Abstract: Of the many methods and compositions provided herein, one method includes a method comprising contacting a metal surface with an acidic fluid comprising an aqueous base-fluid, an acid, a corrosion inhibitor, and a corrosion inhibitor intensifier composition comprising a compound that corresponds to a formula R1R2XCCOOH, wherein X is a halogen, R1 comprises at least one group selected from the group consisting of a C1-C20 alkyl group, a C3-C20 cycloalkyl group, a C1-C20 oxyalkyl, and a C6-C20 aryl group, and R2 comprises at least one group selected from the group consisting of a C1-C20 alkyl group, a C3-C20 cycloalkyl group, a C1-C20 oxyalkyl, and a C6-C20 aryl group.

Abstract: Disclosed herein are defoamers comprising ethylene glycol, a defoaming hydrocarbon base fluid, and a non-ionic surfactant wherein the hydrocarbon base fluid comprises an internal olefin or a straight-chain n-alcohol, and wherein the non-ionic surfactant is present in the defoamer in an amount in the range of from about 1% to about 10% by weight of the defoamer. Also disclosed herein are cement compositions comprising water, hydraulic cement, and a defoamer, wherein the defoamer comprises ethylene glycol, a non-ionic surfactant, and a defoaming hydrocarbon base fluid wherein the hydrocarbon base fluid comprises an internal olefin or a straight-chain n-alcohol, and wherein the non-ionic surfactant is present in the defoamer in an amount in the range of from about 1% to about 10% by weight of the defoamer.

Abstract: Cement compositions including environmentally compatible defoamers and methods of using such cement compositions are provided herein. An example of a method is a method of reducing foam generation in a cement composition. An example of a composition is a is a cement composition comprising water, hydraulic cement, and a defoamer.

Abstract: The present invention relates to well bore stabilization and, more particularly, to treatment fluids that may reduce the tendency of shales to swell and associated methods. In some embodiments, the present invention provides a method of stabilizing a subterranean formation that comprises a shale, the method comprising contacting the subterranean formation that comprises the shale with a treatment fluid, the treatment fluid comprising a base fluid, and a hydrophobically modified polymer. In other embodiments, the treatment fluids comprise a base fluid and a hydrophilically modified polymer. In yet other embodiments, the present invention provides shale-inhibiting components, treatment fluids, and methods of reducing the tendency of shale to swell when exposed to a treatment fluid.

Abstract: Methods and compositions that include a method comprising providing a treatment fluid that comprises an aqueous base fluid, a biocide, a biocide enhancer, a friction reducer, and a compatibility aid, and introducing the treatment fluid into a subterranean formation. A composition provided includes a treatment fluid comprising an aqueous base fluid, a biocide, a biocide enhancer, a friction reducer, and a compatibility aid.

Abstract: Provided herein are defoaming agents that comprise lecithin and a solvent. Optionally, they may comprise hydrophobic particles. One embodiment provides a defoaming agent that comprises lecithin and a solvent.

Abstract: Methods and compositions that include a method comprising providing a treatment fluid that comprises an aqueous base fluid, a biocide, a biocide enhancer, a friction reducer, and a compatibility aid, and introducing the treatment fluid into a subterranean formation. A composition provided includes a treatment fluid comprising an aqueous base fluid, a biocide, a biocide enhancer, a friction reducer, and a compatibility aid.

Abstract: Of the many methods and compositions provided herein, one method includes a method comprising contacting a metal surface with an acidic fluid comprising an aqueous base-fluid, an acid, a corrosion inhibitor, and a corrosion inhibitor intensifier composition comprising a compound that corresponds to a formula R1R2XCCOOH, wherein X is a halogen, R1 comprises at least one group selected from the group consisting of a C1-C20 alkyl group, a C3-C20 cycloalkyl group, a C1-C20 oxyalkyl, and a C6-C20 aryl group, and R2 comprises at least one group selected from the group consisting of a C1-C20 alkyl group, a C3-C20 cycloalkyl group, a C1-C20 oxyalkyl, and a C6-C20 aryl group.

Abstract: A method of treating a subterranean formation including with a bactericidal fluid is provided. The method comprises the steps of: (a) continuously mixing to obtain a stream of a treatment fluid: (i) a base fluid comprising water; (ii) an aqueous solution comprising a hypochlorite having a pH equal to or greater than 7; and (iii) a pH-adjusting agent selected to be capable of lowering the pH of water to less than 7; and (b) injecting the treatment fluid into a wellbore. The step of continuously mixing the base fluid, the aqueous solution of hypochlorite, and the pH-adjusting agent is preferably under conditions and in proportions sufficient to obtain a stream of a treatment fluid having a free chlorine concentration of at least 1 ppm by weight of the water in the treatment fluid and having a pH in the range of 4-7.

Abstract: Provided herein are defoaming agents that comprise lecithin and a solvent. Optionally, they may comprise hydrophobic particles. One embodiment provides a method comprising: providing a well fluid that comprises foam; providing a defoaming agent that comprises lecithin and a solvent; and contacting the well fluid with the defoaming agent so that the amount of foam present in the well fluid is reduced.

