated on a substrate, the at least one fluid channel having a pore structure configured to represent a condition of an earth formation. The method also includes injecting oil into an inlet of the at least one fluid channel until at least a selected amount of the injected oil exits the channel, imaging the fluid channel and determining an amount of remaining fluid in the fluid channel after injection of the oil, the remaining fluid being an amount of the oil and/or an amount of the water-based fluid, and estimating a proportion of the total volume of the fluid channel occupied by the remaining fluid to determine an amount of fluid trapping in the pore structure. The method further includes analyzing the amount of fluid trapping.

Fluid blocking analysis and chemical evalution

Scales are prevented or inhibited from forming in a well or in a formation penetrated by a well by pumping into the well a fluid comprising a hydratable polymer, a crosslinking agent, such as an organometallic crosslinking agent containing a polyvalent metal and a scale inhibitor selected from the group consisting of polyvinyl sulfonates, a polyacrylamidomethylpropane sulfonic acid, carboxymethyl inulin and sulfonated polyacrylates and mixtures thereof.

Method for enhancing productivity of hydrocarbon formations using fluid containing organometallic crosslinking agent and scale inhibitor

Methods of using a clay stabilizing agent to inhibit swelling and/or migration of clay subterranean materials upon exposure to water, wherein the clay stabilizing agent is selected from quaternary ammonium salts according to Formula I, Formula II, Formula III, Formula IV, Formula V, and combinations thereof.

Clay stabilizing and methods of use with quaternary ammonium salts

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Qi Qu