Abstract: The subject matter of the invention is the use of a ruthenium complex of the formula 1, wherein the individual substituents have meanings as indicated in the olefin metathesis reactions description, including a reaction selected from such as ring-closing metathesis (RCM), homometathesis (self-CM) or cross metathesis (CM).

Abstract: The present invention relates to a method for applying scale inhibitor to completion fluids during injectivity test operations. Said method takes advantage of the completion fluid to inhibit scaling in the reservoir by filling the porous spaces of the reservoir rock with the inhibited completion fluid. When the well is put into production, this inhibited fluid positioned inside the reservoir will be produced together with the oil and will inhibit the formation of scale inside the reservoir and on production equipment.

Abstract: A composition includes a colloidal solution which includes a solvent, a plurality of nanoparticles dispersed in the solvent, an activator dissolved in the colloidal solution, and a plurality of gel particles suspended in the colloidal solution. A method for water shutoff includes injecting a composition into a fracture near a water zone in a formation, wherein the composition includes a colloidal solution which includes a solvent, a plurality of nanoparticles dispersed in the solvent, an activator dissolved in the solvent, and a plurality of gel particles suspended in the colloidal solution.

Abstract: Compositions and methods for increasing recovery, or flowback, of hydrocarbon compounds from hydrocarbon-containing subterranean oil formations. Concentrates include a sulfonated and/or a sulfated surfactant, an alkoxylated alcohol surfactant, a coupling agent, a hydrotrope, an additional surfactant, and water. Injectate compositions for oil recovery include the concentrate and a water source such as a produced water and/or seawater. Inclusion of particular hydrotropes such as sodium xylene sulfonate and/or potassium toluene phosphate in the compositions provides higher yields of hydrocarbons recovered. Larger amounts of hydrotrope result in an increase in injectate interfacial tension, but also result, as judged by decreased turbidity, in improved compatibility of the surfactant system in injectates made with water sources comprising salts.

Abstract: The present invention relates to a method for modifying the water permeability of a subterranean formation which comprises oil, said method comprising at least the following steps: Preparing an injection fluid from a dispersion of a hydrophilic phase in a lipophilic phase, with water or brine, the dispersion comprising: a hydrophilic phase comprising at least one linear (co)polymer E, a lipophilic phase, at least one interface polymer composed of at least one monomer of formula (I): Injecting the injection fluid into the subterranean formation, comprising a linear (co)polymer E concentration, such that when released and in contact with water, the viscosity of the injection fluid is greater than the viscosity of the oil in the formation.

Abstract: Disclosed are compositions and kits of fibers and acid-functional vinyl alcohol polymers, wherein such compositions and kits are useful for wellbore remediation as applied to a subterranean formation traversed by the borehole of an oil or gas well.

Abstract: Oil-soluble well treatment agents may be slowly released into a well or a subterranean formation by use of an aqueous fluid of (i) an oil-in-water dispersion having the oil-soluble well treatment agent as a dispersed phase and (ii) a second component having an oil-soluble or water-soluble primer coated onto a portion of its surface. The amount of the oil-soluble well treatment agent in the oil-in-water dispersion is from 20 to 50 weight percent and the average particle size of the oil-soluble well treatment agent in the dispersion may be from 0.005 to 2 micrometers. The oil-in-water dispersion may further contain a water-soluble well treatment agent.

Abstract: This disclosure describes the composition and methods of use for a novel delayed polymer gelation system for high temperature and high salinity applications. This polymer gelation system includes a polymer of acrylamide, AMPS and 500-5000 ppm polyethylene glycol diacrylate in inverse emulsion form, and a polyethyleneimine (PEI) with a MW of 2,000-30,000 daltons as the crosslinking agent.

Abstract: A process is disclosed that includes providing a mixture to a wellbore. The mixture can comprise formic acid or a formic acid precursor, a salt of lactic acid, and a salt of gluconic acid. The mixture can be introduced into an underground formation around the wellbore. The mixture can prevent or at least reduce the formation of formate crystals as compared to mixtures without the salt of lactic acid or the salt of gluconic acid. The mixture permits the formic acid, or formic acid produced from hydrolysis of the formic acid precursor, to react with acid soluble material in the underground formation to generate soluble calcium salts.

Abstract: The present disclosure relates to methods for treating a water zone of a subterranean formation by injecting a mixture including an anionic surfactant and an amine, followed by CO2, to reduce water production from the formation.