Abstract: Cement compositions including environmentally compatible defoamers and methods of using such cement compositions are provided herein. An example of a method is a method of cementing in a subterranean formation. Another example of a method is a method of reducing foam generation in a cement composition. An example of a composition is a cement composition including water, hydraulic cement, and a defoamer. Another example of a composition is a defoamer.

Abstract: A composition of matter for use in stablizing shale formations in earth boreholes comprising polymeric products, e.g., polymers of a dialkyl aminoalkyl methacrylate, which can optionally be quaternized with an alkyl halide to produce drilling fluid additives which stablize borehole formations containing reactive clays in the presence of an aqueous medium.

Abstract: Methods of treating subterranean zones and treating fluids are provided. The methods are basically comprised of preparing or providing a subterranean zone treating fluid comprising an aqueous fluid and an additive for preventing the swelling and migration of formation clays in the subterranean zone selected from the group consisting of 1-carboxy-N,N,N-trimethyl methanaminium chloride, 2-hydroxy-N,N,N-trimethyl ethanaminium acetate, and 2-hydroxy-N,N,N-trimethyl 1-propanaminium acetate.

Abstract: Methods of treating subterranean zones and high density viscous aqueous treating fluids are provided. A high density viscous aqueous treating fluid of the invention comprises salt water comprising water and one or more oxidation resistant salts; a gelling agent; and a delayed oxidizing gel breaker.

Abstract: Methods of forming chemical casings include drilling a well bore with a drilling fluid having a pH in the range of from about 6 to 10 and comprising water, a water soluble or water dispersible polymer which is capable of being cross-linked by a thermoset resin and causing the resin to be hard and tough when cured, a particulate curable solid thermoset resin, a water soluble or dispersible thermoset resin, and a delayed dispersible acid-catalyst for curing the solid thermoset resin and the water soluble thermoset resin, whereby the drilling fluid forms a filter cake on the walls of the wellbore that cures into a hard and tough cross-linked chemical casing thereon.

Abstract: Methods of consolidating formations include drilling a well bore with a drilling fluid that comprises water, a polymeric cationic catalyst which is adsorbed on minerals and rocks in weak unconsolidated zones or formations and then further contacting the unconsolidated formation with a treating fluid comprising a water soluble or dispersible polymer which is cross-linked by a thermoset resin and causes the resin to be hard and tough when cured, and a water soluble or dispersible thermoset resin which cross-links the polymer, is catalyzed and cured by the catalyst and consolidates the weak zone or formation so that sloughing is prevented.

Abstract: Methods of consolidating unconsolidated weak zones or formations and forming chemical casings include drilling a well bore with a drilling fluid having a pH in the range of from about 6 to 10 and that comprises water, a polymeric cationic catalyst which is adsorbed on the mineral surfaces in the weak zone, a particulate curable solid thermoset resin and a delay acid catalyst for curing the solid resin, and forming a filter cake on the walls of the well bore. The filter cake is then contacted with a treating fluid comprising a water soluble or water dispersible polymer which is capable of being cross-linked by a thermoset resin and causing the resin to be hard and tough when cured, and a water soluble or dispersible thermoset resin, whereby the treating fluid components deposit on the filter cake and the thermoset resin cures into a hard and tough cross-linked chemical casing thereon.

Abstract: For use in estimating or predicting bioaccumulation of a chemical analyte, even a surfactant, log Pow values for the analyte may be determined by calculating the log of the ratio of the concentrations of the analyte in n-octanol and in water, equilibrated using a slow-stir method. In this method, samples of the analyte are prepared and stirred in n-octanol and water (or other largely immiscible solvents) at a rate sufficiently low to avoid emulsions over time at a constant temperature. After stirring, the n-octanol layer and the water layer are sampled and the quantity of analyte in each measured.

Abstract: For use in estimating or predicting bioaccumulation of a chemical analyte, even a surfactant, log Pow values for the analyte may be determined by calculating the log of the ratio of the concentrations of the analyte in n-octanol and in water, equilibrated using a slow-stir method. In this method, samples of the analyte are prepared and stirred in n-octanol and water (or other largely immiscible solvents) at a rate sufficiently low to avoid emulsions over time at a constant temperature. After stirring, the n-octanol layer and the water layer are sampled and the quantity of analyte in each measured.

Abstract: Methods comprising: providing a test substance, providing two solvents that are substantially immiscible, introducing a known amount of the test substance and known amounts of the two solvents into a single vessel to create a pre-equilibrium sample, adjusting the concentration of the test substance in the pre-equilibrium sample so that the concentration of the test substance is below the critical micelle concentration of both solvents if the concentration of the test substance is not already below the critical micelle concentration, allowing the test substance to equilibrate between the two solvents over time at a substantially constant temperature, determining the equilibrium concentration of the test substance in each of the solvents, and calculating the partition coefficient.