Abstract: A process is proposed for blocking underground formations in the extraction of fossil oil and/or gas, a first step involving introducing water-absorbing particles into liquid-bearing and porous rock formations, said particles being water-swellable, crosslinked and water-insoluble polymers, said particles in the water-bearing rock formation finally preventing liquid flow through the rock layers by water absorption. This process is characterized in that the absorbing particles comprise a superabsorbent polymer with anionic and/or cationic properties and a retarded swelling action. This process, which can also be carried out in saline formation waters, is notable in that the swelling of the superabsorbents used begins no earlier than after five minutes and in that the superabsorbents are obtainable by four proposed process variants and any combination thereof.

Abstract: Compositions and methods of treating high temperature subterranean formations of up to about 500° F. (260° C.) are provided. The compositions and methods utilize a high molecular weight synthetic copolymer and a pH buffer than maintains a pH in a range of about 4.5 to about 5.25 for the compositions. The high molecular weight synthetic copolymer is derived from acrylamide, acrylamidomethylpropanesulfonic acid, and vinyl phosphonate.

Abstract: A system for reducing pressure drop associated with the turbulent flow of asphaltenic crude oil through a conduit. The crude oil has a high asphaltene content and/or a low API gravity. Such reduction in pressure drop is achieved by treating the asphaltenic crude oil with a high molecular weight drag reducing polymer that can have a solubility parameter within about 20 percent of the solubility parameter of the heavy crude oil. The drag reducing polymer can also comprise the residues of monomers having at least one heteroatom.

Abstract: Composition including freeze thaw stability polymer such as a copolymer having a weight average molecular weight of at least about 30,000 grams per mole, a blend of a first polymer and a second polymer, a crosslinked alkali swellable acrylate copolymer, or at least one polymerizable reactive alkoxylated acrylate monomer. The copolymer has one or more first monomeric units and one or more second monomeric units. The one or more first monomeric units each independently including at least one bicycloheptyl-polyether, bicycloheptenyl-polyether or branched (C5-C50)alkyl-polyether group per monomeric unit. The bicycloheptyl-polyether or bicycloheptenyl-polyether group may optionally be substituted on one or more ring carbon atoms by one or two (C1-C6)alkyl groups per carbon atom. The one or more second monomeric units each independently including at least one pendant linear or branched (C5-C50)alkyl-polyether group per monomeric unit.

Abstract: The present invention relates to processes for tertiary mineral oil production with the aid of a surfactant mixture and to the use of a surfactant mixture for tertiary mineral oil production by means of Winsor type III microemulsion flooding, by injecting a surfactant mixture through at least one aqueous injection borehole into a mineral oil deposit, and withdrawing crude oil from the deposit through at least one production borehole, wherein the surfactant mixture, for the purpose of lowering the interfacial tension between oil and water to <0.1 mN/m, comprises at least the following components: (a) one or more polycarboxylate(s) comprising at least 50 mol % of acrylic acid units and/or methacrylic acid units and/or maleic acid units and/or itaconic acid units or salts thereof, and (b) one or more anionic and/or nonionic surfactant(s).

Abstract: The present disclosure is directed to compositions and methods that may be used for enhanced oil recovery, for modifying the permeability of subterranean formations and for increasing the mobilization and/or recovery rate of hydrocarbon fluids present in the formations. The compositions may include, for example, expandable cross-linked polymeric microparticles having unexpanded volume average particle size diameters of from about 0.05 to about 5,000 microns and cross linking agent contents of from about 100 to about 200,000 ppm of labile cross linkers and from 0 to about 300 ppm of non-labile cross linkers, wherein the expandable polymeric monomers have a block copolymer structure comprising at least two different monomers having different chemical structures.

Abstract: The present invention relates vulcanisable guanidine-free mixtures containing ethylene acrylate (AEM), polyacrylate (ACM) and/or hydrogenated acrylonitrile (HNBR)-based rubbers compounds having an improved scorch resistance, to vulcanisates, prepared by cross-linking this vulcanisable mixtures and their use in automotive, oil-field and/or off-shore applications.

Abstract: Methods and compositions are provided that relate to well bore treatments that comprise swellable particles. An embodiment includes a method that comprises introducing a fluid comprising a dual oil/water-swellable particle into a subterranean formation. Another embodiment includes a method of cementing that comprises: introducing a cement composition comprising cement, water, and a dual oil/water-swellable particle into a space between a pipe string and a subterranean formation; and allowing the cement composition to set in the space. Another embodiment includes a well treatment composition comprising a dual oil/water-swellable particle.

