Abstract: Pre-coated particulate for use in a subterranean operation comprising a particulate; and a film coated onto a surface of the particulate. The film is formed by allowing an anionic polymer and a cationic surfactant to contact the surface of the particulate, and allowing the anionic polymer and the cationic surfactant to interact with each other. In some cases, the anionic polymer is selected from the group consisting of a polyacrylamide; an alkylpolyacrylamide; a copolymer of polyacrylamide, with ethylene, propylene, and styrene; a copolymer of alkylpolyacrylamide with ethylene, propylene, and styrene; a polymaleic anhydride; and any derivatives thereof.

Abstract: The invention discloses a method of creating a polymerized composition in a well bore: providing a polymerizable composition made of a polymerization initiator and a monomer polymerizable by frontal polymerization; introducing the polymerizable composition into the wellbore; exposing the polymerizable composition to a trigger to activate the frontal polymerization; and creating the polymerized composition.

Abstract: Composition comprising a plurality of particulates wherein at least some particulates are at least partially covered with a coating that impedes the intrusion of water into the particulates; and, a silica scale control additive, wherein the silica scale control additive is capable of suppressing silica scale build-up proximate the plurality of particulates. Some compositions further include a treatment fluid wherein and the silica scale control additive are present in the treatment fluid.

Abstract: The invention provides an environmentally friendly composition including a friction reducer, a biocide, a scale inhibitor, and optionally a clay stabilizer.

Abstract: The instant invention pertains to a composition which may be useful for enhancing oil recovery. The composition typically comprises the reaction mixture of at least (a) two or more compounds capable of generating at least about 20 kcal to about 150 kcal per mole when contacted; (b) one or more suitable surfactants or one or more suitable polymers or a mixture thereof; and (c) oil. The invention also pertains to a method for enhancing oil recovery wherein a suitable system is injected through a wellbore into a reservoir to enhance mobility of oil.

Abstract: Disclosed herein is a well treatment fluid comprising an aqueous solution comprising greater than or equal to about 1 wt % boron, at least 5 wt % of a co-solvent, and greater than or equal to about 5 wt % sodium hydroxide, potassium hydroxide, or a combination thereof, wherein the co-solvent comprises glycerol, ethylene glycol, propylene glycol, or a combination thereof. Methods of using the well treatment fluid are also disclosed.

Abstract: A “slick water” fluid for hydraulic fracturing of wells is provided that is mixed by adding solid polymer and solid additives to water. The fluid may be batch mixed or mixed in a continuous process using standard blending equipment. Components are selected that are environmentally preferred. Lower cost and environmental benefits are realized.

Abstract: A method includes performing a chemical process to create a chemical product and an amount of heat, and transferring the heat to a first fluid. The method further includes hydrating a polymer in the first fluid, and adding the chemical product from the chemical process to the first fluid to create a treatment fluid. The method further includes diluting the treatment fluid with respect to at least one constituent of the treatment fluid. The method includes treating a formation of interest in a wellbore with the treatment fluid. The method includes changing a formulation of the treatment fluid during the treating. The method also includes extending the treating beyond a design amount, or ending the treatment before the design amount and preserving some reagents of the chemical process.

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: Disclosed herein is a gel or a gel concentrate comprising, polyacrylamide crosslinked with a non-metallic crosslinker comprising a polylactam. A well treatment fluid comprising the gel or the gel concentrate, a method of making the gel or the gel concentrate, and a method of using the gel or the gel concentrate are also disclosed.

Abstract: A wellbore fluid that includes an oleaginous base fluid; and a silanated weighting agent is disclosed. In particular, the silanated weighting agents may be produced by reaction between an alkyl alkoxy silane and a weighting agent Methods of formulating such fluids and methods of drilling using such fluids are also disclosed.

Abstract: Disclosed herein is a gel comprising, polyacrylamide crosslinked with a non-metallic crosslinker, the non-metallic crosslinker comprising a polyamine. A method of making the gel and a method of using the gel are also disclosed.

