Abstract: A method for acidizing a subterranean formation may include: preparing a water-in-oil emulsion comprising a non-polar phase, a polar phase, an emulsifier an acid, and a drag reducing agent; pumping the water-in-oil emulsion into a wellbore penetrating a subterranean formation above a fracture gradient of the subterranean formation to create or extend at least one fracture in the subterranean formation.

Abstract: A method for stabilizing asphaltenes in petroleum feedstocks such as crude oil includes adding to the feedstock an effective amount of an additive containing at least one waste plastic. Suitable waste plastics include, but are not necessarily limited to, polyethylene, polyethylene terephthalate, polystyrene, polycarbonate, polyamide, and polyurethane, and combinations thereof. By “stabilizing” is meant keeping the asphaltenes in solution in the petroleum feedstocks.

Abstract: The present invention discloses a plant-based self-degradable gel diverting agent and a preparation method therefor. The preparation method comprises the following steps: adjusting a pH of a formaldehyde solution, adding urea in three batches, heating and stirring, adding furfural in the process of adding a second batch of urea until a plant-based urea-formaldehyde resin is obtained through the reaction, completely dissolving starch in water, uniformly stirring to obtain a gelatinized starch solution, adding the plant-based urea-formaldehyde resin, adding a curing agent, and uniformly stirring, mixing and curing to obtain a product. The resin plugging agent is a liquid homogeneous system and has a low initial viscosity; the system is particle-free, can enter tiny slits; and the gel temporary plugging agent does not need to be added with a gel breaker at a temperature of 100-180° C., the temporary plugging agent can be completely degraded.

Abstract: The method of fluid loss control is provided for the case of high-rate fluid loss. Two treatment fluids are provided, where a first treatment fluid comprising a carrier fluid, solids and a first polyelectrolyte, and a second treatment fluid comprising a carrier fluid and a second polyelectrolyte. Two polyelectrolytes in both treatment fluids are oppositely charged under the pumping conditions, being taken from the classes of polyanionic and polycationic polymers. Two treatment fluids are pumped separately to the zone with fluid loss. The mixing of two treatment fluids into the well creates low-permeability agglomerates that plugs the fluid leakage channel, preventing or reducing further fluid movement between the wellbore and subterranean formation. The plugging of thief zone can be temporary or permanent.

Abstract: A gel material for oil and gas conformance control operations is provided. The gel material includes a plurality of gel material components including polyacrylamide, triamine silica, and nanosilica which are added in suitable amounts to form the gel material under a gel formation condition. The present technology replaces and/or supplements conventional crosslinkers and provides enhanced polymeric gels, such as, for oil and gas field applications including wellbore strengthening, loss circulation materials, and water shut-off applications, at high temperatures. The present technology is compatible with fresh and high salinity water.

Abstract: A downhole tool for controlling the flow of a fluid in a wellbore includes a component that comprises: a cementitious material; an aggregate; and a ductility modifying agent comprising one or more of the following: an ionomer; a functionalized filler; the functionalized filler comprising one or more of the following: functionalized carbon; functionalized clay; functionalized silica; functionalized alumina; functionalized zirconia; functionalized titanium dioxide; functionalized silsesquioxane; functionalized halloysite; or functionalized boron nitride; a metallic fiber; or a polymeric fiber.

Abstract: Controlled release particles may include stimuli-responsive coatings on porous particles to allow for controlled release of a material in the pores of the porous particles. For example, a composition may comprise: a porous particle; a material in pores of the porous particle; and a coating bonded to a surface of the porous particle, wherein the coating comprises a multi-urethane compound capable of reversibly converting between a condensed state and an expanded state upon exposure to a stimuli.

Abstract: The present invention relates generally to systems and processes for improved drag reduction estimation and measurement and more specifically to portable drag reduction analyzers and processes for upscaling drag reduction data for a variety of field applications. A drag reduction parameter ?B for the fluid mixture is used for determining drag reduction for a fluid mixture in an oil field or pipeline operation.

Abstract: A method of forming a permeable proppant pack in a geothermal formation can include injecting a fracturing fluid into a fracture of a geothermal formation having a formation temperature greater than about 275° C. The fracturing fluid can include proppants having a core of a solid material that is thermally stable at the formation temperature. The core can be at least partially coated with a resin coating that includes a polymer having a decomposition temperature below the formation temperature and a melting temperature below the decomposition temperature. The resin coating can be decomposed by the heat from the geothermal formation and the core of the proppants can remain in the fracture after the resin coating has decomposed.

