Abstract: The invention discloses a three-dimensional cage-like hyperbranched monomer and preparation method and application thereof. The three-dimensional cage-like hyperbranched monomer has the structural formula I: wherein in the structural formula I: X is any one of —O, —S, —NH; y is any integer from 2 to 8; R is —H or —CH3. The beneficial effect of the technical scheme proposed in the present invention is: by introducing easily polymerizable olefin groups, the carboxyl group and amide group are combined in the three-dimensional cage-like hyperbranched monomer to make the water solubility good, and it can be copolymerized with many other monomers to obtain the three-dimensional cage-like hyperbranched polymer; when used as an additive for wellbore working fluids, due to the hyperbranched structure of the polymer, it has good salt and temperature resistance, and also has viscosity increasing, filtration loss, and flocculation properties; meanwhile, the synthesis method is simple and the cost is low.

Abstract: The present invention relates to a method for enhanced oil recovery by flushing an underground formation, comprising the injection into the underground formation of an aqueous composition comprising microgels having at least one crosslinked polymer, characterized in that the polymer is crosslinked with at least one crosslinking agent capable of being degraded under the temperature conditions of the underground formation, and a content of crosslinking agent between 1 and 90 ppm per mole with respect to the total number of moles of monomer constituting the polymer.

Abstract: A composition comprising a water-soluble powder that is agglomerated by a water-soluble wax, which is then allowed to cool and re-solidify to product clusters of the water-soluble powder.

Abstract: A composition including a coated nanoparticle including a nanoparticle and a cross-linked carbohydrate-based coating and an ion selected from the group consisting of Li+, Na+, K+, Rb+, Cs+, Be2+, Mg2+, Ca2+, Sr2+, Ba2+, and mixtures thereof; methods of making and using the composition; and systems including the composition.

Abstract: A composition including a coated nanoparticle including a nanoparticle and a cross-linked carbohydrate-based coating and an ion selected from the group consisting of Li+, Na+, K+, Rb+, Cs+, Be2+, Mg2+, Sr2+, Ba2+, and mixtures thereof; methods of making and using the composition; and systems including the composition.

Abstract: Gellable treatment fluids containing an amps-acrylamide bipolymer and a suitable surfactant can be used in various subterranean operations where it is necessary for the treatment fluid to remain in a gelled state for extended periods of time at high formation temperatures. The gellable treatment fluids are thermally-stable, solids-free self-degrading treatment fluid compositions useful in fluid loss pill, kill pill, perforation pill and other gel treatment applications.

Abstract: Design and preparation of a smart system, including a hydrophilic polymer nanoparticle as a core material and a hydrophilic-hydrophobic block copolymer as a coating nanolayer for use in a smart core-shell nanostructure flooding during enhanced oil recovery (EOR) process. The hydrophilic polymers are prepared by an inverse emulsion method. The central core of this nanostructure includes hydrophilic polymer. The nanolayer can be a surfmer. The binary properties of the shell and hydrophilic polymers increase the water viscosity in the water-oil interface and enhance oil recovery.

Abstract: Fluid treatment systems and compositions are provided including (a) at least one material including (1) at least one carboxylic acid functional group and (2) at least one sulfur-containing group selected from the group consisting of sulfonyl functional groups, sulfonate functional groups and mixtures thereof; and (b) at least one friction reducing agent selected from the group consisting of guar gums, polyacrylamides, hydratable cellulosic materials, viscoelastic surfactants, and mixtures thereof. The fluid treatment systems and compositions can be used to treat aqueous systems, for example as fracturing fluids for use in fracturing subterranean formations. Methods for inhibiting formation and/or precipitation of metal oxides in an aqueous composition using the fluid treatment systems or compositions also are provided.

Abstract: Fluid treatment systems and compositions are provided including (a) at least one material including (1) at least one carboxylic acid functional group and (2) at least one sulfur-containing group selected from the group consisting of sulfonyl functional groups, sulfonate functional groups and mixtures thereof; and (b) at least one scale control agent. The fluid treatment systems and compositions can be used to treat aqueous systems, for example as fracturing fluids for treating aqueous compositions found in subterranean formations. Methods for inhibiting formation and/or precipitation of calcium salts in an aqueous composition using the fluid treatment systems or compositions also are provided.