Abstract: The present invention describes the use of EDTA and/or alkali treated hard brine at high pH for making ASP formulations for EOR applications.

Abstract: A process for mineral oil production, in which an aqueous formulation comprising at least one water-soluble, hydrophobically associating copolymer (A) and at least one nonionic and/or anionic surfactant (B) is injected through at least one injection borehole into a mineral oil deposit, and crude oil is withdrawn from the deposit through at least one production borehole, wherein the water-soluble, hydrophobically associating copolymer comprises at least acrylamide or derivatives thereof, a monomer having anionic groups and a monomer which can bring about the association of the copolymer, and aqueous formulation, which is suitable for execution of the process.

Abstract: Water-soluble, hydrophobically associating copolymer comprising a monoethylenically unsaturated, water-soluble, surface-active monomer (a), and a monoethylenically unsaturated, hydrophilic monomer (b) different from monomer (a). The copolymer is prepared in the presence of a nonpolymerizable surfactant and has marked thickening properties in aqueous systems.

Abstract: What is proposed is the use of a water-soluble hydrophobically associating copolymer as an additive in the development, exploitation and completion of underground mineral oil and natural gas deposits and in deep drillings, wherein the copolymer comprises (a) at least one monoethylenically unsaturated monomer (a) selected from H2C?C(R1)—R4—O—(—CH2—CH2—O—)k—(—CH2—CH(R3)—O—)l—R5 ??(I), and/or H2C?C(R1)—O—(—CH2—CH2—O—)k—R2 ??(II), and (b) at least one monoethylenically unsaturated, hydrophilic monomer (b) different from monomer (a), wherein the copolymer is obtainable through copolymerization of the monomers (a) and (b) in the presence of at least one surfactant (c).

Abstract: The present disclosure is directed to a method comprising: mixing (i) a zwitterionic polymer prepared by inverse emulsion polymerization of at least one monomer Ab comprising a betaine group and optionally one or more nonionic monomers Ba, (ii) a surfactant and (iii) produced water to form a well servicing fluid. The resulting well servicing fluid is introduced into a hydrocarbon well.

Abstract: A wellbore fluid contains a viscosifying polymer in which portions of the polymer are connected through formation of an inclusion complex involving cucurbituril 8 (i.e. CB[8]) as host molecule. The fluid contains guest molecules with first and second guest groups covalently attached wherein at least one of the guest molecules comprises a polymer chain. The CB [8] host and the guest molecules attach together through reception of first and second guest groups within CB[8] host cavities, thereby connecting polymer chains together as a larger, supramolecular polymer and enhancing viscosity of the fluid. Polymer molecules may be synthetic polymers and guest groups may be attached to monomers before polymerization. Alternatively guest groups may be attached to existing polymers which may be polysaccharide.

Abstract: A process for treatment of produced water obtained from an enhanced oil recovery process from a reservoir, said water containing at least one water-soluble polymer, wherein: an oxidising agent is injected into produced water in a quantity such that the viscosity of said water is reduced to a value below 2 cps, advantageously of the order of 1.5 cps, in a short period from the injection of the oxidising agent, a reducing agent is then injected in the necessary quantity to neutralise all the resulting excess oxidising agent.

Abstract: A copolymer containing, as monomer components, a) at least one sulfonic acid-containing compound, b) at least one nitrogen-containing N-vinylamide, one acrylamide or methacrylamide and c) at least one bifunctional or higher-functional vinyl ether is proposed. These copolymers are suitable in particular as thixotropic agents, antisegregation agents and water retention agents and overall as an additive in cement-containing but also gypsum-based systems. Such copolymers having a molecular weight of >40 000 g/mol can be used in particular as admixtures in the exploration of mineral oil and natural gas deposits.