Abstract: The present disclosure relates to methods of making poly alpha-olefins and compositions thereof. In some embodiments, a method for making a poly alpha-olefin includes agitating in a first reaction vessel for about 30 seconds or greater a composition comprising a transition metal halide, an electron donor, a co-catalyst, and a C4-C20 alpha-olefin. The method includes transferring the composition from the first reaction vessel to a second reaction vessel. The present disclosure further relates to poly alpha-olefins and compositions thereof for reducing drag in the flow of hydrocarbons such as crude oil or refined products in pipes. In at least one embodiment, a composition includes a coated poly alpha-olefin and an inert carrier.

Abstract: A composition of matter including a fluorescent assembly and a drilling fluid is provided. The fluorescent assembly includes a matrix material and a plurality of fluorophores held within the matrix material and has an average particle size of at least one millimeter. A method includes introducing the fluorescent assembly into a drilling fluid and circulating the drilling fluid through a well during a drilling operation that creates formation cuttings such that the fluorescent assembly interacts with the formation cuttings, creating tagged cuttings. The method further includes collecting returned cuttings from the circulating drilling fluid at a surface of the well, detecting the presence of the fluorescent assembly on the returned cuttings to identify the tagged cuttings, and correlating the tagged cuttings with a drill depth in the well at a time during the drilling operation.

Abstract: A system and method for treating lost circulation, including providing a treatment fluid including a polymer and a nitrogen-generating compound through a wellbore into a lost circulation zone in a subterranean formation, generating nitrogen gas in the lost circulation zone by a reaction of the nitrogen-generating compound, generating foam from the nitrogen gas and the treatment fluid in the lost circulation zone to give foamed polymer in the lost circulation zone, and plugging the lost circulation zone with the foamed polymer.

Abstract: Disclosed are compositions and methods for use in oil and gas operations.

Abstract: This invention relates to a process of enhanced oil recovery by sweeping an underground formation comprising injecting into the underground formation an injection fluid comprising at least one water-soluble LCST macromonomeric polymer.

Abstract: A method includes providing an expandable metal slurry downhole in a wellbore. The expandable metal slurry includes granules of an expandable metal material suspended or dispersed in a fluid. Further, the method includes positioning the expandable metal slurry within the wellbore such that the granules of the expandable metal material in the expandable metal slurry are activatable to expand and form a seal within the wellbore.

Abstract: The present invention relates to the use of a combination of block polymers and particular compositions in a fluid injected under pressure into an oil-bearing rock, where: the fluid comprises solid particles and/or is brought into contact with solid particles within the oil-bearing rock following the injection thereof, the combination comprises (i) a polymer comprising: —a first block that is adsorbed on at least a portion of the particles; and —a second block, having a composition different from that of the first, and having a weight-average molecular weight of greater than 10 000 g/mol, for example greater than 100 000 g/mol, and that is soluble in the fluid; (ii) particles suitable for providing a gas barrier effect, preferably a latex and/or silica particles.

Abstract: Corrosion and/or calcium scale deposition on a surface in contact with corrosion forming components and/or scale forming components within a subterranean formation may be decreased, prevented, and/or inhibited by contacting the surface with at least one protein. The protein(s) may be or include, but is not limited to, at least one aspein protein, at least one aspolin protein, at least one dentine protein, at least one DRICH-1 protein, at least one nacrein protein, at least one SMDT-1 protein, derivatives thereof, fragments thereof, mimetics thereof, and combinations thereof. The surface may be or include, but is not limited to a metal surface, a plastic surface, a ceramic surface, a painted surface, a coated surface, and combinations thereof.

Abstract: A coated proppant includes a solid core proppant particle, a first resin coating, and a second coating on the first resin coating. The second coating includes the reaction product of one or more curatives and one or more preformed aliphatic or cycloaliphatic based isocyanurate tri-isocyanates, derived from aliphatic diisocyanates, cycloaliphatic diisocyanates, or a combination of aliphatic and cycloaliphatic diisocyanates.

Abstract: Disclosed are coated particles. The coated particles include substrate particles and a coating disposed over at least a portion of the substrate particles. The coating includes a condensation reaction product of a reaction mixture that includes a liquid isocyanate-functional component and an isocyanate-reactive composition. Also disclosed are methods for making such particles and methods for using such particles as proppants in hydraulic fracturing.

Abstract: Copolymers containing acryloylmorpholine and vinylimidazole, and optionally vinylcaprolactam and/or n-vinyl pyrrolidone, have shown superior results in hydrate inhibition tests at conditions of 7° C. subcooling dosed at 1 vol % based on the water cut of the system fluids. The copolymer product has also passed high TDS (total dissolved solids) brine compatibility tests and secondary property tests including foaming and hot injection tests which make it useful as a kinetic hydrate inhibitor in gas production systems susceptible to the formation of natural gas hydrates.

