Abstract: This invention provides acrylate polymers having at least two different ester groups. The ester groups are selected from the following: a) an aralkyl group; b) a linear alkylether group; c) a polyethoxylated alkylaryl group; and d) a polyethoxylated alkyl group, with the proviso that at least one of said ester groups is selected from b) or d). Processes for preparing such polymers and processes for breaking emulsions with these acrylate polymers are also provided.

Abstract: Wellbore fluid having a continuous aqueous phase, and comprising at least one polymer which has a number average molecular weight in the range of from 10,000 to less than 100,000, wherein the polymer is selected from a copolymer of at least one hydrophilic monomer and at least one hydrophobic monomer containing an alkyl group having at least 8 carbon atoms. The hydrophilic monomer is selected from acrylic acid, methacrylic acid, maleic acid, maleic anhydride, fumaric acid and itaconic acid, and sulfonate groups have been introduced into the copolymer by reaction of at least a portion of the carboxylic acid and/or anhydride groups with a compound of general formula R12N(CH2)nSO3X (I) or a compound of general formula HO(CH2)nSO3X (II). Each R1 is independently selected from hydrogen, methyl or ethyl, X is either H or a Group IA metal, and n is an integer of from 1 to 6.

Abstract: Methods and compositions are provided that include degradable gemini surfactants including degradable gemini surfactants. Methods of use include subterranean operations, especially those involving the placement of resin systems, formation of emulsions (e.g., emulsified acids, emulsified fracturing fluids, drilling fluids, etc.), and in the formation of surfactant gelled fluids. Such treatments include, but are not limited to, drilling, stimulation treatments (e.g., fracturing treatments, acidizing treatments), and completion operations (e.g., sand control treatments like gravel packing).

Abstract: A well stimulation fluid includes water, a polymer, and a biocide consisting of 3,5-dimethyl-1,3,5-thiadiazinane-2-thione in an amount effective to inhibit bacterial growth.

Abstract: Embodiments disclosed herein relate to aqueous based wellbore fluids for preventing wellbore fluid loss downhole containing at least one copolymer formed from at least one natural polymer monomer and at least one latex monomer, and an aqueous base fluid.

Abstract: Methods and compositions are provided that include a water-in-oil composition comprising an oil-based continuous phase and a discontinuous phase that comprises at least a plurality of hydrogel droplets and a method comprising providing a water-in-oil emulsion comprising an oil-based continuous phase and a discontinuous phase that comprises at least a plurality of hydrogel droplets; and placing the water-in-oil emulsion in a well bore penetrating a subterranean formation. Additional methods are also provided.

Abstract: The invention relates to a composition that can form a gel comprising a copolymer. Said composition is an aqueous composition, and the copolymer is a star copolymer. The invention also relates to useful copolymers, especially for the inventive compositions.

Abstract: A spacer for use in an oil well cementing operation comprises an aqueous solution of a visco-elastic surfactant. A method of treating a well in a cementing operation, comprises pumping the spacer into a well ahead of a cement slurry for cementing the well.

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: Additives and treatment fluids with improved shale inhibition, and associated methods of use in subterranean operations, are provided. The additives and treatment fluids used generally comprise a shale-inhibiting component and one or more silicates.

Abstract: A monomer compound that contains at least one polymerizable functional group per molecule, and at least one bicycloheptyl-, bicycloheptenyl-, or branched (C5-C42)alkyl-polyether radical per molecule, wherein the bicycloheptyl- or bicycloheptenyl-polyether radical may optionally be substituted on one or more of the ring carbon atoms by one or two (C1-C6)alkyl groups per ring carbon atom is useful in making polymers, particularly pH responsive polymers.

Abstract: The present invention relates to polymer-coated particulates suitable for use in subterranean operations such as gravel packing, frac-packing, and hydraulic fracturing. One embodiment of the present invention provides improved particulates for use in a subterranean formation, comprising particulates at least partially coated with a polymer, wherein the polymer is deposited on the particulates by at least partially coating the particulates with a polymer solution comprising the polymer and a solvent and then exposing the particulates to an aqueous medium such that the solvent substantially dissociates from the polymer solution and such that the polymer substantially remains on the particulates.