Abstract: Of the methods provided in this invention, one method includes: providing a treatment fluid comprising: an aqueous fluid, a microemulsion surfactant, and an amphiphilic polymer, wherein the amphiphilic polymer comprises a hydrophobic component, and a hydrophilic component; and introducing the treatment fluid into a subterranean formation, wherein the microemulsion surfactant forms a microemulsion that comprises the amphiphilic polymer within the subterranean formation.

Abstract: A method of preparing and using a subterranean formation stabilization agent. The stabilization agent includes a guanidyl copolymer and may be admixed with a fracturing fluid and optionally brine. The stabilization agent is effective in preventing and/or reducing, for example, clay swelling and fines migration from a subterranean formation contacted with the stabilization agent.

Abstract: The subject disclosure discloses mechanisms for embedding and controlling multifunctional additives within a polymer matrix for use in oilfield applications. More particularly, the subject disclosure discloses methods of treating a subterranean formation with a polymer matrix comprising one or a plurality of polymers and one or a plurality of functional additives embedded into this polymer matrix.

Abstract: Composition based on anionic polymers or water-soluble amphoteric (co)polymers suitable for viscosifying the injection fluids for oil recovery, characterized in that, before dilution with the injection fluid, it further contains at least 3 stabilizing agents selected from the group comprising oxygen reducing agents, precipitating agents, free radical scavengers, complexing agents and sacrificial agents, the said stabilizing agent being suitable for preventing the chemical degradation of the polymer once the polymer is introduced into the injection fluid.

Abstract: In one embodiment, the present invention provides a fluid comprising: an aqueous base fluid; and a gelling agent that comprises a polymerizable polycarboxylic acid and that is at least partially crosslinked by a crosslinking reaction comprising a crosslinking agent.

Abstract: The invention discloses a cement slurry composition for cementing a well comprising: an hydraulic cement, water and a combination made of a cellulosic polymer and an acrylamido-methyl-propane sulfonate co- or ter-polymer, wherein the density of said cement slurry is above 1700 kg/m3.

Abstract: This invention provides polymers having side chain groups selected from at least one of the following: a) a group comprising an ester of a polycarboxylic acid or polycarboxylate salt, an aminoalkylphosphate ester, or an ammoniumalkylphosphate ester; b) a group comprising (1) an alkanolamino group, (2) a fatty quaternary ammonium moiety, (3) a heterocyclic ring moiety having at least five members, which ring has at least one nitrogen atom, said ring further comprising either unsaturation or at least one additional heteroatom, or (4) both (2) and (3) c) a group comprising an alkylamino ethoxylate or an alkylamino propoxylate; d) a group comprising a trialkylhexahydrotriazine moiety; e) a group comprising a fatty alkyl ester; and f) a group comprising (i) a group as in a), and (ii) a group as in b). Also provided are processes for preparing polymers having such side chain groups.

Abstract: A method of preparing and using a drag-reducing composition in a well treatment operation includes the step of preparing the drag-reducing composition by mixing a polymer emulsion that includes a first surfactant and a first solvent, with a second surfactant and a second solvent. The method continues with the step of combining the drag-reducing composition with an aqueous treatment fluid. The method further includes the step of injecting the drag-reducing composition and aqueous treatment fluid into a subterranean formation, a pipeline or a gathering line.

Abstract: Methods of processing a fluid recovered from an oil or gas extraction operation for reuse in a hydraulic fracturing fluid are described. The methods include providing an amount of a produced fluid composition containing iron and suspended solids and controlling at least one of the conductivity, iron content, oxidative strength, and pH of the composition, such that Fenton's reagent is formed in situ. Also described are hydraulic fracturing fluids produced using fluid recovered from an oil or gas production process and treated in accordance with the methods described herein as well as systems for preparing a hydraulic fracturing fluid having, as a fluid source, fluid recovered from an oil or gas production process that has been treated in accordance with the methods described herein.

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: Clay is stabilized in the drilling of wells and other formation treatment for hydrocarbon production by the addition to the drilling or other fluid including a choline compound together with an formation control additive.