Abstract: Compositions and methods for coated or uncoated particulates, such as proppants, are provided that can, among other things, provide a hydrophobic surface that can enhance well productivity and other compositions and methods are disclosed.

Abstract: Methods and systems are provided for producing hydrocarbons from production fluids that have water as an external phase. A method for transporting a hydrocarbon through a pipeline includes injecting water into a production stream at a production center. The production stream includes a hydrocarbon, and the water injection forms a transportation stream that includes a water external phase. The transportation stream is flowed through a transportation line to a surface facility, wherein the transportation line comprises a plurality of static mixers spaced at intervals along the transportation line.

Abstract: A process for the preparation of an elastomer capable of swelling in oil and/or in water and brine comprising the steps of: a) making an aqueous inverse emulsion of particles of a polymer comprising a betaine group prepared by inverse emulsion polymerization of monomers Ab comprising a betaine group, optionally other monomers Ba and a small quantity of polyvalent, preferably divalent or trivalent monomers Ca, comprised in an aqueous phase dispersed in the form of droplets in a hydrophobic external phase having hydrophobic surfactants, the molar ratio of the monomers Ab to the optional monomers Ba being between 4/96 and 40/60, preferably 7/93 and 30/70, the molar ratio of the polyvalent, preferably divalent or trivalent monomers Ca per mole of polymer being between 1.5 and 10, preferably between 2 and 4, and b) compounding said elastomer with the aqueous inverse emulsion obtained by step a).

Abstract: Methods for the preparation of polymer-templated core-shell nanoparticles include the steps of (a) preparing a cationic polymeric core material comprising polymeric micelles, and (b) coating the core material with a silica-comprising shell by depositing the shell onto the polymeric micelles from at least one silica precursor to form the core-shell nanoparticles. Compositions which include the core-shell nanoparticles are adapted to facilitate controlled delivery of at least one active agent into a system in response to controlled changes in the pH of the system.

Abstract: The invention provides an oilfield suspending friction reducer treatment composition fluid comprising from about 0.001 weight percent to about 0.5 weight percent of a drag reducing surfactant; at least one drag reducing enhancer selected from the group consisting of polymeric drag reduction enhancers, monomeric drag reduction enhancers, and mixtures thereof.

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 fracturing fluid containing a hydratable viscosifying polymer and a zirconium acetylacetonate crosslinker provides a green alternative to conventional systems. The zirconium aceylacetonate is dissolved in benzyl alcohol or in a mixture of benzyl alcohol and 2,2-dimethyl-1,3-dioxolan-4(yl)-methanol. The pH of the fracturing fluid may be between from about 3.5 to about 11.5. The fracturing fluid may contain an acidic buffering agent or a basic buffering agent. The fracturing fluid may be pumped into a well in order to initiate or enlarge a fracture within a subterranean formation penetrated by the well.

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: Compositions that swell on contact with water contain a non-swellable thermoplastic or thermoset polymer and a swellable inorganic compound. In particular, the compositions are suitable for use in subterranean wells such as those used in the oil and gas industry. The polymer may be polypropylene and the inorganic compound may be magnesium oxide.

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.

Abstract: A well treatment fluid comprising a 2-oxo-aldehyde having 3 or more carbon atoms is disclosed herein. Methods to prepare and to utilize the fluid, and to inhibit biological degradation of a well treatment fluid, are also disclosed.

Abstract: A method of deploying a borehole filtration device is provided utilizing the steps of: deploying a filtration device comprising a polymer foam having a first cell structure, a portion of the molecular structure of which polymer foam is degradable by exposure to a post-treatment fluid, into a borehole; and exposing the polymer foam to the post-treatment fluid, thereby modifying the cell structure of the polymer foam to a second cell structure.

Abstract: Methods and compositions that comprise sub-micron alumina for accelerating setting of a cement composition. An embodiment includes a method of cementing in a subterranean formation. The method may comprise introducing a cement composition into the subterranean formation, wherein the cement composition comprises hydraulic cement, sub-micron alumina, and water. The method further may comprise allowing the cement composition to set in the subterranean formation. Another embodiment includes a cement composition that may comprise hydraulic cement, sub-micron alumina, and water.

Abstract: A method and a sealing fluid for setting a packer in an annulus between a well bore and a well tubular is provided, which by adjusting i.a. the density, viscosity and setting time of the sealing fluid is able to provide among other things a full radial seal with an acceptable axial dispersion, in particular in highly deviated wells and/or in wells having eccentric annuli.

