Abstract: A method of treating a well or a subterranean formation with an aqueous treatment fluid containing one or more oil-soluble, water-insoluble well treatment agents. The fluid includes an aqueous dispersion containing the well treatment agent in an amount from 25 to 60 weight percent. The volume average particle diameter of the oil-soluble well treatment agent in the fluid may be less than or equal to 2.5 microns. The fluid may further contain a water-soluble well treatment agent.

Abstract: A nanometer plugging water-based drilling fluid and preparation method and use thereof are within this disclosure. The nanometer plugging water-based drilling fluid comprise a nanometer plugging agent. The nanometer plugging agent may be surface modified SiO2 powder with the surfactant. The surfactant may be sodium dodecyl benzene sulfonate and/or sodium dodecyl sulfate. The nanometer plugging water-based drilling fluid may perform effective anti-collapse of stratum and maintain the stability of stratum.

Abstract: Provided herein are carbon-based oxide (CBO) materials and reduced carbon-based oxide (rCBO) materials, fabrication processes, and devices with improved performance and a high throughput. In some embodiments, the present disclosure provides materials and methods for synthesizing CBO and rCBO materials. Such methods avoid the shortcomings of current synthesizing methods to facilitate facile, high-throughput production of CBO and rCBO materials.

Abstract: Systems and methods for treating subterranean formations using particulates treated with hydrophobizing agents in aqueous base fluid are provided. In one embodiment, the methods comprise: providing a treatment fluid comprising an aqueous base fluid and at least one particulate treated with one or more hydrophobizing agents; introducing the into a wellbore penetrating at least a portion of a subterranean formation; and using the treatment fluid to drill a portion of the wellbore.

Abstract: A hydraulic fracturing fluid comprising a water-in-oil emulsion comprising (i) an aqueous solution, (ii) an oil, (iii) a first surfactant, and, optionally, (iv) at least one secondary surfactant selected from an emulsifying surfactant and/or a phosphate ester of ethoxylated alcohol or alkylphenol, and methods of making and using the same.

Abstract: A composition of a treatment fluid having an aqueous base fluid and a true crystallization temperature reduction additive. A method includes providing a treatment fluid having an aqueous base fluid, adding a true crystallization temperature reduction additive and placing the treatment fluid in a subterranean wellbore.

Abstract: The present invention is an improved method of production of graphenic materials used to store energy and the energy storage systems using such produced graphenic materials. Provided herein is a method of producing graphene oxide that includes oxidizing graphite powder in a mixture of H3PO4 and H2SO4 in the presence of KMnO4, wherein the ratio of graphite powder to KMnO4 is about 1:9 by weight and the ratio of H3PO4 to H2SO4 is about 1:9 by volume, to produce graphene oxide; dispersing the graphene oxide in water at an acidic pH (e.g., about 0) to form a solution; adjusting the solution to about a neutral pH; and isolating the graphene oxide. An energy storage device is provided herein that includes the graphene oxide made by the disclosed methods or that includes the population (plurality) of reduced graphene oxide particles having the properties disclosed herein, such as batteries and supercapacitors.

Abstract: This can be a method of making a high strength composite reinforcing fiber using flat GO flakes coated on a conventional reinforcing fiber. This maintains some the flexibility of the fiber and aligns the flat graphene flakes along the surface of the fiber; this dramatically increases the strength of the fiber. It also allows bonding between overlapping flakes, in contrast to flakes being uniformly dispersed in a host material that is being reinforced and dramatically increases the strength of the host material.

Abstract: Provided are compositions, methods, and systems that relate to use of crystallization temperature reduction additives in treatment fluids. A treatment fluid for use in subterranean operations, the treatment fluid comprising: a bromide brine having a first true crystallization temperature; a true crystallization temperature reduction additive, the first true crystallization temperature is the true crystallization temperature of the bromide brine without inclusion of the true crystallization temperature reduction additive; the treatment fluid has a second true crystallization temperature that is lower than the first true crystallization temperature.

Abstract: Drilling fluids having improved rheology under downhole temperature and pressure. The improved rheology (IR) drilling fluids are particularly suited for use in deepwater drilling operations. The IR drilling fluids are invert emulsion fluids with viscosifier to rheology modifier weight ratios between about 6 and about 14. The IR drilling fluids exhibit low shear yield point variance and/or yield point variance of below 60 percent based on high-temperature, high-pressure viscometer measurements.

Abstract: Application of polyaminated fatty acid-based oil compositions to additive particles to control dusting. A method reducing an amount of dust produced during transfer of additive particles in well operations may comprise providing treated additive particles comprising additive particles and a polyaminated fatty acid-based oil composition disposed on a surface of at least portion of the particles, wherein the polyaminated fatty acid-based oil composition comprises a polyaminated fatty acid and an organic solvent. The method may further comprise mixing components comprising the treated additive particles and a base fluid to provide a treatment fluid. The method may further comprise introducing the treatment fluid into a subterranean formation.

Abstract: A method of treating a subterranean formation comprising: forming a treatment fluid by adding a desired volume of a liquid concentrate suspension to at least a base fluid, wherein the treatment fluid comprises the liquid concentrate suspension and the base fluid, and wherein the liquid concentrate suspension comprises: (A) water; (B) an additive; and (C) a magnesium silicate clay, wherein the clay increases the viscosity of the water, wherein the liquid concentrate suspension is stable for a time period of at least 2 weeks; and introducing the treatment fluid into the subterranean formation.