Abstract: This invention relates to compositions and methods for treating subterranean formations, in particular, oilfield stimulation compositions and methods using water-in-water polymer emulsions to uniformly dissolve a rheologically active polymer, such as a thickener or friction reducer, in the treatment fluid. The emulsions have a low viscosity and are easily pumped for mixing into a treatment fluid, where upon dilution with an aqueous medium, the polymer is easily hydrated without forming fish-eyes. The partitioning agent in the water-in-water emulsion does not generally affect the rheology of the treatment fluid. The invention also relates to further processing of the emulsion by wet grinding, high shear mixing and/or heating to enhance the hydration rate in the preparation of the well treatment fluid.

Abstract: The invention provides a method made of steps of providing a composition comprising a first chemical component and a degradable protective layer, wherein the degradable protective layer is at least partially degradable when subject to temperature, pH or time; and introducing into a wellbore the composition and allowing the degradable protective layer to degrade and release the first chemical component.

Abstract: A fracturing fluid may include water; at least one polymeric viscosifier; at least one proppant; and a solution of peracetic acid in an amount effective to inhibit bacterial growth. Other embodiments are directed to methods for inhibiting bacterial contamination in a fracturing fluid and/or ballast water.

Abstract: Drilling, drill-in and completion fluids containing nanoparticles for use in hydrocarbon drilling and recovery processes and methods related thereto are provided. The fluids also include a dual acting shield agent that shields the nanoparticles and also acts as a viscosifier. The fluids can be used in various types of hydrocarbon drilling and recovery processes, such as drilling, drill in, completion, and the like.

Abstract: A method for enhancing recovery of crude oil from a porous subterranean formation of which the pore spaces contain crude oil and connate water comprises:—determining the Ionic Strength (Mol/l) of the connate water; and—injecting an aqueous displacement fluid having a lower Ionic Strength (Mol/l) than the connate water into the formation, which aqueous displacement fluid furthermore has an Ionic Strength below 0.15 Mol/l. FIGS. 13 and 16 and Table 4 demonstrate that injection of an aqueous displacement fluid with lower Ionic Strength than the connate water improves oil recovery (IOR).

Abstract: The present invention relates to aqueous tackifiers and methods of controlling particulates in subterranean formations using aqueous tackifiers. Some embodiments of the present invention provide methods of controlling particulates, comprising placing an aqueous tackifier compound into a portion of a subterranean formation comprising unconsolidated particulates; and, activating the aqueous tackifier compound. Other embodiments of the present invention provide methods of coating a portion of a surface in a subterranean formation comprising substantially coating an aqueous tackifier compound onto a portion of a subterranean formation; and, activating the aqueous tackifier compound. Other embodiments of the present invention provide treatment fluids for controlling fine particulates, comprising a servicing fluid and an aqueous tackifier compound.

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: Compositions and methods for oil recovery using a surfactant-less alkaline-polymer system in hard water or hard brine is described in the instant invention. The formulation further includes a chelating agent, an alkaline agent (which can be the same as the chelating agent), and a co-solvent. The formulations as disclosed herein are capable of forming a surfactant in-situ resulting in Winsor Type III micro-emulsions of low interfacial tension.

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: The invention discloses a method comprising providing a fluid comprising a viscosifying agent in an aqueous medium; contacting the fluid with a halogenisocyanuric acid or halogenisocyanurate component; whereby the viscosity of the fluid with the halogenisocyanuric acid or halogenisocyanurate component is reduced compared to the viscosity of the fluid alone; and introducing the fluid into a well. The halogenisocyanuric acid component can be mono chloroisocyanuric acid, dichloroisocyanuric acid or trichloroisocyanuric acid. The halogenisocyanurate component can be an alkali metal monochloroisocyanurate, alkali metal dichloroisocyanurate or alkali metal trichloroisocyanurate.

