Abstract: The disclosed compositions and methods utilize hydrophilic polymers modified by the incorporation of one or more hydrophilic side groups. The polymers may exhibit physical association in solution at a specific temperature so as to provide a significant increase in viscosity at the specific temperature. The viscosity of such systems is substantially increased by the further inclusion of one or more hydrophilic components that may exhibit physical association in solution at one or more temperature trigger points and also associate with the one or more hydrophilic polymers modified by the incorporation of one or more hydrophilic side groups.

Abstract: A method for treating a wellbore tubular or subsurface completion equipment to help remove scale is provided. In general, the method comprises the steps of: (A) determining the likelihood of the presence of carbonate scale in the wellbore tubular or subsurface completion equipment; (B) forming or providing a treatment fluid comprising: (i) water; (ii) a chelating agent capable of forming a heterocyclic ring that contains a metal ion attached to at least two nonmetal ions; and (iii) a viscosity-increasing agent; and (C) introducing the treatment fluid into the wellbore tubular or the subsurface completion equipment.

Abstract: The lubricity of a drilling fluid or a completion fluid may be increased by incorporating into the fluid a water-soluble or water-dispersible salt of a sulfonated (sulfated) vegetable oil or a derivative thereof, such as a sulfonated (sulfated) castor oil. Suitable derivatives include the sodium, potassium, calcium, magnesium or ammonium salt. A non-ionic or anionic surfactant which is capable of enhancing the solubility of the salt may further be incorporated into the drilling fluid or completion fluid.

Abstract: The present invention relates to glycerol based drilling fluids. In particular, the invention relates to drilling fluids comprising a 95-20 volume % glycerol/water solution capable of stabilizing water-sensitive formations during drilling and the use of such solutions for drilling a well having water-sensitive formations.

Abstract: A method of reducing fluid loss from a wellbore that includes emplacing a fluid loss pill in the wellbore, the fluid loss pill comprising: a base fluid; a hydratable or solvatable synthetic copolymer having at least one crosslinkable comonomer; and a crosslinking agent is disclosed.

Abstract: An electrodeposition coating composition comprises an unhydrolyzed or at least partially hydrolyzed polyvinyl formamide polymer for improved edge coverage of the coating when plated onto a conductive substrate. The plated coating can be cured.

Abstract: Sealant compositions comprising a colloidally stabilized latex and methods of using the same to service a wellbore are provided. The sealant compositions may include: an aliphatic conjugated diene monomer; an additional monomer comprising a non-aromatic unsaturated mono- or di- carboxylic ester monomer, an aromatic unsaturated monomer, a nitrogen-containing monomer, or combinations thereof; and a protective colloid. The foregoing sealant composition may be displaced into the wellbore to isolate the subterranean formation from a portion of the wellbore, to support a conduit in the wellbore, to plug a void or crack in the conduit, to plug a void or crack in a cement sheath disposed in an annulus of the wellbore, to plug an opening between the cement sheath and the conduit, or combinations thereof. The colloidally stabilized latex remains substantially stable when exposed to salt, which may be present in the wellbore and/or in the sealant composition itself.

Abstract: A substance and method for treating a subterranean formation using hydraulic fracturing. A non-metallic, substantially deformable, proppant particle is “elastically flexible” or “plastically compressible” and adapted for use at concentrations which will substantially create a partial monolayer.

Abstract: A composite proppant having an increased buoyancy comprising a proppant substrate such as a porous ceramic or a silica sand coated with a material of a lesser actual density than the apparent density of the proppant substrate to increase the buoyancy of the composite proppant.

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 drilling fluid has a redispersible polymer powder introduced as a water dispersion that is capable of providing a deformable latex film on at least a portion of a subterranean sand formation and which inhibits or controls fluid loss and acts as a sealing agent when used to drill in sand formations for hydrocarbon recovery operations. The redispersible polymer powder may be made by drying the emulsion in which they are formed and then grinding into a powder or by spray drying. The polymer particles of suitable size precipitate or collect or assemble onto the pores of a subterranean sand formation to at least partial seal the formation with a deformable polymer film.