Abstract: A method of treating a subterranean formation penetrated by a wellbore involves introducing an acid treatment fluid through the wellbore into the formation. The treatment fluid is formed from a zwitterionic viscoelastic surfactant, an acid in an amount to provide the treatment fluid with an initial pH of ?0 and a rheology enhancer. The treatment fluid has a high viscosity at the initial pH and a lower viscosity when the pH of the treatment fluid is raised to an intermediate pH of from greater than 0 to about 5.

Abstract: A method for treating a subterranean formation includes forming a treatment fluid including a carrier fluid, a solid acid-precursor, and a solid scale inhibitor. The solid acid-precursor includes a material that forms an acid at downhole conditions in the subterranean formation. The method further includes adding a solid acid-responsive material into the treatment fluid, where the solid acid-responsive material enhances formation of acid from the solid acid-precursor in acidic conditions. The method includes performing an acid fracture treatment and inhibiting scale formation within the subterranean formation. The solid scale inhibitor allows for long-term scale inhibition after the treatment.

Abstract: The present disclosure is directed to compositions and methods for enhanced oil recovery, for modifying the permeability of subterranean formations and for increasing the mobilization and/or recovery rate of hydrocarbon fluids present in the formations. The compositions may include, for example, expandable cross-linked polymeric microparticles having unexpanded volume average particle size diameters of from about 0.05 to about 5,000 microns and cross linking agent contents of from about 100 to about 200,000 ppm of labile cross linkers and from 0 to about 300 ppm of non-labile cross linkers that may be used in combination with other components such as, for example, a second and different polymeric microparticle, a viscosified aqueous solution, a subterranean reservoir treatment, or combinations thereof.

Abstract: An acidizing fluid for sandstone formations is provided, along with methods of acidizing a sandstone formation penetrated by a wellbore. The aqueous acid treatment is a mixture of an aqueous liquid, a fluoride source, and an effective amount of at least one homopolymer or copolymer of a polycarboxylic acid, salt thereof or derivative thereof, which is introduced into the wellbore, and allowed to acidize the formation and concurrently inhibit calcium fluoride formation and impart calcium tolerance to the fluid.

Abstract: A well treatment composition is formed from a fluid mixture of a viscoelastic surfactant and a liquid carrier fluid. The fluid mixture has rheological properties wherein the mixture exhibits shear-thickening behavior when the shear rate is increased from a first shear rate to a second higher shear rate. The fluid mixture may further include a shear activation additive that interacts with the viscoelastic surfactant to facilitate the shear-thickening behavior. The method is accomplished by introducing the fluid mixture into a wellbore formed in a subterranean formation. In certain applications, the fluid mixture may be recycled by bringing the fluid mixture to the surface and reintroducing the fluid into the same or a different wellbore.

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: 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: Compositions and methods are described for inhibiting corrosion of corrodible metals present in contact with water in cooling water and other water storage systems. The compositions include concentrated stannous salts and agents to solubilize such salts.

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: This invention is directed to a composition comprising crosslinked expandable polymeric microparticles comprising structured polymers having labile crosslinks or having a labile core and non-labile crosslinks. The starting configuration of the structured polymers constrains the microparticle to an unexpanded volume average particle size diameter of from about 0.05 to about 5,000 microns. Labile crosslinks or the labile core of the structured polymers are subject to degradation which results expansion of the microparticle. 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: 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 discloses a method of treating a subterranean formation of a well bore: providing a treatment fluid made of: a fluid; a particulate material, and a viscosifier material; wherein the viscosifier material is inactive in a first state and is able to increase viscosity of the treatment fluid when in a second state; introducing the treatment fluid into the wellbore; and providing a trigger able to activate the viscosifier material from first state to second state.

Abstract: Low molecular weight graft copolymer comprising a synthetic component formed from at least one or more olefinically unsaturated carboxylic acid monomers or salts thereof, and a natural component formed from a hydroxyl-containing natural moiety. The number average molecular weight of the graft copolymer is about 100,000 or less, and the weight percent of the natural component in the graft copolymer is about 50 wt % or greater based on total weight of the graft copolymer. Processes for preparing such graft copolymers are also disclosed.