Abstract: Methods and compositions useful for subterranean formation treatments, such as hydraulic fracturing treatments and sand control that include porous materials. Such porous materials may be selectively configured porous material particles manufactured and/or treated with selected glazing materials, coating materials and/or penetrating materials to have desired strength and/or apparent density to fit particular downhole conditions for well treating such as hydraulic fracturing treatments and sand control treatments. Porous materials may also be employed in selected combinations to optimize fracture or sand control performance, and/or may be employed as relatively lightweight materials in liquid carbon dioxide-based well treatment systems.

Abstract: The present invention relates to subterranean drilling operations, and more particularly, to drilling fluids that may be used to drill a well bore in a subterranean formation that may demonstrate improved shale inhibition and methods of using such drilling fluids in subterranean formations. One embodiment of the methods of the present invention provides a method of drilling a well bore in a subterranean formation comprising providing a drilling fluid comprising an aqueous-based fluid and a shale inhibiting component comprising a nanoparticle source; and placing the drilling fluid in the well bore in the subterranean formation. Another embodiment of the present invention provides a method of flocculation comprising providing a fluid comprising suspended particles, and adding a shale inhibiting component comprising a nanoparticle source to the fluid comprising suspended particles to form flocculated particles.

Abstract: The present disclosure is directed to a thermothickening composition comprising: a surfactant; and a thermothickening polymer that is the product of at least the following monomers: a non-ionic hydrosoluble unsaturated amide monomer; an ionic monomer; and an unsaturated dicarboxylic acid half ester having a heat sensitive functional group.

Abstract: A lost circulation composition for use in a wellbore comprising a crosslinkable polymer system and a filler.

Abstract: Composite propping agents of low density and of high mechanical strength are based on a thermoplastic polymer matrix, in particular having low compressive deformation at high temperatures are especially useful in the field of well fracturing for the recovery of sludges, liquids and gases present in underground reservoirs, and in particular in the field of the extraction of hydrocarbons, such as crude oil or natural gas.

Abstract: Method for enhanced oil recovery consisting in introducing into the injection water a solution containing at least one polymer and at least one surfactant, the surfactant/polymer weight ratio being between 1 and 10 and the surfactant concentration in the solution being higher than 100 ppm (parts per million), characterized in that the said polymer contains at least one hydrophobic cationic monomer.

Abstract: A thermal insulating packer fluid contains at least one water superabsorbent polymer and optionally water and/or brine, and a viscosifying polymer. The composition is capable of inhibiting unwanted heat loss from production tubing or uncontrolled heat transfer to outer annuli. The viscosity of the composition is sufficient to reduce the convection flow velocity within the annulus.

Abstract: The present invention relates to a process for preparing a phosphorus-containing polymer, comprising the steps of (i) copolymerizing at least (a) monoethylenically unsaturated dicarboxylic anhydrides having from 4 to 6 carbon atoms with (b) olefins of the formula CH2?C(R1)R2 where R1 is H or CH3 and R2 is H, CH3, C2H5 or phenyl; (ii) reacting the polymer formed in step (i) with at least one primary or secondary phosphorus-containing amine or a phosphorus-containing alcohol and (iii) at least partly ring-opening the remaining anhydride groups. The invention further relates to phosphorus-containing polymers obtainable from this process, and to processes for preventing Ba/Sr scale with the aid of the polymer.

Abstract: Herein provided are variable density fluid compositions and methods for using such compositions in a subterranean formation. One exemplary embodiment of the variable density fluid compositions of the present invention comprises a variable density fluid comprising: a base fluid; and a portion of elastic particles, the elastic particles having an isothermal compressibility factor in the range of from about 1.5×10?3 (1/psi) to about 1.5×10?9 (1/psi). Also provided are cement compositions comprising elastic particles, processes for preparing such cement compositions, and methods of cementing in subterranean formations using such cement compositions. One or more elastic particles are mixed with the cement before pumping the cement into a well bore. The elastic particles are preferably composed of an elastomeric material such as a copolymer of methylmethacrylate and acrylonitrile; a terpolymer of methylmethacrylate, acrylonitrile, and dichloroethane; a styrene-divinylbenzene copolymer; and polystyrene.

Abstract: Methods and compositions for stabilizing portions of a subterranean formation that comprise unconsolidated particulates are provided. In one embodiment, a method of treating a subterranean formation includes introducing a pre-flush fluid into a subterranean formation comprising unconsolidated particulates; introducing a foamed consolidation fluid comprising an aqueous base fluid, an emulsified resin, a hardening agent, a silane coupling agent, and a surfactant into the subterranean formation subsequent to the pre-flush fluid; wherein the emulsified resin is emulsified prior to being introduced into the aqueous base fluid; and allowing the resin to cure to at least partially consolidate the unconsolidated particulates.

