Halliburton Energy Services, Inc.

Russell M Fitzgerald

B Raghava Reddy

Ronald J Crook

Karen Luke

Dennis Willie Gray

Ashok K Santra

James Frank Heathman

Ronald Earl Sweatman

Frank Zamora

Keith A Rispler

Glen Clifford Fyten

Bradley Leon Todd

Donald Getzlaf

Bryan K Waugh

Anindya Ghosh

Steven B Laramay

Feng Liang

Sam Jason Lewis

Frank Zamora, Jr

Robert S Taylor

Sears T Dealy

Rita J McKinley

Glen C Fyten

Donald A Getzlaf

Jiten Chatterji

Bobby J King

David D Onan

Ronald J Powell

David Leon Meadows

Johnny W Johnson

Joe M Sandy

Brent E Traxel

A dry, free-flowing cement composition that comprises dry cement particles and flow inducing particulates that comprise solid adsorbent particulates having adsorbed thereon a flow inducing chemical, ethylene glycol, and water. The water is present in an amount from 5% to 30.3% by weight of the solid adsorbent particulates, the ethylene glycol is present in an amount from 3.25 to 20% by weight of the solid adsorbent particulates, and the flow inducing particulate is present in an amount from 0.005% to 5% by weight of the cement. The dry, free-flowing cement composition is free-flowing at temperatures at least as low as 10&#xb0; F.

Particulate flow enhancing additives and associated methods

Compositions that may improve the flow properties of dry particulate cementitious and non-cementitious materials, and methods of synthesis and use, are provided. In one embodiment, the methods may comprise providing a flow enhancing additive comprising a flow inducing chemical, a solid adsorbent particulate material, ethylene glycol, and water; providing a cementitious material, a non-cementitious material, or a mixture of cementitious and non-cementitious material; and blending the flow enhancing additive with the cementitious material, the non-cementitious material, or the mixture of cementitious and non-cementitious material.

A composition comprising a carboxylated, sulfonated polysaccharide and a wellbore servicing fluid. A wellbore servicing composition comprising a hydraulic cement and a carboxylated, sulfonated polysaccharide. A wellbore servicing composition comprising a polysaccharide having carboxylate and sulfonate groups.

Polysaccharide based cement additives

A method of servicing a wellbore comprising introducing to the wellbore a wellbore servicing fluid comprising an additive composition comprising a polysaccharide having carboxylate and sulfonate groups. A method of servicing a wellbore comprising preparing at the well site an additive composition comprising a polysaccharide having carboxylate and sulfonate groups, introducing the additive composition into a wellbore servicing fluid, and placing the wellbore servicing fluid into a subterranean formation. A method of preparing a wellbore servicing fluid comprising contacting a polysaccharide composition with an oxidizing agent to form an oxidized polysaccharide, and contacting the oxidized polysaccharide with a sulfonating agent to form a carboxylated sulfonated polysaccharide, and contacting the carboxylated sulfonated polysaccharide with a wellbore servicing fluid.

Methods of using polysaccharide based cement additives

A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising cement, water and a polyuronide polymer, placing the wellbore servicing fluid in the wellbore, and allowing the wellbore servicing fluid to set. A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a highly methylated pectin, cementitious material and water into the wellbore, placing the wellbore servicing fluid in the wellbore, and allowing the wellbore servicing fluid to set. A wellbore servicing fluid comprising cement, water and a polyuronide polymer.

Wellbore servicing compositions and methods of making and using same

A method of servicing a wellbore comprising placing in the wellbore a composition comprising a non-API compliant reactive calcium silicate based hydraulic binder and at least one gelation inhibiting retarder, and allowing the composition to set. A method of servicing a wellbore comprising placing in a wellbore a cement composition comprising an industrial waste product selected from the group consisting of Class C Fly ash, cement kiln dust, and combinations thereof and a gelation inhibitor, and allowing the composition to set. A method of controlling the thickening time of a cementitious composition comprising contacting a material having greater than 15 wt. % of tricalcium aluminate and tetracalcium aluminoferrite with a gelation inhibitor comprising a alkylbenzene sulfonic acid, at least one methallyl sulfonic acid monomer; at least one copolymerizable nonionic monomer, and at least one copolymerizable olefinically unsaturated carboxylic acid monomer.