Abstract: A aqueous solution that includes water, from 100,000 to 300,000 ppm of dissolved solids, from 0.5 to 3 gallons per thousand gallons of a water-in-oil emulsion, and an inverting surfactant. The water-in oil emulsion includes an oil phase and an aqueous phase where the oil phase is a continuous phase comprising an inert hydrophobic liquid and the aqueous phase is present as dispersed distinct particles in the oil phase. The aqueous phase contains water, a water soluble polymer, and surfactants. The water soluble polymer includes 30 to 50 weight percent of a non-ionic monomer, 5 to 15 weight percent of a sulfonic acid containing monomer, and 40 to 60 weight percent of a cationic monomer. The water soluble polymer makes up from 10 to 35 weight percent of the water-in-oil emulsion.

Abstract: Crosslinked gelling agents employed during subterranean operations use electronically-modified boronic acids to enable higher operating temperatures while allowing reduced gelling agent loadings; the boronic acids having Formula I: X1 and X2 are independently selected from O, CH2, CH2O, OCH2, bond, and null, Y1 and Y2 are independently N or C, Ar is a 5- or 6-membered ring aryl or heteroaryl group with a link L to monomer unit M1, m is 1 or 2, n is 0, 1, 2, or 3, and each Z is independently an electron withdrawing group selected from nitro, ester, carboxylic acids, carboxylates, halogen, cyano, amide, acyl, alkylsulfonyl, arylsulfonyl, heteroarylsulfonyl, CF3, a quaternary ammonium salt, polyhaloalkyl, and carbamate, with the proviso that when n is 0, the link L between M1 and Ar includes an electron withdrawing group attached to Ar, and introducing the treatment fluids into subterranean formations.

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: A hydraulic fracturing composition includes: a superabsorbent polymer in an expanded state; a plurality of proppant particles disposed in the superabsorbent polymer; a well treatment agent, and a fluid to expand the superabsorbent polymer into the expanded state. A process for treating a well with well treatment agent includes disposing a hydraulic fracturing composition comprising the well treatment agent in a well. The well treatment agent can be a scale inhibitor, tracer, pH buffering agent, or a combination thereof.

Abstract: A crosslinking composition for hydrocarbon gels containing phosphate ester gelling agents comprising a modified imidazoline or pyrimidine including an alkyl group (or unsaturated carbon chain) or of 10 to 22 carbon atoms, a polyamine, and ferric sulfate. The method of making the crosslinking agent features adding the polyamine after reaction of the other ingredients; unique gels formed with the crosslinking agent are particularly effective for LNG at very cold temperatures.

Abstract: The invention provides for the use of a copolymer, comprising a) 0.1 to 10 mol-%, based on the weight of the copolymer, of structural units derived from vinylphosphonic acid or of a salt thereof, b) 40 to 80 mol-%, based on the weight of the copolymer, of structural units derived from compounds of the formula (1) c) 1 to 50 mol-%, based on the weight of the copolymer, of structural units derived from compounds of the formula (5) in which X is OH or NR3R4, and R3 and R4, independently of one another, are H or C1-C4-alkyl, for the inhibition and/or dispersion of inorganic sulphide scales, and for a process for the inhibition and/or dispersion of inorganic sulphide scales, the process comprising adding to water being within an oil or gas containing formation said copolymer.

Abstract: Charged nanoparticles may be added to an aqueous downhole fluid having polymers therein where the charged nanoparticles may crosslink at least a portion of the polymers. The polymers may be or include, but are not limited to polyacrylamide, xanthan, guar, polyacrylic acid, poly 2-acrylamido-2-methyl-1-propane sulfonic acid (AMPS), polyethylene oxide, polypropylene oxide, or combinations thereof. The polymers may be homopolymers, copolymers, terpolymers, or combinations thereof. The charged nanoparticles may be or include, but are not limited to clay nanoparticles, modified nanoparticles, or combinations thereof. The aqueous downhole fluid may be or include, but is not limited to fracturing fluids, injection fluids, and combinations thereof for performing a fracturing operation, an injection operation, another enhanced oil recovery operation, and the like.

