Abstract: Fluids including a parylene-coated chemical entity and methods of treating a subterranean formation with such fluids are disclosed. The methods may include introducing a treatment fluid into a subterranean formation, the treatment fluid containing a parylene-coated particle having a chemical entity encapsulated therein.

Abstract: The disclosed compositions and methods provide a system that is effective for hydraulic fracturing, which can be used to extract natural gas and oil from subterranean formations, such as deep shale and coal bed type rack formations. In a first aspect, the invention features a composition for hydraulic fracturing, which includes a low pH product, a surfactant, and a thickening agent, all in an aqueous composition. The composition includes i) from about 0.01 wt % to about 20.0 wt % of a low pH product that includes an ammonium salt (e.g., ammonium bicarbonate, ammonium carbonate, or ammonium hydroxide) and hydrogen chloride (and optionally a carborane).

Abstract: A method for breaking the viscosity of an aqueous fluid gelled with a water soluble polymer or a VES is disclosed. The method includes providing an aqueous fluid. The method also includes adding to the aqueous fluid, in any order: a water soluble polymer in an amount sufficient to form a gelled aqueous fluid having a viscosity, a water soluble oxidizing agent configured to generate free radicals and a plurality of metallic particles to produce a mixture comprising dispersed metallic particles dispersed within the gelled aqueous fluid, the metallic particles configured to dissolve in the gelled aqueous fluid and provide a reducing agent to accelerate the generation of free radicals. The method further includes dissolving the metallic particles in the gelled aqueous fluid to provide a source of at least one transition metal ion in an amount effective accelerate the generation of free radicals and reduce the viscosity.

Abstract: The present invention relates to a foam containing water, between 5 and 30 wt % on total weight of the foam of a chelating agent selected from the group of glutamic aid N,N-diacetic acid or a salt thereof (GLDA), aspartic acid N,N-diacetic acid or a salt thereof (ASDA), methylglycine N,N-diacetic acid or a salt thereof (MGDA), N-hydroxyethyl ethylenediamine-N,N?,N?-triacetic acid or a salt thereof (HEDTA), a foaming agent, and at least 25 vol % on total volume of the foam of a gas, and having a pH of between 2 and 5, to a viscosified composition containing water, between 5 and 30 wt % on total volume of the composition of a chelating agent selected from the group of glutamic aid N,N-diacetic acid or a salt thereof (GLDA), aspartic acid N,N-diacetic acid or a salt thereof (ASDA), methylglycine N,N-diacetic acid or a salt thereof (MGDA), N-hydroxyethyl ethylenediamine-N,N?,N?-triacetic acid or a salt thereof (HEDTA), and at least 0.

Abstract: Boronated biopolymer crosslinking agents useful in producing viscosified treatment fluids that include an aqueous fluid, a base polymer, and the boronated biopolymer crosslinking agent, wherein the boronated biopolymer crosslinking agent comprises a biopolymer derivatized with a boronic acid, a boronate ester, or both. Such viscosified treatment fluids may be useful in fracturing operations, gravel packing operations, drilling operations, and the like.

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: A composition for enhancing fluid viscosity including a mixture of at least one cationic or cationizable polymer and at least one anionic or anionizable (hydrolysable) polymer. The composition has a zeta potential at 25° C. in the range of 0.5 to 100 mV or ?0.5 to ?100 mV, typically 1 to 60 mV or ?1 to ?60 mV, or is a precursor convertible at a temperature of 100 to 250° C. to the composition having a zeta potential at 25° C. of 0.5 to 100 mV or ?0.5 to ?100 mV, typically 1 to 60 mV or ?1 to ?60 mV. Typically the compositions exhibit salt tolerance and interaction of both polymers at very high temperatures (>300° F.) such that the system exhibits an increase of viscosity at extreme temperatures. The compositions are useful for hydraulic fracturing, enhanced oil recovery, subterranean acidization, personal care as well as home and industrial cleaners.

Abstract: Improved hydraulic fracturing compositions are disclosed which help reduce potential negative environmental impact by hydraulic fracturing. The disclosed compositions have flammability and toxicity and are relatively safe for the environment. The compositions may also contain biodegradable components.