Abstract: The invention discloses a method comprising providing a fluid comprising a viscosifying agent in an aqueous medium; contacting the fluid with a N-halogenated derivative of hydantoin; whereby the viscosity of the fluid with the N-halogenated derivative of hydantoin is reduced compared to the viscosity of the fluid alone; and introducing the fluid into a well. The N-halogenated derivative of hydantoin can be dichlorodimethylhydantoin (DCDMH), bromochlorodimethylhydantoin (BCDMH), or dibromodimethylhydantoin (DBDMH). The N-halogenated derivative of hydantoin can be 1,3-Dichloro-5,5-dimethylhydantoin or 1,3-Dibromo-5,5-dimethylhydantoin.

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: The present invention includes methods and compositions relating to the setting of fluids or slurries in a wellbore. In one embodiment, a method of isolating a portion a wellbore includes preparing a sealant composition having a fluid component, a polymeric additive constituent, and a set modifier component. The sealant composition is placed into a wellbore and subjected to ionizing radiation. The ionizing radiation can cause bonding between polymeric additive constituents and create a polymer matrix within the sealant composition that increases the mechanical strength of the sealant composition. The ionizing radiation also alters the set modifier component, triggering the thickening of the sealant composition.

Abstract: The present invention relates to the preparation of foaming formulations for high temperature, salinity and concentration of divalent ions, such as Calcium and Magnesium, that apply the synergistic effect of sodium alpha olefin sulfonates and alkyl amido propyl betaines; said inventions may use, as solvent, water, sea water, connate water, alcohols or mixtures all thereof. Said formulations control the piping of gas in reservoirs of the naturally fractured carbonate type.

Abstract: The present invention relates to methods useful for isolating a portion of a wellbore. In one embodiment, a method includes preparing a sealant composition containing a set modifier component. The sealant composition is placed into the wellbore and is subjected to ionizing radiation that alters the set modifier component, triggering the thickening of the sealant composition.

Abstract: Of the many embodiments presented herein, one is a subterranean treatment fluid comprising: an aqueous fluid; and a water-soluble degradable synthetic vinyl polymer having a labile link in its backbone. Also provided in one instance is a water-soluble degradable synthetic vinyl polymer with labile group in its backbone made by a redox polymerization, the redox polymerization reaction comprising these reactants: a macroinitiator that comprises a labile link, an oxidizing metal ion, and a vinyl monomer.

Abstract: This invention relates to compositions and methods for treating subterranean formations, in particular, oilfield stimulation compositions and methods using water-in-water polymer emulsions to uniformly dissolve a rheologically active polymer, such as a thickener or friction reducer, in the treatment fluid. The emulsions have a low viscosity and are easily pumped for mixing into a treatment fluid, where upon dilution with an aqueous medium, the polymer is easily hydrated without forming fish-eyes. The partitioning agent in the water-in-water emulsion does not generally affect the rheology of the treatment fluid. The invention also relates to further processing of the emulsion by wet grinding, high shear mixing and/or heating to enhance the hydration rate in the preparation of the well treatment fluid.

Abstract: This invention relates to compositions and methods of treating a subterranean formation penetrated by a well bore including providing a treatment composition comprising a rheological polymer, a partitioning agent, a charged polyelectrolyte, and a first liquid medium, forming a stabilized heterogeneous mixture comprising a dispersed rheological polymer-rich phase and a partitioning agent-rich phase, and injecting the treatment fluid into the well bore. The invention relates to methods and compositions for preparing a well treatment fluid, including mixing polyethylene glycol partitioning agent, a charged polyelectrolyte, a first aqueous medium, and one or more rheological polymers selected from the group consisting of guar, modified guar, cellulose, modified cellulose, heteropolysaccharide, heteropolysaccharide derivative, or polyacrylamide, to hydrate the one or more polymers and form a water-in-water emulsion, and mixing the water-in-water emulsion with a second aqueous medium to form a well treatment fluid.

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.