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

Abstract: Polymeric additives used with viscoelastic surfactants, fluids comprising such additives and viscoelastic surfactants, and associated methods of use, are provided. In one embodiment, the methods comprise: providing a treatment fluid that comprises an aqueous base fluid, a viscoelastic surfactant, and an amphiphilic polymer, the amphiphilic polymer comprising a hydrophobic component, and a hydrophilic component comprising at least 15 monomer units; and introducing the treatment fluid into at least a portion of a subterranean formation.

Abstract: A drag-reducing additive includes 40-85% by weight of a polymer emulsion that includes a polymer, a first surfactant, and a first solvent; 10-35% by weight of a second surfactant with an HLB greater than 8; and 5-30% by weight of a second solvent. In a preferred embodiment, the second solvent includes a terpene. In another preferred embodiment, the polymer is a copolymer that includes acrylamide and acrylic acid.

Abstract: A method of treating a wellbore may include emplacing in at least a selected region of the wellbore a formulation that includes at least one diene pre-polymer; at least one reactive diluent; at least one inert diluent comprising an oleaginous liquid or a mutual solvent; and at least one initiator; and initiating polymerization of the at least one diene pre-polymer and the at least one reactive diluent to form a composite material in the selected region of the wellbore.

Abstract: Composite mixtures are disclosed that include: (a) proppant, and (b) fibers, and/or (c) one or more of an organic binder, wax, gel, oil or polymeric binder. A method for improving the engineering properties of proppants includes adding one or more of the materials to the proppant, and mixing them for incorporation into a hydraulic fluid (such as water). Alternatively, the proppants, and/or fibers and/or other constituents may be added separately to a hydraulic fluid such as water.

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: A capsule for carrying a proppant for emplaced in a formation containing formation fluid by a hydraulic fracture operation using a fracturing fluid. The capsule includes a capsule body. The capsule body includes a proppant. There is a surface layer on the capsule body that is permeable to the formation fluid or the fracturing fluid or is permeable to both the formation fluid and the fracturing fluid. The proppant material is dry cement that interacts with the formation fluid or the fracturing fluid or both the formation fluid and the fracturing fluid that migrate through the surface layer and is taken up by the dry cement causing the dry cement to harden.

Abstract: A composition including a wellbore work fluid and a polymer having mechanically labile chemical bonds is injected downhole, and combines with fluid present downhole to yield a composite fluid. Mechanical energy (e.g., ultrasonic energy) is provided to the composite fluid downhole to cleave the mechanically labile chemical bonds in the polymer. The polymer may be used as a viscosifier, friction reducer, or fluid loss additive. Cleaving the mechanically labile chemical bonds with mechanical energy allows precise degradation downhole.

Abstract: This invention relates to a process for inhibiting scaling in a subterranean oil or gas producing formation, comprising adding to the formation a composition comprising a metal chelant, a scale inhibitor and divalent metal cations, wherein the stability constant of the metal chelant-metal cation chelate at ambient temperature is equal to or higher than the stability constant of the chelate formed from the metal cations and the scale inhibitor, and wherein the solubility of the chelate formed from the metal cations and the scale inhibitor decreases with increasing temperature.

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 instant application relates to nanogels or compositions that hold multivalent metal ions until some level of nanogel degradation has occurred, then slowly release the multivalent metal ions for gelation with carboxylate containing polymers. Compositions comprising such nanogels, together with polymers that can be crosslinked with multivalent metal ions, allow the deployment of such mixtures in various applications, and greatly increased gelation times.

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: 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: The present invention relates to hollow hydrogel capsules. In various embodiments, the present invention provides a method of treating a subterranean formation with a hollow hydrogel capsule including a hydrogel shell including a hydrolyzed and crosslinked polymerized composition. The hollow hydrogel capsule also includes a hollow interior including at least one component of a downhole composition for subterranean petroleum or water well drilling, stimulation, clean-up, production, completion, abandonment, or a combination thereof. In various embodiments, the present invention provides compositions comprising the hollow hydrogel capsules and methods of making the hollow hydrogel capsules.

Abstract: Proppants for hydraulic fracturing of oil and gas wells have a polymeric coating that is strengthened with reinforcing particulates that are reactive with, or chemically bonded to, the polymeric proppant coating. Preferably, these particulates are added into the coating during the coating process. In one embodiment, functionalized particulates are used that become grafted into the polymer of the proppant coating through the chemical functionality imparted to the particulates. If non-functionalized particulates are used, a coupling agent is preferably added to enhance the bond strength between the added particulates and the polymeric matrix of the proppant coating.

Abstract: The present disclosure is directed to a thermothickening composition comprising: a surfactant; and a thermothickening polymer that is the product of at least the following monomers: a non-ionic hydrosoluble unsaturated amide monomer; an ionic monomer; and an unsaturated dicarboxylic acid half ester having a heat sensitive functional group.