Halliburton Energy Services, Inc.

Princeton University

Danait, Achala V.

Salgaonkar, Lalit P.

Robb, Ian D.

Ian D Robb

Richard W Pauls

Thomas Donovan Welton

Jason E Bryant

David L Carbajal

Dale E Jamison

Jeff Kirsner

Don Siems

Kimberly Burrows-Lawson

B Raghava Reddy

Bradley Leon Todd

Phillip D Nguyen

Sherry Gale Gaskins

Jimmie Dean Weaver, Jr

Lulu Song

Frank Zamora

Richard Dale Rickman

Alexander Bismarck

Ronney R Koch

Sears T Dealy

Keith A Frost

Joe M Sandy

Diptabhas Sarkar

Bobby J Burns

Sean R Beach

Mike A Bajomo

Joachim Steinke

Jiten Chatterji

Bobby J King

Rajesh Kumar Saini

William Walter Shumway

Ronnie Glen Morgan

Robert K Prud'homme

David Eugene McMechan

Lewis R Norman

Douglas H Adamson

Karen L King

Frank Zamora, Jr

J Michael Wilson

Ronald J Powell

Benjamin John Iverson

Narongsak Tonmukayakul

Eric Davidson

Lalit Pandurang Salgaonkar

O Marlene Isenberg

Achala Vasudev Danait

Stephen T Arrington

Arron L Karcher

Keith Douglas Pewitt

Kenneth W Oyler

Michael L Carter

Mustafa Erhan Yildiz

Rob E Hanes, Jr

James M Griffin

Jimmy D Weaver

Bairreddy Raghava Reddy

Philip Duke Nguyen

Michael Bajomo

A method of servicing a wellbore comprising contacting a wellbore servicing composition with a rheology modifying additive wherein the rheology modifying additive comprises a gum and a polymeric material. A method of cementing in a subterranean formation comprising providing a sealant composition comprising cement, water, and a rheology modifying additive wherein the rheology modifying additive comprises a gum and an anionic polymer, placing the composition in the subterranean formation, and allowing the cement composition to set therein.

Compositions for modifying rheological properties of cement systems

According to one aspect of the inventions, emulsion compositions are provided. Emulsions according to this aspect include: (a) a water-insoluble resinous material; (b) water; and (c) an emulsifier, wherein the emulsifier comprises a non-ionic, a cationic, or a zwitterionic emulsifier; wherein the continuous phase of the emulsion comprises the water; wherein a dispersed phase of the emulsion comprises the resinous material; wherein the dispersed phase is in the form of droplets having a size distribution range such that at least 50% of the droplets have a size of 0.5 micrometers-500 micrometers; wherein the resinous material of the droplets is in a concentration of at least 5% by weight of the water; and wherein the composition of the droplets has a viscosity of less than 2,000 Poise measured at 20&#xb0; F. According to another aspect of the inventions, methods are provided for treating a portion of a subterranean formation. Methods according to this aspect include the steps of: (a) forming an emulsion according to the composition described above; and (b) introducing the emulsion into a portion of a subterranean formation.

Stabilization of emulsions containing resinous material for use in the field of oil or gas well treatments

A persulfate compound activated by a strong base is used for low-temperature breaking of fluids viscosified with a multi-chain polysaccharide. The breaker system can be used in an oilfield or pipeline application where a multi-chain polysaccharide may be used in a fluid. It is particularly useful at low temperatures of less than 100&#xb0; F. Optionally, the water can be a brine.

Alkaline persulfate for low-temperature breaking of multi-chain polymer viscosified fluid

Methods for oil and/or gas production may employ mixed surfactants to treat a subterranean formation. The methods can comprise: providing a treatment fluid comprising: an aqueous base fluid, a first surfactant having a charge, a second surfactant having an opposite charge, and a compatibilizer; and introducing the treatment fluid into at least a portion of the subterranean formation.

Treatment fluids for wetting control of multiple rock types and associated methods

Improved treatment fluids and methods for use in subterranean operations including the treatment of low permeability shale formations. In one embodiment the methods comprise: providing a treatment fluid comprising an aqueous base fluid and a controlled wetting system that comprises: a water soluble polymer having a charge, a surfactant having an opposite charge, and a compatibilizer; and introducing the treatment fluid into a subterranean formation.

Surfactants and friction reducing polymers for the reduction of water blocks and gas condensates and associated methods

A method including the steps of: (a) providing a dispersion comprising: a water-soluble polysaccharide and a carrier fluid, wherein the carrier fluid comprises: (i) glycerol, and (ii) a mono-hydroxylic alcohol having 1-3 carbons, wherein the mono-hydroxylic alcohol is present in at least 0.1% by weight of the glycerol, wherein the polysaccharide is insoluble in the carrier fluid; (b) mixing the dispersion with at least water to form an aqueous well treatment fluid, wherein the polysaccharide is soluble in the aqueous phase of the aqueous wellbore treatment fluid; and (c) introducing the aqueous treatment fluid into a subterranean formation.