Abstract: A well treatment method includes forming a well treatment fluid by combining ingredients including a polymer, a crosslinker, an acidifying substance, and a base fluid. Crosslinking increases viscosity of the fluid during a development time. A pH decrease is controlled during the development time using the acidifying substance. The method also includes delaying the development time of the viscosity increase by controlling the pH decrease. A well treatment method includes forming a well treatment fluid by combining ingredients including a hydratable polymer, a crosslinker, an acidifying substance, and a base fluid. The method includes delaying development time of a viscosity increase by controlling a pH decrease without adding further acidifying substance after combining the polymer, crosslinker, acidifying substance, and base fluid. A well treatment fluid formulated with ingredients include a base fluid, a polymer, a crosslinker, and an acidifying substance.

Abstract: A method includes providing an oilfield treatment fluid including an aqueous HCl solution having greater than 15% HCl by weight, and a fixing agent (FA) in a molar ratio of FA:HCl of between 0.5 and 2.5 inclusive. The FA is urea and/or a urea derivative. The oilfield treatment fluid further includes a viscosifying agent that is not a plant-based polysaccharide gum. The method further includes providing the oilfield treatment fluid to a high pressure pump, and operating the high pressure pump to treat a formation fluidly coupled to a wellbore.

Abstract: Methods of treating a subterranean formation are disclosed that include placing a treatment fluid into a subterranean formation, the treatment fluid containing a one or more polymers capable of consolidating to form a polymeric structure at a downhole location. Also disclosed are treatment fluids including a polymeric structure for treating a subterranean formation.

Abstract: A thixotropic agent comprised of a gel which is comprised of a polymeric organic material cross-linked with certain boehmite aluminas having a crystallite size of less than about 100 ? as measured on the 120 plane.

Abstract: A method includes adding an amount of chlorine dioxide from about 10 ppm to about 400 ppm to an aqueous base fluid to provide a treated fluid, adding a water-soluble polymer to the treated fluid, thereby forming a hydrated polymer, the amount of chlorine dioxide added confers a viscosity increase allowing a reduction in the amount of water-soluble polymer to obtain a target viscosity by about 25% to about 75% relative to a control fluid lacking chlorine dioxide.

Abstract: A method of using a water based solution having a controllable gel time. The method includes providing a predetermined ratio of a water soluble silicate solution having at least one alkali metal, providing a predetermined ratio of a water dispersible polymer, and providing a predetermined ratio of a water soluble initiator containing a reactive carbonyl compound. One embodiment of the method also includes combining the water soluble silicate solution, the dispersible polymer, and the water soluble initiator and injecting downhole in a single stage treatment. Another embodiment of the method includes pre-mixing at least the water soluble silicate solution and the dispersible polymer into a mixture, then injecting the water soluble initiator and the mixture downhole separately for a multi-stage treatment with in situ mixing.

Abstract: Reduction of the water permeability within a subterranean formation, particularly within a proppant pack or a gravel pack, can be achieved through the use of a relative permeability modifier (RPM) coated on a particulate material. Methods for reducing the water permeability include providing RPM-coated particulates that contain a RPM coating on the particulates, and placing a treatment fluid containing a base fluid and the RPM-coated particulates in at least a portion of a subterranean formation. The treatment fluid can also contain a companion polymer that serves to further reduce the water permeability compared to that achievable when using the RPM alone.

Abstract: Methods of treating a subterranean formation including providing a treatment fluid comprising a brine base fluid and an anionic carboxylated polysaccharide, wherein the brine base fluid comprises a concentration of salt in the range of from about 30,000 ppm to saturation and a pH in the range of from about 4 to about 8, and wherein the anionic carboxylated polysaccharide is present in the range of from about 0.05% to about 2% by weight of the treatment fluid; and introducing the treatment fluid into the subterranean formation.