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: Aqueous and substantially anhydrous fluids having particularly low thermal conductivities and variable densities are disclosed. The fluids include: one or more organic and/or inorganic salts and at least one aprotic polar organic solvent, a mixture of aprotic and protic polar organic solvents, and/or a polar organic solvent having both protic and aprotic polar functional group linkages. The fluids optionally include one or more viscosifying agents and are free of cross-linking agents. Methods for formulating and using the fluids are also disclosed.

Abstract: Fluid treatment systems and compositions are provided including (a) at least one material including (1) at least one carboxylic acid functional group and (2) at least one sulfur-containing group selected from the group consisting of sulfonyl functional groups, sulfonate functional groups and mixtures thereof; (b) at least one friction reducing agent selected from the group consisting of guar gums, polyacrylamides, hydratable cellulosic materials, viscoelastic surfactants, and mixtures thereof; and (c) at least one scale control agent. The fluid treatment systems and compositions can be used to treat aqueous systems, for example as fracturing fluids for treating aqueous compositions found in subterranean formations. Methods for inhibiting formation and/or precipitation of metal oxides in an aqueous composition using the fluid treatment systems or compositions also are provided.

Abstract: Energized slurries (including foams) comprising an Apollonian particle mixture and at least one additive selected from the group consisting of viscosifiers, gelling agents and rheological agents. Also, methods, fluids, equipment and/or systems for treating a subterranean formation penetrated by a wellbore, relating to treatment fluids based on the energized slurries.

Abstract: A treatment fluid for treating a portion of a high-temperature subterranean formation comprises: a base fluid, wherein the base fluid comprises water; a viscosifier, wherein the viscosifier is a polymer, and wherein the viscosifier is thermally stable up to a temperature of 325° F.; and a stabilizer package, wherein the stabilizer package: (A) comprises a first stabilizer and a second stabilizer, wherein the first stabilizer is an oxygen scavenger and the second stabilizer is a pH adjustor; and (B) is capable of increasing the thermal stability of the viscosifier to a temperature greater than 350° F., wherein the portion of the subterranean formation has a bottomhole temperature greater than 350° F. A method of treating a high-temperature subterranean formation comprises introducing the treatment fluid into the portion of the subterranean formation.

Abstract: The invention relates to a hydrocarbon recovery composition comprising an anionic surfactant, wherein said composition is in the solid state, and to a shaped article comprising said composition. Preferably, said composition is in the form of a powder. Further, the invention relates to a process for treating a hydrocarbon containing formation comprising the steps of a) transporting said composition or shaped article to the location of the hydrocarbon containing formation; b) dissolving said composition or shaped article in water thereby forming an aqueous fluid containing the hydrocarbon recovery composition; c) providing the aqueous fluid containing the hydrocarbon recovery composition to at least a portion of the hydrocarbon containing formation; and d) allowing the hydrocarbon recovery composition to interact with the hydrocarbons in the hydrocarbon containing formation.

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: Various embodiments disclosed relate to a composition including a crosslinkable ampholyte polymer or a crosslinked product of the same, methods of making and using the composition, and systems including the composition. In various embodiments, the present invention provides a method of treating a subterranean formation. The method can include obtaining or providing a composition including a crosslinkable ampholyte polymer. The crosslinkable ampholyte polymer can include an ethylene repeating unit including a —C(O)NH2 group, an ethylene repeating unit including a —S(O)2OR1 group, and an ethylene repeating unit comprising an —N+R23X? group. At each occurrence, R1 can be independently selected from the group consisting of —H and a counterion. At each occurrence, R2 can be independently substituted or unsubstituted (C1-C20)hydrocarbyl. At each occurrence, X? can be independently a counterion. The composition can also include at least one crosslinker.

Abstract: Electromagnetically active slurries comprising stabilized fluids and methods of using the stabilized, electromagnetically active slurries in fluid flow control and detection. Also, methods, fluids, equipment and/or systems for treating a subterranean formation penetrated by a wellbore, relating to treatment fluids based on the stabilized, electromagnetically active slurries.