Abstract: A scale inhibitor squeeze treatment is enhanced by injecting a pre-flush solution into a wellbore, where the pre-flush solution includes at least one organic carbonate solvent, such as a dialkyl carbonate and/or a cyclic carbonate. The use of an organic carbonate solvent can help prevent the pre-flush solution emulsion formation, help avoid water-blocking, and enhance scale inhibitor adsorption. The use of an organic carbonate solvent also permits the pre-flush solution to be free of water, in one non-limiting embodiment.

Abstract: Energy may be stored by injecting fluid into a fracture in the earth and producing the fluid back while recovering power and/or desalinating water. The method may be particularly adapted to storage of large amounts of energy such as in grid-scale electric energy systems. The fracture may be formed and treated with resin so as to limit fluid loss and to increase propagation pressure. The fluid may be water containing a dissolved salt or fresh water and a portion or all of the water may be desalinated using pressure in the water when it is produced.

Abstract: It has been discovered that solid contaminants in a mixture of a hydrocarbon phase and an aqueous phase may be retained in the hydrocarbon phase by introducing to the mixture an effective amount of an oil-wetting additive to retain at least a portion of the solid contaminants in the hydrocarbon phase as contrasted with an aqueous phase. The oil-wetting additive can be a surface-active additive including, but is not necessarily limited to, drilling fluid additives, surfactants, antifoulants, nanoparticles and combinations thereof.

Abstract: Disclosed herein is a wellbore servicing fluid comprising a scale inhibitor, a surfactant, and an aqueous fluid comprising sulfate in an amount of from about 100 ppm to about 10,000 ppm based on the total weight of the aqueous fluid. The wellbore servicing fluid can be used as a fracturing fluid in a method of servicing a wellbore penetrating a subterranean formation. The wellbore servicing fluid can mitigate the formation of scales, prevent water blockage, and increase hydrocarbon production.

Abstract: A method and system for corrosion control and scale control in water supply for injection, including specifying a corrosion inhibitor for squeeze treatment of a water supply well, specifying a scale inhibitor that can form a complex with the corrosion inhibitor, pumping the corrosion inhibitor and the scale inhibitor through a wellbore of the water supply well into an aquifer in a subterranean formation, forming the complex of the corrosion inhibitor and the scale inhibitor, and pumping water from the water supply well to an injection well for injection, the water including the scale inhibitor released from the complex in the aquifer and the corrosion inhibitor released from the complex in the aquifer.

Abstract: An ecofriendly corrosion inhibitor composition and a method for inhibiting corrosion on a metal surface with the ecofriendly corrosion inhibitor composition are provided. The ecofriendly corrosion inhibitor composition includes 10-30 weight % of fatty acids derived from waste vegetable oils and 70-90 weight % of heavy aromatic naphtha. The fatty acids derived from waste vegetable oils include oleic acid, linoleic acid, and palmitic acid. In the method, the ecofriendly corrosion inhibitor composition is added to a hydrocarbon fluid exposed to the metal surface and the corrosion inhibitor composition inhibits corrosion on the metal surfaces.

Abstract: Methods for determining an in-situ pore pressure in a formation rock may include acquiring well log data, calculating a cation-exchange capacity, calculating a mole fraction of fixed charges using the cation-exchange capacity, determining a formation temperature, calculating the in-situ pore pressure, outputting the in-situ pore pressure of the formation rock, and using the in-situ pore pressure in a wellbore stability model to monitor and maintain stability of the formation rock. Corresponding electronic devices may include a computer processor coupled to at least one logging tool, wherein the logging tool is configured to acquire well log data in a formation rock. Non-transitory computer storage mediums may include program instructions, that when executed, may be configured to perform the methods for determining an in-situ pore pressure in a formation rock.

Abstract: A method of producing a nanosilica-containing cement formulation, the method comprising the steps of mixing an amount of a determinant nanosilica particle and a functional coating; applying a dynamic initiator to trigger a reversible reaction of the functional coating to produce a reversible cage, where the reversible cage surrounds the determinant nanosilica particle to produce an encapsulated nanosilica; and mixing the encapsulated nanosilica and a cement formulation to produce the nanosilica-containing cement formulation.