Abstract: A binder is described which comprises A) a hydrolysate or heterocondensate of at least one hydrolysable silicon compound and at least one metal, phosphorus or boron compound, the metal being selected from Al, Ge, Sn, Pb, Ti, Mg, Li, V, Nb, Ta, Zr and Hf, B) an organic polymerizable or polycondensable monomer or oligomer and C) a buffer, so that the pH of the buffered binder is in the range from 2 to 7, and optionally a complexing agent, if appropriate, the at least one hydrolysable silicon compound comprising one or more hydrolysable silicon compounds having at least one nonhydrolysable group or oligomers thereof. The binder is suitable for consolidating bulk or loose substrates.

Abstract: This invention is directed to a composition comprising expandable polymeric microparticles comprising hydrophobic polymers having a backbone with labile pendant groups, the microparticles having an unexpanded volume average particle size diameter of from about 0.05 to about 5,000 microns. Labile pendant groups on the backbone are subject to hydrolysis under a change in environmental conditions that results in expansion of the microparticle. 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: 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 treatment fluid for treating a subterranean formation is formed from an aqueous solution of a polysaccharide, a polyacrylamide, a crosslinking agent, which may be a Group 4 transition metal crosslinking agent, and less than 0.1% by weight of any clay component. In certain embodiments, the polyacrylamide may have an average molecular weight of from greater than 0.5 million to about 20 million and may be present in the fluid in an amount of from about 0.01% to 1% by weight of the fluid. A method of treating a subterranean formation penetrated by a wellbore may be carried out by introducing the treatment fluid into the formation through the wellbore. In certain embodiments, the treatment fluid may be introduced into a portion of the formation having a temperature of 120° C. or higher.

Abstract: Methods are provided for treating a portion of a well. The method according to this aspect comprises the steps of: (A) forming a treatment fluid, the treatment fluid comprising: (i) water; (ii) a water-soluble polymer; (iii) a complexed metal cation that: (a) has a valence state of at least three; and (b) is capable of cross-linking the water-soluble polymer; and (iv) an aromatic compound that is capable of dissolving, melting, or chemically decomposing, dissociating, or reacting, to form a chelating agent, wherein the chelating agent comprising vicinal substituents containing donor heteroatoms, and wherein the chelating agent is capable of chelating the metal cation; and (B) introducing the treatment fluid into the well.

Abstract: The present invention includes composition having a nonionic, fluorinated polymeric surfactant, water and solvent. Embodiments of compositions according to the present invention are useful, for example, for recovering hydrocarbons from subterranean clastic formations.

Abstract: A variety of methods and compositions are disclosed, including, in one embodiment, a method that comprises: introducing a treatment fluid into a subterranean formation, wherein the treatment fluid comprises water and a concentrated polymer composition comprising a complexing agent and a friction reducing polymer. Also disclosed is a method that comprises combining at least water and a concentrated polymer composition to form a treatment fluid, wherein the concentrated polymer composition comprises a complexing agent and a friction reducing polymer; and introducing the treatment fluid into a subterranean formation. Also disclosed is a concentrated polymer composition comprising: a friction reducing polymer in an amount of about 15% to about 60% by weight of the composition; and a complexing agent.

Abstract: Embodiments of the present disclosure include compositions for enhanced oil recovery and methods of using the same. Compositions of the present disclosure include particles of a hydrophobic polymer having constitutional repeating units of which at least 10 percent are hydrolysable and through hydrolysis increase a viscosity of the aqueous composition within a subterranean formation.

Abstract: Exemplary embodiments of the cement compositions comprise water, a cement, and a fluid loss control additive, the fluid loss control additive comprising a graft copolymer. The graft copolymer comprises a backbone and at least four grafted monomers selected from the group consisting of 2-acrylamido-2-methylpropanesulfonic acid, acrylamide, acrylic acid, vinylphosphonic acid, diallyldimethylammonium chloride, and salts thereof. The backbone of the graft copolymer comprises a humic acid salt. Methods of cementing using exemplary embodiments of the cement compositions are also provided.

Abstract: The invention is directed to crosslinked water-soluble swellable polymers, methods for making same and their various uses. More particularly, the invention relates to a composition comprising expandable polymeric particles being made with 0.1-5% hydrophobic monomers and labile crosslinkers and stable crosslinkers, said particles mixed with a fluid. A particularly important use is as an injection fluid in petroleum production, where the expandable polymeric particles are injected into a well and when the heat and/or pH of the target zones in the formation cause degradation of the labile crosslinker and when the particle expands, the hydrophobic groups associate to form a hydrophobically associative polymer, thus diverting water to lower permeability regions and improving oil recovery.

