Halliburton Energy Services, Inc.

Other

Billy F Slabaugh

Jimmie Dean Weaver, Jr

Jim D Weaver

Philip D Nguyen

Harold Grayson Walters

Robert E Hanes, Jr

Mark A Parker

Michael A McCabe

John M Terracina

Max Lynn Phillippi

Phillip C Harris

Lyle Lehman

Bradley Leon Todd

Thomas Donovan Welton

Jason E Bryant

Matthew Eric Blauch

Leonard R Case

Stanley J Heath

Ronald J Powell

Bobby K Bowles

Chris E Shuchart

Tommy Slabaugh, Legal Representative

David M Barrick

Trinidad Munoz, Jr

Diederik W Van Batenburg

Joseph G Yaritz

Paul D Lord

Michael J R Segura

Michael Segura

Will E Haley

Ronnie Glen Morgan

Lewis R Norman

Tim H Hunter

Billy Wilson McDaniel

Herbert John Horinek

Neil Alan Stegent

Randy S Rosine

Arron L Karcher

Jonn Thompson

Von Parkey

Donna L Harris

Graeme W Pirie

Jiten Chatterji

Bobby J King

Roger Stanley Cromwell

Calvin Lynn Stegemoeller

Karen L King

Robert S Taylor

Mark D Kalman

Michael L Walker

Mark R Savery

Johnny W Johnson

R Clay Cole

John Michael Wilson

Laurence James Abney

Gerard Glasbergen

Richard L Middaugh

Thomas E Rush

Ottmar F Hoch

Steve F Wilson

Shaun Burns

Robert Eugene Hanes

Gregory L Tanaka

Shaun Bums

Larry Lance Abney

Ron J Powell

Shane L Milson

Philip Duke Nguyen

Calvin L Stegemoeller

Max L Phillippi

Bobby Bowles

Methods are provided that include, but are not limited to, methods of treating guar splits comprising: exposing guar splits to a treatment chemical to create treated guar splits, wherein the treatment chemical comprises at least one treatment chemical selected from the group consisting of: an aqueous salt solution; a caustic solution, and a derivatizing agent; and grinding the treated guar splits to create ground, treated guar splits.

Methods and compositions for enhancing guar hydration rates and performing guar derivatization reactions

A method comprising: providing at least one encaged treatment chemical that comprises a treatment chemical and a polymer carrier; placing the encaged treatment chemical into a portion of a subterranean formation; and allowing the treatment chemical to diffuse out of the encaged treatment chemical and into a portion of the subterranean formation or an area adjacent thereto.

Methods and compositions for delaying the release of treatment chemicals

Methods of forming one or more fractures in a subterranean formation penetrated by a well bore. The methods generally include providing a treating fluid that comprises water and one or more sulfonated gelling agent polymers, wherein the one or more sulfonated gelling agent polymers comprise a sulfonated synthetic polymer selected from the group consisting of sulfonated polyvinyl alcohol, sulfonated polyacrylate, sulfonated polyacrylamide/acrylic acid copolymers, and any combination thereof; and introducing the treating fluid into the subterranean formation. The treating fluid may be placed at a pressure sufficient to create or extend fractures within the subterranean formation.

Methods of fracturing subterranean formations using sulfonated synthetic gelling agent polymers

A wellbore servicing method comprises converting a water into an electrochemically activated water, preparing a wellbore servicing composition comprising the electrochemically activated water, and placing the wellbore servicing composition in a wellbore. Also, a cement composition comprises a cement and an electrochemically activated water.

Method for wellbore servicing to enhance the mechanical strength of cement using electrochemically activated water

Methods and compositions for enhancing guar hydration rates and performing guar derivitization reactions

Methods of forming one or more fractures in a subterranean formation penetrated by a well bore including the steps of providing a high ionic strength treating fluid that comprises water and one or more sulfonated gelling agent polymers wherein the high ionic strength treating fluid comprises one or more water soluble salts in a concentration of greater than about 8% by weight of the treating fluid, and introducing the treating fluid into the subterranean formation at a rate and pressure sufficient to create or enhance one or more fractures therein.

Methods of fracturing subterranean formations using sulfonated gelling agent polymers

Treatment fluids comprising gelling agents that comprise crosslinkable polymers and certain biopolymers, and methods of use in subterranean operations, are provided. In one embodiment, the present invention provides a treatment fluid comprising: an aqueous base fluid; a crosslinking agent; and a gelling agent comprising a polymer that is a crosslinkable polymer, and a polymer that is a biopolymer wherein a molecule of the biopolymer (1) consists only of glucose, or (2) has a backbone comprising one or more units that comprise at least (a) one glucose unit and (b) one linear or cyclic pyranose-type monosaccharide unit, wherein (a) and (b) have different molecular structures.