Abstract: A liquid corrosion inhibitor composition for use with acid compositions for use in industrial activities, said corrosion inhibitor composition comprising: a thiourea derivative; a first type of amphoteric surfactant is selected from the group consisting of: a sultaine surfactant; a betaine surfactant; and combinations thereof; a second type of amphoteric surfactant; and a solvent.

Abstract: The invention discloses transparent cleansing compositions for personal care which are based on one or more vegetable oils, potassium N-acyl L-prolinate as an anionic surfactant and polyglyceryl-3 oleate as a non-ionic surfactant. The personal care cleansing formulae disclosed herein are totally based on bio-renewable ingredients. Further, in contrast to the compositions from the prior arts, the cleansing compositions of the present invention are free from toxic and petrochemical based ingredients or impurities.

Abstract: Some methods of production hydrocarbons from a formation comprise drilling two or more horizontal wellbores in the formation, at least a portion of each extending in a direction that is within 20 degrees of parallel to a direction of maximum horizontal stress of the formation. The horizontal wellbores can include one or more producer wellbores and one or more injector wellbores, each of the producer wellbore(s) separated from at least one of the injector wellbore(s) by a formation-permeability-dependent well spacing. Some comprise comprising creating one or more longitudinal fractures that are in communication with the formation in each of the horizontal wellbores, injecting a recovery fluid comprising gas into at least one of the injector wellbore(s) such that the recovery fluid flows into the formation, and receiving hydrocarbons from the formation into at least one of the producer wellbore(s).

Abstract: A wellbore servicing fluid comprising (a) a cationic formation stabilizer having (i) a molecular weight in a range of from equal to or greater than 0.05 to equal to or less than 2.0 kiloDaltons (kDa), or (ii) cationic charge functional groups of greater than 2 to equal to or less than 5 cationic charges per molecule, or (iii) both (i) and (ii), (b) an anionic friction reducer, and (c) an aqueous fluid.

Abstract: A method of making a proppant-gel matrix comprising: a) hydrating a gelling agent to form a hydrated gelling agent; b) adding a basic compound to the hydrated gelling agent to form a basic hydrated gelling agent having a pH in the range of 11.5 to 14.0; c) mixing the basic hydrated gelling agent and a proppant to form a basic hydrated gelling system; and d) adding a crosslinking agent to the basic hydrated gelling system to form the proppant-gel matrix, is disclosed. The proppant-gel matrix can then be used as a fracturing fluid in a hydraulic fracturing process.

Abstract: Proppant compositions and methods for using same are disclosed herein. In particular, a proppant composition for use in hydraulic fracturing is disclosed herein. The proppant composition can contain a plurality of particulates and at least one particulate of the plurality of particulates containing a chemical treatment agent. The at least one particulate having a long term permeability measured in accordance with ISO 13503-5 at 7,500 psi of at least about 10 D. The at least one chemical treatment agent can separate from the at least one particulate when located inside a fracture of a subterranean formation after a period of time.

Abstract: A composition includes a nonionic fluorinated polymeric surfactant, a nonfluorinated surfactant, and a scale treatment. Additionally, a method for scale treatment is provided. The method includes injecting gas into the aforementioned composition to produce a foam and injecting the foam into a formation. In the formation, the foam may be exposed to a first temperature at which it has a first viscosity. The foam may be maintained inside the formation for a period of time, and then recovered from the formation, at which point it is exposed to a second temperature and has a second viscosity.

Abstract: Coated proppants include a proppant particle, a surface copolymer layer surrounding the proppant particle, and a resin layer surrounding the surface copolymer layer. The surface copolymer layer includes a copolymer of at least two monomers chosen from styrene, methyl methacrylate, ethylene, propylene, butylene, imides, urethanes, sulfones, carbonates, and acrylamides, where the copolymer is crosslinked by divinyl benzene. The resin layer includes a cured resin.

Abstract: The present invention relates to a process for the preparation of a water-soluble copolymer comprising the step of reacting a monomer (a) of formula (I), wherein Q1, Q2, R1 to R7 and X have the meaning as indicated in the description and claims with at least one monoethylenically unsaturated, anionic monomer (b), preferably representing a monoethylenically unsaturated monomer comprising at least one carboxy, phosphonate or sulfonate group and salts thereof, preferably their ammonium salts or alkaline-earth metal salts or alkali metal salts; and at least one monoethylenically unsaturated, non-ionic monomer (c). The present invention further relates to a copolymer obtainable by said process and its use in enhanced oil recovery (EOR), a formulation comprising said copolymer and a method of oil production uses said formulation.