Abstract: Use of a mixture comprising a surfactant and a cosurfactant in the form of an aqueous solution for flooding underground deposits of hydrocarbons for mobilizing and recovering the hydrocarbons from the underground deposits, the cosurfactant being a substance or a group of substances selected from the following list: an amphiphilic comb polymer having a backbone with two or more side chains attached to the backbone, the side chains differing from one another and/or the side chains differing from the backbone in their amphiphilic character, an amphiphilic polymer having one or more hydrophobic subunits [A2] based on a polyisobutene block, at least 50 mol % of whose polyisobutene macromolecules have terminally arranged double bonds, and one or more hydrophilic subunits [B2], or an amphiphilic polymer having the general structural formula

Abstract: Exemplary embodiments provide treatment fluids for treating a subterranean formation to improve gas production therefrom. Exemplary embodiments of the treatment fluids comprise a base fluid and a cationic polyorganosiloxane, wherein the cationic polyorganosiloxane comprises at least two cationic quaternary ammonium groups.

Abstract: The present invention relates to a microporous polyolefin film suitable as a separator for batteries and thermal properties thereof. A microporous polyolefin film according to the present invention has a film thickness of 5-40 ?m, a porosity of 30%-60%, a permeability of 2.0×10?5-8.0×10?5 Darcy, a maximum pore size determined by the bubble point method of not more than 0.1 ?m, a puncture strength of 0.20 N/?m or more at room temperature and 0.05 N/?m or more at 120° C., and a maximum shrinkage ratio in the transverse direction (TD) when subjected to a thickness-normalized external force in TMA (thermo-mechanical analysis) of not more than 0%. With excellent thermal stability at high temperature as well as superior puncture strength and gas permeability, the microporous polyolefin film according to the present invention is suitable for high-capacity, and high-power batteries.

Abstract: Fluids and associated methods useful in subterranean applications are provided. Compositions are provided that may be useful in subterranean applications for addressing, among other things, drill string sticking problems. More particularly, spotting fluid compositions are provided having a water insoluble external phase fluid; a water soluble internal phase fluid; and an ether carboxylic acid emulsifying agent. Additional optional components may be used, such as viscosifiers, weighting agents, and wetting agents.

Abstract: Gas hydrate formation in a well completion fluid in the annular space of a hydrocarbon producing well may be controlled by the incorporation of effective amounts of one or more low dose gas hydrate inhibitors, including but not limited to, low dosage hydrate inhibitors (LDHIs), kinetic hydrate inhibitors, dendrimeric or branched compounds, linear polymers and copolymers, grafted or branched linear polymers and copolymers, and onium compounds.

Abstract: A solid zirconium cross-linking agent and use in a cross-linking composition in oil field applications such as hydraulic fracturing and plugging of permeable zones. The zirconium cross-linking agent is prepared by a process comprising contacting a zirconium complex with an alkanolamine and water at particular mole ratios of alkanolamine and water to zirconium.

Abstract: A porous polymer blend, and a method of producing a porous polymer blend from at least two immiscible polymers. The at least two immiscible polymer being blended together and exhibiting the absence of complete phase separation. The method of producing a porous polymer blend comprising: forming a liquid composition comprising at least two immiscible polymers dissolved in a common solvent; subjecting the liquid composition to a reduction in temperature to cause at least two immiscible polymers to phase separate into a common polymer rich phase and a common polymer poor phase; solidifying the at least two immiscible polymers in the common polymer rich phase so as to avoid complete phase separation of the at least two immiscible polymers; and removing the common polymer pore phase to provide a blend of the at least two immiscible polymers having a porous morphology.

Abstract: A lost circulation material and method for well treatment employing the material that is effective at sealing or plugging small fissures and large fractures and has utility over a wide range of temperatures, including high temperatures. The material has an optimized bimodal particle distribution and optionally has a polymer flocculent or water swellable polymer.

Abstract: A process is disclosed for treating an underground formation, which process comprises: (a) introducing into the underground formation a micellar dispersion comprising water, one or more organic acid precursors, one or more surfactants and, optionally, one or more salts, co-surfactants and/or organic liquids that are not organic acid precursors; and (b) allowing (i) the micellar dispersion to solubilize hydrocarbons, emulsions or water blocks present in the underground formation, and (ii) at least a portion of the organic acid precursor to hydrolyze in-situ to produce sufficient organic acid to substantively dissolve acid soluble material present in or adjacent to filter cakes or other damage in the underground formation.