Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

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

Abstract: 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° 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° F. to about 525° F.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

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

Abstract: 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.

Abstract: 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° 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° F. to about 525° F.

Abstract: 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.

Abstract: Methods and cement compositions are provided for sealing a subterranean zone penetrated by a wellbore, wherein the cement composition comprises zeolite, cementitious material, and a mixing fluid.

Abstract: Methods for cementing in a subterranean zone, which use a cement composition that includes zeolite, cementitious material, proportioned fluid loss control additives and a mixing fluid. Cement compositions containing proportioned fluid loss control additives, and methods of making cement compositions containing proportioned fluid loss control additives.

Abstract: Zeolite compositions having a low maximum setting temperature for use in permafrost and waterwell applications are provided.