Abstract: A granulated mica composition may include mica having an average particle size less than about 20 mesh, and 0.01% to about 1.0% of a water soluble binder. The granulated mica composition may have a granule size greater than about 20 mesh. A process for producing a granulated inorganic particulate composition for use in oilfield applications may include mixing at least one inorganic particulate having an average particle size of less than about 20 mesh with water and at least one binder, and agglomerating the resulting mixture to form a granulated inorganic particulate having an average particle size of greater than about 20 mesh. A method for treating a subterranean formation may include admixing a granulated inorganic particle composition into a fluid, such that the inorganic particulate is dispersed into the fluid as a suspended inorganic particulate, and injecting the fluid and suspended inorganic particulate into the subterranean formation.

Abstract: The invention discloses a method of treating a wellbore by providing an aqueous mixture of a hydrated polysaccharide with a salt; adding to the mixture a cross-linking agent for cross-linking the hydrated polysaccharide, wherein the cross-linking agent comprises a zirconium compound, glutamic acid, and a polyol; pumping the aqueous mixture of the hydrated polysaccharide and the cross-linking agent into the wellbore; and cross-linking the hydrated polysaccharide.

Abstract: Ceramic propping agents include a plastic clay, aluminosilicate network modifier, strength enhancing agent, and binder. Usable strength enhancing agents can include nepheline materials having 0.1 to 5 percent iron oxide by weight. A resin coating can be used to encapsulate particles of the ceramic propping agent. The propping agent can be produced by grinding the components to the same approximate particle size, nucleating the particles by adding water, growing the resulting spherical pellets by adding additional particles that adhere to the surface of the spherical pellets, and vitrifying the pellets to form the propping agent.

Abstract: A method, system, and composition for producing oil from a formation utilizing an oil recovery formulation comprising a surfactant, an ammonia liquid, an alkali metal carbonate or bicarbonate, a polymer, and water are provided.

Abstract: A cement composition for use in an oil or gas well, the cement composition comprises: a calcium aluminate cement; water; an organic acid; and a polymeric mixture comprising: (A) water; (B) citric acid; (C) a first polymer, wherein the first polymer: (i) comprises a cellulose backbone and carboxymethyl functional groups; and (ii) has a molecular weight of less than 100,000; and (D) a second polymer, wherein the second polymer: (i) comprises a lignosulfonate; and (ii) has a molecular weight of less than 100,000, wherein a test composition consisting essentially of: the cement; the water; the organic acid; and the polymeric mixture, and in the same proportions as in the cement composition has a thickening time of at least 5 hours at a temperature of 300° F. (148.9° C.) and a pressure of 10,000 psi (68.9 MPa).

Abstract: Treatment of a subterranean formation can be conducted with viscosified treatment fluids that comprise a multifunctional boronic acid crosslinking agent. Methods for treating a subterranean formation can comprise providing a treatment fluid that comprises an aqueous base fluid, a gelling agent, and a multifunctional boronic acid crosslinking agent that comprises a copolymer comprising at least one boronic acid monomer unit and at least one water-soluble monomer unit; and introducing the treatment fluid into a subterranean formation.

Abstract: Fracturing fluid compositions and methods of fracturing subterranean formations using polyboronic compounds as crosslinking agents are provided. The compositions and methods of the present invention allow for lower polymer loadings because achieving higher fracturing fluid viscosities can be achieved using less polymer than in traditional crosslinked systems.

Abstract: Fluid loss materials including carboxymethylcellulose and zirconium-based crosslinkers may be employed as fluid loss materials in methods of treating subterranean formations. One method includes providing a treatment fluid including carboxymethylcellulose (CMC) and a crosslinker including zirconium, wherein the carboxymethylcellulose has a degree of substitution in a range of from about 0.5 to about 2.

Abstract: The invention provides for modified proppants, comprising a proppant particle and a hydrogel coating, wherein the hydrogel coating localizes on the surface of the proppant particle to produce the modified proppant, methods of manufacturing such proppants and methods of use.

Abstract: Disclosed are treating fluid compositions for use in subterranean workover and hydrocarbon recovery operations, as well as methods of treating subterranean formations penetrated by a wellbore utilizing the treating fluid. The treating fluid compositions contain a first, aqueous liquid, and a crosslinkable organic polymer that is at least partly soluble in the liquid. The treating fluid further contains a borate crosslinking agent solution containing a primary, un-refined borate and a secondary, refined borate, the borate solution being present as a crosslinking agent upon addition to the first fluid admixture so as to crosslink the organic polymer and increase the viscosity and/or accelerate the crosslink time of the treating fluid.