Abstract: A treatment fluid for treating a portion of a high-temperature subterranean formation comprises: a base fluid, wherein the base fluid comprises water; a viscosifier, wherein the viscosifier is a polymer, and wherein the viscosifier is thermally stable up to a temperature of 325° F.; and a stabilizer package, wherein the stabilizer package: (A) comprises a first stabilizer and a second stabilizer, wherein the first stabilizer is an oxygen scavenger and the second stabilizer is a pH adjustor; and (B) is capable of increasing the thermal stability of the viscosifier to a temperature greater than 350° F., wherein the portion of the subterranean formation has a bottomhole temperature greater than 350° F. A method of treating a high-temperature subterranean formation comprises introducing the treatment fluid into the portion of the subterranean formation.

Abstract: A method involving exposing a substance to a promoter, the promoter being made from a liquid carrier and a metal salt component, the metal salt component, having at least (i) a magnetic susceptibility above 1000 or (ii) an ionization potential below about 500 volts, or (iii) both (i) and (ii), and applying electromagnetic wave energy to the substance while the substance is in the presence of the promoter, for a period of time and at a frequency and amplification sufficient to promote the modification of at least one physical property of the substance. A related method of treating a well in a subterranean formation, a tank or a pipeline, and the well treatment promoter composition, are also described.

Abstract: Methods of treating flowback water from a subterranean formation penetrated by a well bore are provided, comprising: (a) providing remediated flowback water having a ferrous iron (Fe+2) ion concentration of less than about 100 milligrams of ferrous iron ion per liter of flowback water, a barium ion (Ba+2) concentration of less than about 500 milligrams of barium ion per liter of flowback water, and a calcium ion (Ca+) concentration of at least about 1,000 milligrams of calcium ion per liter of remediated flowback water; and (b) treating the flowback water with: (i) at least one friction reducing agent; and (ii) at least one scale formation inhibiting agent and/or at least one iron precipitation control agent to provide treated flowback water which can be reused as fracturing fluid in a well drilling operation.

Abstract: The present invention is directed to fracturing fluids having temperature-sensitive viscosities. The fracturing fluids may include a mixture of a hydrophobically associative polymer (HAP) and a surfactant in an aqueous medium, wherein the surfactant imparts a critical solution temperature (CST) to the fluid. The fluid is more viscous at temperatures lower than the CST as compared to temperatures above the CST.

Abstract: The invention is directed to polymers that self-crosslink at acidic pH or can be crosslinked by phenolic agents in brine. Such polymers have lower viscosity and can be pumped deep into reservoirs, where they will cross link in situ, thus increasing their viscosity and/or form a gel and blocking thief zones. Methods of making and using such polymers are also provided.

Abstract: Water-soluble, hydrophobically associating copolymers which comprise new types of hydrophobically associating monomers. The monomers comprise an ethylenically unsaturated group and a polyether group with block structure comprising a hydrophilic polyalkylene oxide block which consists essentially of ethylene oxide groups, and a terminal, hydrophobic polyalkylene oxide block which consists of alkylene oxides with at least 4, preferably at least 5 carbon atoms.

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: Hydrophilic polymer particles have been obtained using polyacrylamide, xanthane, maleic anhydride polymers, allylamine, ethyleneimine, and oxazoline as core polymers. Then, hydrophobic polymers shells have been produced on the core-side using styrene, styrene copolymers, polyvinyl state, polysolfune, polymethyl methacrylate, and polycyclohxyl methacrylate by in-situ polymerization of monomer as method one and inverse emulsion process as method two. These particles can release hydrophilic polymers at oil-water interface at the reservoir temperature where the water flooding should have the maximum viscosity. So, active materials cause to decrease the mobility ratio of water to oil in the reservoirs and on the other hand, plug the swept porosities and prevent to act the water fingering process.

Abstract: A method of treating a portion of a subterranean formation that includes: providing a water-in-oil emulsion, inverting the water-in-oil emulsion to form a friction reducing treatment solution, and introducing the treatment solution into the portion of the subterranean formation. The water-in-oil emulsion has an oil phase, an aqueous phase and surfactants. The oil phase (O) and an aqueous phase (A) are present at an O/A ratio of from about 1:8 to about 10:1. The oil phase is present as a continuous phase and contains an inert hydrophobic liquid. The aqueous phase is present as a dispersed phase of distinct particles in the oil phase and includes water and a water soluble polymer. The water soluble polymer makes up from 10 to 25 weight percent of the water-in-oil emulsion. The water-in-oil emulsion is inverted by adding it to water to form a friction reducing treatment solution.