Abstract: A non-aqueous wellbore servicing fluid comprising an alpha-olefin homopolymer grafted with a polar monomer.

Abstract: An engineered composition for reducing lost circulation in a well includes a mixture of coarse, medium and optional fine particles, and a blend of long fibers and short fibers. The long fibers are rigid and the short fibers are flexible. The long fibers form a tridimensional mat or net in the lost-circulation pathway that traps the mixture of particles and short flexible fibers to form a mudcake. The mixture of particles and blend of fibers may be added to water-based and oil-based drilling fluids. The composition, size, and concentration of each component of the mixture of particles and blend of fibers may be fine-tuned for each application.

Abstract: A method of controlling the pressure of a casing annulus in a subterranean well that includes injecting into the casing annulus a composition including a base fluid and a polymer coated colloidal solid material. The polymer coated colloidal solid material includes: a solid particle having an weight average particle diameter (d50) of less than two microns, and a polymeric dispersing agent coated onto the surface of the solid particle during the cominution (i.e. grinding) process utilized to make the colloidal particles. The polymeric dispersing agent may be a water soluble polymer having a molecular weight of at least 2000 Daltons. The solid particulate material may be selected from materials having of specific gravity of at least 2.

Abstract: A method for improving bonding and sealing in a well, comprising providing a wellbore, providing a pipe, coating an outside surface of the pipe with an adhesive thermoplastic resin, running the coated pipe into the wellbore, and causing the temperature of said wellbore to increase to a temperature greater than a melting temperature of said adhesive thermoplastic resin.

Abstract: A method of servicing a wellbore comprising placing a sealant composition comprising solid latex into the wellbore.

Abstract: The present invention relates to methods and compositions for carrier fluids comprising water-absorbent fibers. One embodiment of the present invention provides a method of treating a portion of a subterranean formation, comprising providing a slurry wherein the slurry comprises a servicing fluid, particulates, and a degradable, water-absorbent material wherein the degradable, water-absorbent material acts to help keep the particulates from settling out of the slurry; and, introducing the slurry into the portion of the subterranean formation. Another embodiment of the present invention provides a slurry suitable for use in subterranean operations comprising a servicing fluid, particulates, and a degradable, water-absorbent material wherein the degradable, water-absorbent material acts to help keep the particulates from settling out of the slurry.

Abstract: A two step process for treating an oil or gas well. The first step uses a cross linking agent, such as borax, as a preliminary wash for the well following drilling. The cross linking agent cleans the well of excess mud and pre-coats the tubing and the formation surfaces with the cross linking agent. The second step introduces a cement-polymer mixture into the well. A polymer, such as for example polyvinyl alcohol, that undergoes cross linking when exposed to the cross linking agent is employed. When the polymer comes into contact with the cross linking agent in the well, cross linking of the polymer occurs. This cross linking helps to prevent fluid loss into the formation. Also, because the cross linking agent wash previously cleaned the surfaces of the tubing and the formation, better bonding between the cement and the surfaces of the tubing and the formation occurs.

Abstract: This invention is directed to a composition comprising expandable polymeric microparticles comprising an interpenetrating polymer network (IPN). The IPN constrains the microparticle to an unexpanded volume average particle size diameter of from about 0.05 to about 5,000 microns. Labile cross-links in the polymers of the IPN are subject to degradation, which results in release of the expandable microparticle so that the microparticle expands. The invention is further directed to the use of the composition for modifying the permeability of subterranean formations and increasing the mobilization and/or recovery rate of hydrocarbon fluids present in the formations.

Abstract: A process for recovering materials from a subterranean formation, for example in enhanced oil recovery, comprises: (A) (a) (i) selecting a first polymeric material having a repeat unit of formula (A) wherein A and B are the same or different, are selected from optionally-substituted aromatic and heteroaromatic groups and at least one comprises a relatively polar atom or group and R1 and R2 independently comprise relatively non-polar atoms or groups; or (ii) selecting a first polymeric material prepared or preparable by providing a compound of general formula (B) wherein A, B, R1 and R2 are as described above, in an aqueous solvent and causing the groups C?C in said compound to react with one another to form said first polymeric material; (b) selecting a second polymeric material which includes a functional group which is able to react in the presence of said first polymeric material to form a third polymeric material; (c) causing the formation of said third polymeric material by a reaction involving said firs