Gelation inhibiting retarders for highly reactive calcium silicate based binder compositions and methods of making and using same

A method of servicing a wellbore comprising placing a wellbore servicing fluid comprising a density segregation inhibitor composite into the wellbore, wherein the density segregation inhibitor composite comprises a high density additive and a low density additive; and wherein the high density additive comprises barium sulfate, iron oxide, manganese oxide, or combinations thereof. A method of inhibiting segregation of particles in a wellbore servicing fluid comprising preparing a composite material comprising a high density additive and a low density additive, wherein the low density additive comprises an elastomer which can increase in volume by greater than about 300% based on its original volume when contacted with a fluid.

Wellbore servicing compositions comprising a density segregation inhibiting composite and methods of making and using same

Methods and compositions for wellbore treating fluids that include zeolite and at least one carrier fluid.

Zeolite-containing remedial compositions

Cement compositions may comprise one or more secondary amines substituted with a carboxyl group or salts thereof (e.g., 3-hydroxy N,N'-iminodisuccinic acid) for retarding the setting of such compositions. The inclusion of such materials in cement compositions may be highly beneficial. In wellbores having BHCT's of less than or equal to about 250&#xb0; F., the use of the secondary amine as the set retarder ensures that the thickening time of the cement composition is sufficient to allow the cement composition to be pumped to its desired downhole location. Further, the secondary amine may be used in combination with conventional set retarders to enhance the ability of those retarders to increase the thickening time of the cement composition at higher BHCT's, e.g., from about 250&#xb0; F. to about 525&#xb0; F.

Cement compositions comprising biodegradable monomers for retarding the setting thereof

A method of servicing a wellbore comprising placing a cement composition comprising a cementitious material, water, and an elastomeric material comprising a bonding polar group into a wellbore, and allowing the cement composition to set to form a set cement, wherein the elastomeric material has a phase transition temperature, exhibits cold flow behavior, or both at less than or equal to the bottom hole static temperature of the wellbore. A method of servicing a cased wellbore penetrating a formation, comprising introducing a self-repairing cementitious material into a wellbore, and allowing the cement to set, wherein upon a loss of structural integrity the set cement self-repairs, and wherein the loss of structural integrity comprises the formation of flow pathways for fluid migration in the cement and self-repair comprises obstructing potential pathways for fluid migration.

Self repairing cement compositions and methods of using same

A wellbore may be cemented by preparing a cementitious composition comprising water, a metal oxide or hydroxide compound, a phosphate compound, a borate compound, and a sugar, followed by displacing the cementitious composition into the wellbore. The metal oxide or hydroxide compound reacts with the phosphate compound in the wellbore to set into a hard mass. The synergistic effect of the borate compound and the sugar may increase a thickening time of the cementitious composition to in a range of from about 2 hours to about 11 hours at ambient temperatures in the wellbore. As such, the thickening time is sufficient to allow the cementitious composition to be placed in its desired location in the wellbore before setting.

Methods of increasing the thickening times of phosphate-based cementitious compositions in high-temperature wellbores

Methods and compositions for cementing, especially drilling fluids that comprise zeolite and a carrier fluid, and cementing compositions made with such drilling fluids.

Drilling and cementing with fluids containing zeolite

A method of servicing a wellbore that penetrates a subterranean formation includes displacing a cement composition comprising an aromatic sulfonated polymer into the wellbore and allowing the cement composition to set. In an embodiment, a transition time of the cement composition is less than or equal to about 60 minutes, alternatively less than or equal to about 50 minutes, less than or equal to about 40 minutes, less than or equal to about 30 minutes, less than or equal to about 20 minutes, or less than or equal to about 10 minutes. Thus, the transition time may be short enough to inhibit a substantial amount of gas migration into the cement composition before it sets. In yet another embodiment, the cement composition exhibits a viscosity that increases from a value of 35 Bc (Bearden units) to about 100 Bc in about 10 minutes or less when the cement composition sets.

Cement compositions comprising aromatic sulfonated polymers and methods of using the same

Methods of retarding the setting of a cement composition comprise including one or more secondary amines substituted with a carboxyl group or salts thereof (e.g., 3-hydroxy N,N'-iminodisuccinic acid) in the cement composition. The inclusion of such materials in cement compositions may be highly beneficial. In wellbores having BHCT's of less than or equal to about 250&#xb0; F., the use of the secondary amine as the set retarder ensures that the thickening time of the cement composition is sufficient to allow the cement composition to be pumped to its desired downhole location. Further, the secondary amine may be used in combination with conventional set retarders to enhance the ability of those retarders to increase the thickening time of the cement composition at higher BHCT's, e.g., from about 250&#xb0; F. to about 525&#xb0; F.

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Velma, OK, United States of America

Russell M Fitzgerald