Abstract: The invention is directed to stable and labile crosslinked water swellable polymeric microparticles that can be further gelled, methods for making same, and their various uses in the hygiene and medical arts, gel electrophoresis, packaging, agriculture, the cable industry, information technology, in the food industry, papermaking, use as flocculation aids, and the like. More particularly, the invention relates to a composition comprising expandable polymeric microparticles having labile crosslinkers and stable crosslinkers, said microparticle mixed with a fluid and an unreacted tertiary crosslinker comprising PEI or other polyamine based tertiary crosslinker that is capable of further crosslinking the microparticle on degradation of the labile crosslinker and swelling of the particle, so as to form a stable gel.

Abstract: A method of treating a zone of a subterranean carbonate formation penetrated by a wellbore is provided. The method includes the steps of: According to an embodiment, a method of treating a zone of a subterranean carbonate formation penetrated by a wellbore is provided, the method including the steps of: (a) forming a treatment fluid comprising: (i) water; (ii) a water-soluble polymer having at least one functional group that can be crosslinked with aluminum(III); and (iii) a water-soluble aluminum carboxylate; wherein the pH of the treatment fluid is less than 1; (b) introducing the treatment fluid through the wellbore into the zone; and (c) allowing time for the strong acid in the treatment fluid to spend in the formation such that the pH of the fluid increases sufficiently for the aluminum of the aluminum carboxylate to crosslink the polymer.

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: A particulate suspending agent may be useful for mitigating particulate settling in wellbore applications with high-temperature and/or at near-neutral and higher pH values. Methods of treating a wellbore may include providing a treatment fluid comprising an aqueous liquid, a plurality of particulates, and a particulate suspending agent, wherein the particulate suspending agent comprises a crosslinked polymer particulate formed by a reaction comprising a first monofunctional monomer and an orthoester crosslinker, the orthoester crosslinker comprising an orthoester linkage and at least two crosslinking moieties; and placing the treatment fluid in a wellbore penetrating a subterranean formation.

Abstract: A well servicing fluid formulated with components comprising a friction reducer having at least one polymer unit chosen from acrylamide groups, acrylate groups, sulfo groups, and maleic acid groups; and an anionic surfactant, a cationic surfactant and an aqueous base capable of forming a viscoelastic gel. Methods of making the well servicing fluid and methods of employing the well servicing fluid in a well are also disclosed.

Abstract: The invention is directed to stable crosslinked water-soluble swellable polymers and methods for making same. More particularly, the invention relates to a composition comprising expandable polymeric particles having anionic sites and labile crosslinkers and stable crosslinkers, said particle mixed with a fluid and a cationic crosslinker that is capable of further crosslinking the particle on degradation of the labile crosslinker and exposure of the anionic sites so as to form a gel. A particularly important use is as an injection fluid in petroleum production, where the expandable polymeric particles are injected into target zone and when the heat and/or suitable pH of the target zone cause degradation of the labile crosslinker and the particle expands, the cationic crosslinker crosslinks the polymer to form a gel, thus diverting water to lower permeability regions and improving oil recovery.

Abstract: Processes are provided for reducing the hydrodynamic friction of a turbulent brine stream including, for example, the step of injecting a mixture of a finely divided free flowing friction reducing powder into the turbulent brine stream, wherein the particles of the powder have a primary particle size between 10 and 100 microns in average particle diameter, and the brine stream comprises water with at least 90,000 ppm total dissolved solids, wherein the total dissolved solids includes at least 30,000 ppm sodium cations, 10,000 ppm calcium cations, and 1,000 ppm magnesium cations, and wherein the brine has an electrical conductivity of greater than 100.0 mS/cm at 25° C. For use with a harsher brine, the particles preferably have a primary particle size between 10 and 53 microns in average particle diameter. The friction reducing powder may, for example, be a polyacrylamide polymer.