Abstract: An enhanced oil recovery formulation composition containing a sacrificial agent and a surfactant dispersed in a fluid is provided. The sacrificial agent reduces the amount of surfactant required to enhance oil recovery from a petroleum-bearing formation. The sacrificial agent is selected from the group consisting of a compound comprising a single carboxylic acid, a single carboxylic acid derivative, or a single carboxylate salt, or a compound lacking a carboxylic acid group, a carboxylate group, a sulfonic acid group, or a sulfonate group that is a pheol, a sulphonamide, or a thiol, or a compound having a molecular weight of 1000 or less that comprises one or more hydroxyl groups.

Abstract: The invention provides for modified proppants, comprising a proppant particle and a hydrogel coating, wherein the hydrogel coating localizes on the surface of the proppant particle to produce the modified proppant, methods of manufacturing such proppants and methods of use.

Abstract: The invention provides for modified proppants, comprising a proppant particle and a hydrogel coating, wherein the hydrogel coating localizes on the surface of the proppant particle to produce the modified proppant, methods of manufacturing such proppants and methods of use.

Abstract: An aqueous composition for removing scale deposits, especially on subsea equipment and a method of using the same is described. The aqueous composition comprises (a) a potassium phosphate compound; and (b) acetic acid. The composition is capable of dissolving away into seawater and poses little or no risk to the environment.

Abstract: The present invention provides modified proppants, and methods for their manufacture. In embodiments, the modified proppant comprises a proppant particle and a hydrogel coating, wherein the hydrogel coating is applied to a surface of the proppant particle and localizes on the surface to produce the modified proppant. In embodiments, formulations are disclosed comprising the modified particles, and methods are disclosed for using the formulations.

Abstract: Treating fluid compositions for use in hydrocarbon recovery operations from subterranean formations are described, as well as methods for their preparation and use. In particular, treating fluid compositions are described which comprise a liquid, a crosslinkable organic polymer material that is at least partially soluble in the liquid, a crosslinking agent that is capable of increasing the viscosity of the treating fluid by crosslinking the organic polymer material in the liquid, and a crosslinking modifier additive which can delay or accelerate the crosslinking of the treating fluid composition. Such compositions may be used in a variety of hydrocarbon recovery operations including fracturing operations, drilling operations, gravel packing operations, water control operations, and the like.

Abstract: Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include nitrogen generating compounds, which upon activation, react to generate heat and nitrogen gas.

Abstract: A downhole sealant includes a composition that includes a polymer; an absorbent material; a primary crosslink network including primary bonds between chains of the polymer; and a secondary crosslink network which is transient. A method of regulating the swell rate of the downhole sealant includes disposing a downhole sealant comprising a polymer and an absorbent material in a borehole; maintaining a primary crosslink network of the polymer; and decomposing a secondary crosslink network of the absorbent material in response to a condition to regulate the swell rate of the downhole sealant.

Abstract: A fracking fluid hydration unit is provided that has a plurality of hydration tank sections wherein shear is added to the hydrated fluid flow via a recirculation hydrated fluid jetting system.

Abstract: A method for breaking the viscosity of an aqueous fluid gelled with a water soluble polymer or a VES is disclosed. The method includes providing an aqueous fluid. The method also includes adding to the aqueous fluid, in any order: a water soluble polymer in an amount sufficient to form a gelled aqueous fluid having a viscosity, a water soluble oxidizing agent configured to generate free radicals and a plurality of metallic particles to produce a mixture comprising dispersed metallic particles dispersed within the gelled aqueous fluid, the metallic particles configured to dissolve in the gelled aqueous fluid and provide a reducing agent to accelerate the generation of free radicals. The method further includes dissolving the metallic particles in the gelled aqueous fluid to provide a source of at least one transition metal ion in an amount effective accelerate the generation of free radicals and reduce the viscosity.