Delivering water-soluble polysaccharides for well treatments

Emulsions for use in a well including: (a) a water-insoluble resinous material; (b) water; and (c) an emulsifier, wherein the emulsifier comprises a non-ionic, a cationic, or a zwitterionic emulsifier; wherein the continuous phase of the emulsion comprises the water; wherein a dispersed phase of the emulsion comprises the resinous material; wherein the dispersed phase is in the form of droplets having a size distribution range such that at least 50% of the droplets have a size of 0.5 micrometers-500 micrometers; wherein the resinous material of the droplets is in a concentration of at least 5% by weight of the water; and wherein the composition of the droplets has a viscosity of less than 2,000 Poise measured at 20&#xb0; F. Methods include the steps of: (a) forming an emulsion described above; and (b) introducing the emulsion into a portion of a subterranean formation.

Methods and compositions for breaking treatment fluids utilized in the stimulation of a subterranean formation.

Methods and compositions for treating subterranean zones

Of the many methods and compositions provided herein, in one embodiment, the invention provides a method comprising: providing an oil-wet well bore surface; providing a surfactant wash treatment fluid that comprises an acid-compatible surfactant, an acid and/or an acid-generating component, and an aqueous fluid; contacting the oil-wet well bore surface with the surfactant wash treatment fluid; allowing the oil-wet well bore surface to become water-wet; and producing fluids from the formation. In another embodiment, the invention provides a surfactant wash treatment fluid for use in a subterranean formation comprising an aqueous fluid, an acid-compatible surfactant, an acid and/or an acid-generating component.

Surfactant wash treatment fluids and associated methods

The invention provides a method for treating a subterranean formation penetrated by a wellbore, the method comprising the steps of formulating a treatment fluid and introducing the treatment fluid through the wellbore. The treatment fluid comprises water; diutan; and a sufficient amount of salt to increase the density of the treatment fluid to at least 8.5 lb/gal, wherein at least 50% by weight of the salt is selected from the group consisting of: bromide salts, non-bromide salts having a higher salting-in effect than bromide according to the Hofmeister series as measured by the salt's effect on the cloud point of poly(ethylene oxide) that has a molecular weight of 4&#xd7;10, and any combination in any proportion thereof. The invention also provides a treatment fluid for use in a subterranean formation penetrated by a wellbore, the treatment fluid comprising: water; diutan; and a sufficient amount of salt to increase the density of the treatment fluid to at least 8.5 lb/gal, wherein at least 50% by weight of the salt is selected from the group consisting of: bromide salts, non-bromide salts having a higher salting-in effect than bromide according to the Hofmeister series as measured by the salt's effect on the cloud point of poly(ethylene oxide) that has a molecular weight of 4.10, and any combination in any proportion thereof.

Viscosified treatment fluids comprising scleroglucan or diutan and associated methods

Methods are provided that include a method comprising providing a acidic treatment fluid that comprises a base fluid, an acid composition, and a gelling agent that comprises clarified diutan; and introducing the acidic treatment fluid into at least a portion of a subterranean formation. In some embodiments, the acidic treatment fluid may be allowed to interact with a component of the subterranean formation so that the component is at least partially dissolved. In some embodiments, the acidic treatment fluid may be introduced into a pipeline. Additional methods are also provided.

Treatment fluids comprising diutan and associated methods

Methods for treating a portion of a well include the steps of: (a) forming a treatment gel comprising a polymer or a polymer system of a mixture of two or more polymers, wherein the polymer or the polymer system is capable of each of the following, when tested at at least one concentration in the range of 2-10 times C* in deionized water, at about 22&#xb0; C., and at about 1 atmosphere pressure: (i) forming a polymer gel of the polymer and water at at least one pH in the range of 4-9, wherein a bulk form of the polymer gel has a G' greater than G&#x2033; at all frequencies in the range of 1 rad/sec-100 rad/sec; (ii) dissolving at at least one pH in the range of 2-4; and (iii) dissolving at at least one pH in the range of 9-12; (b) dispersing the treatment gel in a fluid to form a treatment fluid; (c) introducing the treatment gel in a treatment fluid into a portion of a well; and (d) after the step of introducing the treatment gel, adjusting the pH of the treatment gel to at least one pH in the range of 2-4 or 9-12.

Methods of treating a portion of a well with a polymer or polymer system capable of forming a gel that dissolves at a low and high pH

Methods for treating a portion of a well include the steps of: (a) forming a treatment gel comprising a polymer or a polymer system of a mixture of two or more polymers, wherein the polymer or the polymer system is capable of each of the following, when tested at least one concentration in the range of 2-10 times C* in deionized water, at about 22&#xb0; C., and at about 1 atmosphere pressure: (i) forming a polymer gel of the polymer and water at least one pH in the range of 4-9, wherein a bulk form of the polymer gel has a G' greater than G&#x2033; at all frequencies in the range of 1 rad/sec-100 rad/sec; (ii) dissolving at least one pH in the range of 2-4; and (iii) dissolving at least one pH in the range of 9-12; (b) dispersing the treatment gel in a fluid to form a treatment fluid; (c) introducing the treatment gel in a treatment fluid into a portion of a well; and (d) after the step of introducing the treatment gel, adjusting the pH of the treatment gel to at least one pH in the range of 2-4 or 9-12.

Growing community of inventors

Duncan, OK, United States of America

Ian D Robb