Abstract: The disclosure is directed to polyelectrolyte complex nanoparticles that can be used to deliver agents deep into hydrocarbon reservoirs. Methods of making and using said polyelectrolyte complex nanoparticles are also provided.

Abstract: Provided is a method for treating a sandstone formation with a well treatment composition. The method may include introducing a pre-flush pill, introducing the well treatment composition, introducing a post-flush fluid, and maintaining the wellbore such that the well treatment composition interacts with the sandstone formation. Further provided is a method that may introduce the well treatment composition as two pills, such as an organic acid pill and an inorganic acid pill. The well treatment composition may include an aqueous solution of an ammonium salt, an inorganic acid, an organic acid, and optionally one or more of a pH adjuster, a mutual solvent, a surfactant, and a corrosion inhibitor.

Abstract: Various embodiments disclosed relate to demulsifier compositions for treatment of subterranean formations or produced petroleum comprising an emulsion. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a demulsifier composition. The demulsifier composition includes an alkanolamide surfactant that is a (C1-C50)hydrocarbyl amide having groups R1 and R2 substituted on the amide nitrogen, wherein R1 and R2 are each independently selected from the group consisting of —H, —(C1-C50)hydrocarbyl, and —(C1-C50)hydrocarbylene-OH, wherein at least one of R1 and R2 is —(C1-C50)hydrocarbylene-OH. The demulsifier composition includes an alkoxylated alcohol surfactant that is a (C1-C50)hydrocarbyl-OH having a —((C2-C3)alkylene-O)n—H group on the —OH group, wherein n is about 1 to about 100. The demulsifier composition also includes an amine-oxide surfactant.

Abstract: An oil field chemical-carrying material comprising polymeric particles and a process for making the same are disclosed. An oil field chemical is integrally incorporated into the granulated particle. The oil field chemical is in particular a tracer and the particle is in particular a proppant for use in hydraulic fracturing of a subterranean formation. Methods of delivering oil field chemicals, methods of monitoring subterranean formations, methods of tracing flow of fluid from hydrocarbon reservoirs and methods of hydraulic fracturing subterranean formations are also disclosed.

Abstract: Described herein are methods of enhancing the rheological properties of a colloidal mineral suspension in a liquid with high-intensity acoustical energy. In some examples, the colloidal mineral suspension may be dehydrated after treatment with high-intensity acoustical energy.

Abstract: An aqueous injection fluid including: a polymer comprising hydrophilic moieties and a plurality of hydrophobic groups; and a surfactant that changes shape based on salinity and/or temperature.

Abstract: The present disclosure provides a preparation method of an environment-friendly high-temperature resistant water-based drilling fluid plugging anti-sloughing agent, the preparation method comprises the following steps: mixing and emulsifying a styrene monomer, an acrylic monomer and an emulsifier MS-1 aqueous solution to prepare a pre-polymerization emulsion; dispersing hydrophilic monomer, cationic monomer and an emulsifier MS-1 in water, adjusting the pH to be within a range of 6.5-8.

Abstract: The present disclosure provides treatment fluids that comprise star macromolecules as a fluid loss additive or a viscosifier. An embodiment of the present disclosure is a method comprising: providing a treatment fluid that comprises: an aqueous base fluid; and a star macromolecule that comprises: a hydrophilic polymeric core, a first group of polymeric arms attached to the core wherein each of the arms in the first group consists of hydrophilic monomers, and a second group of polymeric arms attached to the core wherein each of the arms in the second group comprises at least one hydrophilic homopolymeric segment and at least one hydrophobic homopolymeric segment; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.

Abstract: The present invention relates to a method for producing mineral oil from underground mineral oil deposits, in which an aqueous formulation comprising at least a mixture of alkyl ether carboxylate and corresponding alkyl ether alcohol, where the alkyl ether carboxylate has been prepared from the alkyl ether alcohol and the molar ratio in the mixture of alkyl ether carboxylate:alkyl ether alcohol is from 51:49 to 92:8, is injected through at least one injection well into a mineral oil deposit, where the deposit has a deposit temperature of 55° C. to 150° C., a crude oil having more than 20° API and a deposit water having more than 100 ppm of divalent cations, and crude oil is withdrawn through at least one production well from the deposit. The invention further relates to the preparation of the mixture and to a concentrate comprising the mixture.