Abstract: Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include nitrogen generating compounds, which upon activation, react to generate heat and nitrogen gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, heat and nitrogen gas are generated. Upon the generation of nitrogen gas and heat within the formation, microfractures are produced within the formation and the hydrostatic pressure within the reservoir is reduced to less than the reservoir fluid pressure, such that the rate of production of hydrocarbons from the formation is increased.

Abstract: A method comprises providing a treatment fluid comprising a gelling agent, an aqueous base fluid, a buffer composition comprising a plurality of salts, and a crosslinking agent; and contacting a subterranean formation with the treatment fluid. The aqueous base fluid is preferably seawater and the buffer composition includes one or more salts present in the treatment fluid from about 1 to about 1000 pounds per gallon of treatment fluid.

Abstract: Methods and compositions for breaking treatment fluids utilized in the stimulation of a subterranean formation.

Abstract: A flooding fluid for use in petroleum recovery from a petroleum-bearing formation is prepared by mixing an oxygen scavenger consisting essentially of an alkaline aqueous solution of at least one water-soluble borohydride with an aqueous or nonaqueous input fluid having oxygen dissolved therein to reduce the level of dissolved oxygen.

Abstract: Fracturing fluid compositions and methods of fracturing subterranean formations using polyboronic compounds as crosslinking agents are provided. The compositions and methods of the present invention allow for lower polymer loadings because achieving higher fracturing fluid viscosities can be achieved using less polymer than in traditional crosslinked systems.

Abstract: The current application discloses a method of treating a portion of a subterranean formation comprises providing a treatment fluid comprising a carrier fluid, a non-hydrolyzed polyacrylamide or a nonhydrolyzed non ionic copolymer of acrylamide, and a delaying agent; and treating the subterranean formation.

Abstract: A method of treating a portion of a subterranean formation comprises providing a treatment fluid comprising a carrier fluid, a viscosifying agent, a breaker, and a breaker aid wherein the breaker aid slowly releases a catalyst, wherein the viscosifying agent and the breaker in the carrier fluid have an initial viscosity and the catalyst and the breaker cooperate to decrease the viscosity of the treatment fluid below half of the initial viscosity after at least 30 minutes; and treating the subterranean formation.

Abstract: A method of forming a wellbore fluid, the method including introducing a hydratable polymer and introducing a crosslinker comprised of at least a silica material, the crosslinker having a dimension of from about 5 nm to about 100 nm.

Abstract: The present invention relates to compositions and use of fluidized polymer suspensions containing allyloxy linkage and its functional derivatives, and water soluble polymers for use in oil field applications as fluid additives for drilling and cementing processes.

Abstract: The concentrate solution for the crosslinking of polymers comprises water, polyol, a viscosifying agent, a first borate ion in solution, and a crosslinking agent able to release a second borate ion, wherein the second borate ion is not in solution.

Abstract: This invention relates to fluid compositions used in treating a subterranean formation. In particular, the invention is aqueous wellbore treatment compositions which are foams containing a viscosifying agent, a foam extender, a gas component, and a surfactant, as well as methods of forming such fluids, and uses thereof. The viscosifying agent may be a hydratable polymer, viscoelastic surfactant, or heteropolysaccharide. The foam extender may be a material such as a polyoxyalkyleneamines, ethylenepolyamines, tertiary polyamines, bicarbonate, carbonate, phosphate, or sesquicarbonate.

Abstract: A method for treating a subterranean formation is made of steps of providing a composition comprising a carrier fluid, a polymer viscosifying agent, carbon dioxide and a formate salt or formic acid; injecting into a wellbore, the composition; contacting the composition with the subterranean formation, wherein the temperature is above 100 degrees Celsius at this contact; and allowing the composition to treat the subterranean formation.

Abstract: Methods and compositions that include a method of cementing comprising providing a cement composition comprising water, a hydraulic cement, and an additive comprising at least one additive selected from the group consisting of a stevia retarder and inulin; placing the cement composition in a subterranean formation; and permitting the cement composition to set in the formation.

Abstract: A drilling fluid includes a base fluid and a circulation loss reducing additive package having a polysaccharide, a cellulose derivative and a pH controlling component.