Abstract: Methods comprising: providing a degradable polymer within a portion of a subterranean formation; introducing a base solution into the portion of the subterranean formation, wherein the base solution comprises at least one base selected from the group consisting of: ammonium hydroxide, an alcoholic alkaline solution, and an alkaline amine solution, and derivatives thereof; and allowing the base solution to degrade the degradable polymer.

Abstract: A process that includes pumping a first wellbore fluid comprising an oxidative degradable polymer into a wellbore through a subterranean formation; pumping a second wellbore fluid comprising a pH-activated oxidative breaker into the wellbore; pumping a third wellbore fluid comprising a delayed acid source into the wellbore; and allowing the delayed acid source to acidify at least a portion of the wellbore to a pH of less than 7 so as to activate the pH-activated oxidative breaker at the lower pH and degrade the oxidative degradable polymers is disclosed.

Abstract: Disclosed herein is a method comprising disposing in a formation fracture, a proppant and/or a fracturing fluid that comprises a radiation susceptible material that comprises indium and/or vanadium; irradiating the radiation susceptible material with neutrons; measuring gamma-radiation emitted from the radiation susceptible material in a single pass; wherein the single pass does not involve measuring of background radiation from previous or subsequent logging passes; and determining formation fracture height from the measured gamma-radiation.

Abstract: A fluid comprising a viscous hyposaline aqueous solution of first and second cationic polymers comprising quaternized ammonium groups, wherein the first cationic polymer comprises a hydrophilic base polymer structure and the second cationic polymer comprises a lipophilic base polymer structure, and a method comprising introducing the viscous fluid into an initial first interval of a subterranean formation, and diverting with the viscous fluid a treating fluid from the initial first interval to an initial second interval. The fluid and method are useful to modify a hydrocarbon reservoir formation for improved relative permeability of oil with respect to water to enhance hydrocarbon production from the reservoir.

Abstract: Provided herein are methods and compositions for generating acids for use downhole, for example, to break fluid-loss control pills. The delayed-release acid breakers of the present invention comprise orthoesters and/or poly(orthoesters).

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: Aqueous well treatment fluid compositions are disclosed comprising an aqueous fluid containing polymer or copolymer for modifying fluid viscosity of the aqueous fluid and, in addition, an agent for effecting a controlled reduction in the aqueous fluid viscosity in a subterranean environment. The viscosity-reducing agent comprises a dilute concentration of peracetic acid. A method of using such compositions in oil- and gas-field treatment operations is also disclosed.

Abstract: The present invention relates to the use of an oil formulation in the field of the oil industry, in particular for the prevention of water penetration. The formulation according to the invention is in particular intended to be injected into underground formations, such as injection wells or production wells.

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

Abstract: A method for removing water from a wellbore fluid is disclosed. The method may include the steps of contacting a wellbore fluid with a water absorbing polymer, where the wellbore fluid includes an aqueous fluid, allowing the water absorbing polymer to interact with the wellbore fluid for a sufficient period of time so that the water absorbing polymer absorbs at least a portion of water in the aqueous fluid, and separating the water absorbing polymer containing the absorbed water from the wellbore fluid.

Abstract: Well treating composites are composed of an organic lightweight material and a weight modifying agent. The organic lightweight material preferably forms the continuous phase and the weight modifying agent forms the discontinuous phase. The apparent specific gravity (ASG) of the organic lightweight material is less than the ASG of the well treating composite. The composite of the invention is particularly useful in hydraulic fracturing fluids as lightweight proppants as well as in sand control methods, such as gravel packing and frac packing A subterranean formation may be treated by injecting the well treating composite into the formation in order to increase fracture conductivity, reduce the generation of fines, reduced unwanted water production and/or reduce particulate production.

Abstract: The present invention includes composition having a nonionic, fluorinated polymeric surfactant, water and solvent. Embodiments of compositions according to the present invention are useful, for example, for recovering hydrocarbons from subterranean elastic formations.

Abstract: A method of treating a formation that includes emplacing an oxidizing breaker fluid into a region of the formation occupied by a gel; and allowing sufficient time for the oxidizing breaker fluid to degrade the gel is disclosed.

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: 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.