Abstract: Methods of servicing a wellbore include generating gas in a plugging composition in situ within a permeable zone in the wellbore, thereby improving the ability of the plugging composition to seal the permeable zone. The gas may be generated via a chemical reaction by, for example, introducing first and second reactants to the plugging composition that can react at ambient temperatures in the wellbore. In an embodiment, the first and second reactants are concurrently pumped into the wellbore via separate flow paths within two concentric conduits to the permeable zone where they are allowed to contact each other in the presence of the plugging composition. In another embodiment, the first reactant, the second reactant, and a retarder for slowing the reaction between the two reactants are concurrently pumped to the permeable zone. In yet another embodiment, one of the reactants is encapsulated to delay a reaction between the two reactants.

Abstract: An all-oil reversible gelling system includes a polymer, a crosslinker, a gel accelerator, and an oxidant, wherein temperature activates the crosslinker so as to cause the system to form a gel, and the oxidant subsequently decomposes the gel. This gel is designed to seal temporarily portions of oil-producing or water or gas injecting subterranean formations.

Abstract: This invention provides acrylate polymers having at least two different ester groups. The ester groups are selected from the following: a) an aralkyl group; b) a linear alkylether group; c) a polyethoxylated alkylaryl group; and d) a polyethoxylated alkyl group, with the proviso that at least one of said ester groups is selected from b) or d). Processes for preparing such polymers and processes for breaking emulsions with these acrylate polymers are also provided.

Abstract: Use of water-soluble polymers for tertiary mineral oil production by introducing the polymer into a mineral oil deposit, in which the water-soluble polymers are used in the form of a dispersion of the water-soluble polymer and at least one water-soluble, polymeric stabilizer.

Abstract: Methods and compositions are provided that include a water-in-oil composition comprising an oil-based continuous phase and a discontinuous phase that comprises at least a plurality of hydrogel droplets and a method comprising providing a water-in-oil emulsion comprising an oil-based continuous phase and a discontinuous phase that comprises at least a plurality of hydrogel droplets; and placing the water-in-oil emulsion in a well bore penetrating a subterranean formation. Additional methods are also provided.

Abstract: The present invention relates to methods for treating subterranean formations. A method, that comprises providing a treatment fluid that comprises an aqueous fluid, and a degradable surfactant derived from a degradable polymer; and introducing the treatment fluid into a well bore that penetrates the subterranean formation, is provided.

Abstract: A process for the preparation of hydrolytically and hydrothermally stable consolidated proppants is described, in which (A) a consolidating agent comprising (A1) a hydrolysate or precondensate of at least one functionalized organosilane, a further hydrolyzable silane and at least one metal compound, the molar ratio of silicon compounds used to metal compounds used being in the range of 10 000:1 to 10:1, and (A2) an organic crosslinking agent are mixed with a proppant and (B) the consolidating agent is cured at elevated pressure and elevated temperature. The consolidated proppants obtained have high mechanical strength.

Abstract: Composites containing a hydrocarbon-soluble well treatment agent may be supplied to a well using a porous particulate. Such well treatment agents may for example inhibit the formation of paraffins, salts, gas hydrates, asphaltenes and/or other deleterious processes such as emulsification (both water-in-oil and oil-in-water). Further, other well treatment agents include foaming agents, oxygen scavengers, biocides and surfactants as well as other agents wherein slow release into the production well is desired.

Abstract: The invention provides a method of treating a subterranean formation penetrated by a wellbore, the method comprising the steps of: (a) mixing a particulate and an active material to obtain an at least partially coated particulate, wherein: (i) water forms a contact angle of less than 90 degrees with a surface of the particulate, (ii) the active material is capable of forming a coating on the particulate, (iii) the active material forms a contact angle less than 90 degrees with the particulate, and (iv) water forms a contact angle of greater than 90 degrees with a layer of the active material; (b) mixing the at least partially coated particulate and a carrier fluid to obtain a treatment fluid; and (c) introducing the treatment fluid into the subterranean formation through the wellbore to deposit the at least partially coated particulate into the subterranean formation.

Abstract: Novel uses of reactive surfactants in treating subterranean formations and/or proppant particulates are provided. In one embodiment, the present invention provides a surfactant-treated proppant particulate comprising a proppant particulate that comprises at least one surface that has been allowed to interact with a reactive surfactant.