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: High solids content slurry, systems and methods. The slurry comprises a carrier fluid and a solids mixture of first, second, third and fourth particle size distribution (PSD) modes wherein the first PSD mode is at least three times larger than the second PSD mode, which is larger than the third PSD mode, which is larger than the fourth PSD mode, and wherein at least one of the second and third PSD modes is less than 3 times larger than the respective third or fourth PSD mode. The method comprises forming the slurry, positioning a screen in a wellbore and circulating the slurry through the wellbore such that the solids mixture is deposited between the screen and the wellbore. The system comprises a pump to circulate the slurry, a workstring to position the screen and means for converting the slurry to a gravel pack.

Abstract: A salt-tolerant, thermally-stable rheology modifier and, in particular, a rheology modifier for applications in oil-field well-bore fluids. In accordance with one aspect, the rheology modifier comprises a terpolymer of acrylamide, 2-acrylamido-2-methyl-propanesulfonic acid (AMPS) and a long-chain alkyl acrylate wherein the terpolymer is prepared by dispersion polymerization.

Abstract: Disclosed herein is a degradable latex comprising a stable dispersion of macromolecules in a liquid medium, wherein the macromolecules comprise a primary moiety comprising a plurality of functional groups, and a plurality of secondary moiety each chemically bonded through a labile linkage to the functional groups of the primary moiety, wherein at least a portion of residues of the secondary moiety are dispersible in the liquid medium. Methods of making and degrading the degradable latex, treating a formation and a treatment fluid are also disclosed.

Abstract: Methods of stabilizing water-sensitive clays in subterranean formations may include introducing a drill-in treatment fluid into at least a portion of a subterranean formation comprising water-sensitive minerals, where providing the drill-in treatment fluid comprises an aqueous-based fluid and a hydrophobically-modified cationic polymer; and allowing the hydrophobically-modified cationic polymer to at least partially coat the water-sensitive mineral.

Abstract: A treatment fluid for treating a subterranean formation penetrated by a wellbore is formed from water, a polyacrylamide in an amount of less than about 0.5% by weight of the fluid for reducing friction of the fluid and a stabilized peroxide breaker. A method of treating a subterranean formation penetrated by a wellbore is carried out by forming treatment fluid comprising water, a polyacrylamide in an amount of less than about 0.5% by weight of the fluid for reducing friction of the fluid and a stabilized peroxide breaker. The treatment fluid is introduced into the formation through the wellbore at a pressure above the fracture pressure of the formation.

Abstract: Well operating elements are described, one embodiment comprising a first component that is substantially non-dissolvable when exposed to a selected wellbore environment and a second component that is soluble in the selected wellbore environment and whose rate and/or location of dissolution is at least partially controlled by structure of the first component. A second embodiment includes the component that is soluble in the selected wellbore environment, and one or more exposure holes or passages in the soluble component to control its solubility. The second embodiment may or may not include a substantially non-dissolvable component. Methods of using the well operating elements in oilfield operations are also described. This abstract allows a searcher or other reader to quickly ascertain the subject matter of the disclosure. It will not be used to interpret or limit the scope or meaning of the claims.

Abstract: The invention relates to a method for the assisted recovery of petroleum in a deposit by means of the introduction of an aqueous solution of a hydrosoluble polymer into the deposit, said method being characterised in that said aqueous solution is prepared by dissolving a polymer-based composition containing at least one hydrosoluble polymer, at least one radical capturing agent, and at least one sacrificial agent, in an aqueous solution subjected to a step of treatment with at least one deoxygenating agent, prior to the introduction of the polymer-based composition.

Abstract: A composition comprising crosslinked expandable polymeric microparticles capable of hydrolysis at or below neutral pH and a method of modifying the permeability to water of a subterranean formation by introducing such compositions into the subterranean formation is disclosed and claimed. This invention further relates to compositions and methods for the recovery of hydrocarbon fluids from a subterranean reservoir or formation subjected to CO2 or CO2 Water Alternating Gas flooding at low pH and increases the mobilization and/or recovery rate of hydrocarbon fluids present in the subterranean formations.