Polymer mixtures for crosslinked fluids

A system is provided that includes: (a) a mobile platform; (b) an input pump operatively connected to be capable of pumping a treatment stream through the system; (c) a centrifugal separator operatively connected downstream of the input pump to centrifugally treat the treatment stream; (d) a borate filter operatively connected downstream of the centrifugal separator to filter the treatment stream capable of removing at least some of a borate when the treatment stream is at a pH of 8 or above; and (e) a chemical-additive subsystem operatively connected to be capable of: (i) selectively adding one or more chemical agents to the treatment stream upstream of the centrifugal separator, wherein the chemical agents can be selected to be capable of precipitating dissolved ions selected from the group consisting of: sulfate, calcium, strontium, or barium, magnesium, iron; and (ii) selectively adding a chemical agent to the treatment stream upstream of the borate filter to increase the pH of the treatment stream to 8 or above.

Mobile systems and methods of sufficiently treating water so that the treated water may be utilized in well-treatment operations

A method is provided for treating at least a portion of a well. The method includes the steps of: (a) simultaneously introducing into a mixer at least: (i) a first stream comprising water; (ii) a second stream comprising a dry, hydratable, viscosity-increasing agent for water, wherein the second stream is substantially free of water; and (iii) a third stream comprising a non-hydratable, insoluble particulate; wherein at least the first and second streams are not mixed prior to being introduced into the mixer; (b) mixing the first, second, and third streams in the mixer to form a pumpable mixture, wherein: (i) the mixer creates at least a sufficiently-high shear rate to disperse the viscosity-increasing agent and the insoluble particulate in the pumpable mixture; and (ii) the pumpable mixture has or is capable of developing a substantially-higher viscosity than the viscosity of the first stream; and (c) introducing a treatment fluid comprising the pumpable mixture into a wellbore.

Methods for treating a well by simultaneously introducing into a mixer streams of water, a viscosity-increasing agent, and a particulate and introducing the mixture into the well

Methods comprising: providing a consolidating agent emulsion composition that comprises an aqueous fluid, a surfactant, and a consolidating agent; and coating at least a plurality of particulates with the consolidating agent emulsion to produce a plurality of consolidating agent emulsion coated particulates. Methods comprising: providing a treatment fluid comprising a consolidating agent emulsion comprising an aqueous fluid, an amine surfactant, and a consolidating agent; and introducing the treatment fluid into a subterranean formation. Methods comprising the steps of: coating a plurality of particulates with a consolidating agent emulsion to produce consolidating agent emulsion coated particulates; providing a treatment fluid comprising an aqueous fluid, a surfactant, and a consolidating agent; introducing the treatment fluid into a subterranean formation. Consolidating agent emulsion compositions comprising: an aqueous fluid; a surfactant; and a consolidating agent comprising a non-aqueous tackifying agent or resin.

Consolidating agent emulsions and associated methods

The invention provides a method of treating a subterranean formation penetrated by a wellbore, the method comprising the steps of: (a) mixing a particulate and an active material to obtain an at least partially coated particulate, wherein: (i) water forms a contact angle of less than 90 degrees with a surface of the particulate, (ii) the active material is capable of forming a coating on the particulate, (iii) the active material forms a contact angle less than 90 degrees with the particulate, and (iv) water forms a contact angle of greater than 90 degrees with a layer of the active material; (b) mixing the at least partially coated particulate and a carrier fluid to obtain a treatment fluid; and (c) introducing the treatment fluid into the subterranean formation through the wellbore to deposit the at least partially coated particulate into the subterranean formation.

Methods to increase recovery of treatment fluid following stimulation of a subterranean formation comprising cationic surfactant coated particles

In one embodiment, the present invention provides a method of increasing the viscosity of a treatment fluid comprising the steps of: adding a networking agent to the treatment fluid, wherein the networking agent is represented by the formula: Y&#x2014;X&#x2014;[B(OR)2]n, wherein: Y is at least partially capable of forming a crosslink between a gelling agent molecule, a second networking agent, and/or a combination thereof; X is at least partially capable of preventing or inhibiting a reaction represented by the formula: ROH+R'B(OR)2&#x2192;R&#x2032;OH+B(OR)3; R and R&#x2032; are a hydrogen, an alkyl group, an aryl group, or a combination thereof; and n is a positive integer greater than or equal to 1; allowing at least one crosslink to form between the networking agent and a gelling agent molecule, a second networking agent, and/or a combination thereof; and allowing the viscosity of the treatment fluid to increase. Methods of treating a portion of a subterranean formation, networking agent compositions, and treatment fluid compositions also are provided.

Boronic acid networking agents and associated methods

A hydrocarbon industry servicing fluid comprises an irradiated fluid that is biologically inert. The fluid may be irradiated with ultraviolet light. A method comprises performing a hydrocarbon industry service operation with an irradiated fluid that is biologically inert. The method may comprise disposing of the irradiated fluid to the environment or capturing the irradiated fluid when the service operation is complete. The method may further comprise re-irradiating the captured irradiated fluid to produce a remediated fluid, and performing a service operation with the remediated fluid.

Hydrocarbon industry servicing fluid and methods of performing service operations

Growing community of inventors

Duncan, OK, United States of America

Billy F Slabaugh