Abstract: The present disclosure provides treatment fluids that comprise star macromolecules as a fluid loss additive or a viscosifier. An embodiment of the present disclosure is a method comprising: providing a treatment fluid that comprises: an aqueous base fluid; and a star macromolecule that comprises: a hydraulic polymeric core, a first group of polymeric arms attached to the core wherein each of the arms in the first group consists of hydrophilic monomers, and a second group of polymeric arms attached to the core wherein each of the arms in the second group comprises at least one hydrophilic homopolymeric segment and at least one hydrophobic homopolymeric segment; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.

Abstract: Salt-tolerant friction-reducing terpolymer compositions are provided. The compositions can be used in a method of reducing friction resulting from turbulent flow in an aqueous fracturing fluid in a subterranean fracturing process.

Abstract: The present invention relates to compositions and methods for reducing or preventing the loss of drilling fluids and other well servicing fluids into a subterranean formation during drilling or construction of boreholes in said formation. Specifically, this invention comprises a curable composition capable of free radical polymerization for creating lost circulation material in-situ.

Abstract: The invention relates to a class of novel surfactants that have utility in the recovery and/or extraction of oil.

Abstract: The invention is directed to long lasting crosslinked water-soluble swellable polymers, methods for making same, and their uses. More particularly, the invention relates to a composition comprising expandable polymeric particles having cationic sites as well as labile crosslinkers and stable crosslinkers, said particle 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 target zones in the reservoirs and when the heat and/or a suitable pH in the reservoir cause degradation of the labile crosslinker and when the particle expands, the cationic sites in the polymer adsorb to negative sites of the rock in the formation, thus diverting water to lower permeability regions and improving oil recovery. However, many other uses are possible.

Abstract: The invention is directed to stable crosslinked water-soluble swellable polymers, 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 that is capable of further crosslinking the microparticle on degradation of the labile crosslinker so as to form a stable gel.

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: 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: Treatment methods for coated or uncoated proppants that can, among other things, control fugitive dust during typical handling procedures with typical transport equipment and/or add functional features to the proppant solid are disclosed herein.

Abstract: A polymer composition includes a base polymer comprising a hydrocarbon rubber, an acrylic copolymer, and a refined oil in which the acrylic polymer is dispersed. The polymer composition is swellable when treated with an aqueous medium, non-aqueous medium, or both. A sealing element for a flow channel includes an expandable section filled with a swellable composition that swells when treated with a swelling material. The swellable composition includes the polymer composition, and the swelling material may be aqueous, non-aqueous, or both.

Abstract: The current technology relates to mining processes and compositions which inhibit the growth of complex scale. More specifically it relates to a process for preventing/inhibiting and/or controlling gypsum scale in aqueous mineral ore slurries, and for inhibiting scale in relatively high solids content environments in industrial mining operations.

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: The present invention relates to the formation of a gel within a medium M, in particular within an underground formation, which comprises the following steps: (EI) a basic compound C is added to a fluid latex L comprising dispersed particles of a polymer P, bearing ester side functions, said basic compound C being added in an amount suitable for hydrolysing at least one part of said ester side functions into carboxylic acid and/or alcohol functions, as a result of which a modified latex L? is obtained, the viscosity of which gradually increases with time from the addition of the compound C up to the formation of a gel; then (E2) the resulting modified latex is introduced into the medium M before the formation of the gel and the gel is left to form within the medium M.

Abstract: A composite having a solid particulate and a surface modifying treatment agent on the solid particulate wherein the surface modifying treatment agent has a hydrophobic tail and an anchor for adhering the hydrophobic tail onto the solid particulate. The anchor may be metal and the hydrophobic tail may be an organo-silicon material, a fluorinated hydrocarbon or both an organo-silicon material and a fluorinated hydrocarbon. The composite may be used as a proppant in a hydraulic fracturing operation as well as a sand control particulate in a gravel packing operation. The presence of the surface modifying treatment agent on the surface of the solid particulate reduces the generation of fines and dust as well as the migration of sand during a hydraulic fracturing operation or a sand control operation. The presence of the surface modifying treatment agent on the surface of the solid particulate further enhances the crush resistance of the solid particulate.