Abstract: A downwell packer assembly includes a tubular member and a packer element mounted on the tubular member. The packer element comprises a composition that includes a polymer. The packer element includes micropores (typically created via a blowing agent). When the packer element is exposed to a swelling fluid, such as water or hydrocarbon, the micropores can help to control and, in some instances, increase the rate of swelling. Such swelling enables the packer element to form a seal against the walls of the wellbore.

Abstract: A composition suitable for use in a packer element for a wellbore includes: a hydrocarbon-swellable polymer, the hydrocarbon-swellable polymer present in the composition in an amount between about 10 and 30 percent by weight; an oil-resistant polymer, the oil-resistant polymer present in the composition in an amount between about 10 and 30 percent by weight; and a hydrocarbon swelling agent, the hydrocarbon swelling agent present in the composition in an amount between about 15 and 60 percent by weight. A composition as described may have a good balance of the swelling properties of the hydrocarbon-swellable polymer and the mechanical properties of the oil-resistant polymer. These properties may be useful in a packer element for a wellbore.

Abstract: A method of servicing a wellbore comprising preparing a cement slurry by premixing at least one latex, at least one stabilizer, and optionally water to form a homogeneous solution, further mixing the homogeneous solution with an ionic compound, cement, and optionally additional water to form the slurry, and placing the slurry in the wellbore. A method of stabilizing latex in cement slurry containing saltwater, comprising premixing the latex with a stabilizer until a homogenous solution forms prior to contacting the latex with the saltwater. A cement slurry comprising a latex, a stabilizer, a cement, an ionic compound, and water wherein the latex and stabilizer are contacted prior to contact of the latex with the ionic compound.

Abstract: Wellbore fluids containing poly(trimethylene ether)glycols are provided. The wellbore fluids can provide enhanced functionality, improved cost effectiveness, and reduced environmental impact as compared to conventional wellbore fluids.

Abstract: Adding relatively low molecular weight water-soluble friction loss reduction polymers to an aqueous fluid gelled with a viscoelastic surfactant (VES) increases the critical generalized Reynold's number at which the Fanning friction factor increases and friction pressure starts to increase rapidly. The water-soluble polymeric friction loss reduction additives lower surface pumping pressure in VES-gelled fracturing fluids for a given pump rate, thus lowering hydraulic horsepower (HHP) requirements for pumping fluids downhole, e.g. for hydraulic fracturing or frac packing treatments of subterranean formations.

Abstract: Disclosed is a method and material for forming a fluid barrier in the material surrounding a wellbore. The method involves temporarily opening a fracture extending from the wellbore and then depositing particulates in the fracture which will swell when exposed to the fluid. The particles are deposited in the fracture without causing appreciable swelling thereof and then, after the fracture closes, the particles are allowed to swell when contacted with the fluid to form a fluid barrier.

Abstract: Rapid setting plugging compositions comprising oil, clay, magnesium chloride, and magnesium oxide powder are provided for sealing permeable zones in subterranean formations. The permeable zones may be sealed by passing the plugging composition and water to the subterranean formation. While being exposed to downhole temperatures in a range of from about 0° F. to about 500° F., the plugging composition quickly thickens to form a sealing mass that is substantially impermeable to fluid in less than about 1 minute after contacting the water. It then usually develops an effective amount of compressive strength to prevent it from being washed away within a period ranging from about 5 minutes to about 2 hours at temperatures ranging from about 0° F. to about 500° F.

Abstract: Methods and compositions are provided for treating fluids, especially spacer fluids and cement compositions as well as drilling, completion and stimulation fluids including, but not limited to, drilling muds, well cleanup fluids, workover fluids, conformance fluids, gravel pack fluids, acidizing fluids, fracturing fluids and the like for introduction into a subterranean zone penetrated by a wellbore, wherein the treating fluid comprises zeolite and a carrier fluid. The treating fluid may additionally include one or more of a viscosifier, organic polymer, dispersants, surfactants and weighting materials.

Abstract: Methods and compositions useful to prevent scale formation and/or diageneous reactivity on mineral surfaces residing or to be placed in subterranean formations, are provided. In one embodiment, the methods comprise: providing an anionic polymer and a cationic surfactant; contacting a mineral surface with the anionic polymer and the cationic surfactant; and allowing the anionic polymer and the cationic surfactant to interact with each other, whereby a film is formed on at least a portion of the mineral surface.