Abstract: Drilling fluids were developed including a base fluid, a weighting agent and/or a bridging agent, and a thickening agent, where the weighting agent and/or the bridging agent includes a particulate strontium carbonate having a desired distribution, for weighting agents, the distribution includes particles between 2? and 5000? and for bridging agents, the distribution is constructed from particles having specific sizes. Methods making and using the drilling fluids were also discovered.

Abstract: An acid soluble defluidizing pill for reducing fluid loss in a wellbore is provided that includes an oleaginous or non-oleaginous base fluid; at least one synthetic fiber; and at least one inorganic crystalline fiber; in which one or more of the synthetic fiber and the inorganic crystalline fiber are at least substantially acid soluble.

Abstract: An audio device with an insertion part being adapted to be inserted into an ear canal of a user. The insertion part comprises pressure means and a resilient surface. The resilient surface comprises an adhesive, which is adapted to adhere to a skin portion of a bony portion of an ear canal of a user. The pressure means are adapted to provide a force to press the adhesive against the skin portion. The pressure means include a phase-changing material, which is adapted to cause a reduction in the force, when heat is supplied to the phase-changing material.

Abstract: The present invention relates to a preparation method of graphene oxide based on mixed acid system. The method consists of the following steps. a. Preparation of graphite powder; b. Preparation of suspension liquid of first acid system; c. Preparation of second acid system; d. Preparation of graphene oxide. The invention also relates to a preparation method of graphene using graphene oxide obtained by method mentioned above. The method consists of the following steps. e. Preparation of graphene oxide-dispersant solution; f. Reduction of graphene oxide; g. Process of supersonic stripping; h. Obtaining graphene by separation and drying. The preparation methods of graphene oxide and graphene in our invention could reduce the dosage of strong acid as well as heat release of chemical reaction, and cause less corrosion to our equipments, which makes the reaction more effective and properties of graphene products better, facilitating the achievement of large scale industrial production.

Abstract: A method of fabricating a graphene oxide material in which oxidation is confined within the graphene layer and that possesses a desired band gap is provided. The method allows specific band gap values to be developed. Additionally, the use of masks is consistent with the method, so intricate configurations can be achieved. The resulting graphene oxide material is thus completely customizable and can be adapted to a plethora of useful engineering applications.

Abstract: There is described a drilling fluid for wellbore strengthening having nanoparticles and granular particles. In one aspect described herein, the drilling fluid is an invert emulsion based fluid. In a further aspect, the nanoparticles are iron hydroxide or calcium carbonate, and in a further aspect from about 1 to 30 nm in size. In one aspect described herein, the granular particles are graphite or calcium carbonate and in a further aspect, up to 250 ?m in size. The nanoparticles and granular particles plug fractures in the wellbore to strengthen the wellbore.

Abstract: A method for controlling the loss of drilling fluid from an oil well borehole into formations penetrated by a drill bit is disclosed by which resilient graphitic carbon particles having a resiliency greater than about 130% rebound after compression to 10,000 psi; a degree of graphitization greater than 85%, as measured by d002 using XRD; an average pore size larger than 0.035 micron; and an aspect ratio smaller than 0.63 are added to the drilling fluid.

Abstract: A treatment fluid comprises: a metal oxide, wherein the metal oxide is capable of forming a chelate complex or coordination complex with a ligand, wherein the chelate complex or coordination complex has a setting time of less than 90 minutes at a temperature of 71° F. and a pressure of 1 atmosphere. A method of treating a portion of a subterranean formation comprises: introducing the treatment fluid into the subterranean formation; allowing or causing a chelate complex or coordination complex to form between the metal oxide and a ligand; and allowing or causing the chelate complex or coordination complex to set.

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: The present invention relates to oil well drilling comprising a weighting agent consisting of microfine, particulate ilmenite having a FeTiO3 content of at least 85% by weight, a specific surface area (BET) between 1 and 5 m2/g, where 90% by volume of the particles have a size of less than 12.5 ?m and a D50 between 3 ?m and 6 ?m by volume measured by laser diffraction using Malvern laser diffraction particle size analyzer, where the particles have an average circularity of at least 0.85 determined by image analysis. The invention further relates to high density oil well cement slurry comprising water, Portland cement, a to weighting material and optionally silica flour, microsilica, fiber, rubbery particles a fluid loss addition and a retarder, where the weighting material is particulate microfine ilmenite having a FeTiO3 content of at least 85% by weight, a specific surface area (BET) between 1 and 5 m2/g, and where 90% by volume of the particles have a size of less than 12.

Abstract: A system and method of treating a fluid to be used for hydraulic fracturing adds an effective amount of chlorine dioxide to the fluid to act as a biocide that kills harmful bacteria. A system for adding chlorine dioxide to the fluid can continuously add chlorine dioxide to an incoming flow of the fluid to produce a continuous flow of treated fluid.

Abstract: Disclosed are spacer fluids comprising cement kiln dust (“CKD”) and methods of use in subterranean formations.

Abstract: A cordierite material having an increased ?-cordierite phase and a reduced ?-cordierite phase is described. Methods of making the cordierite material are further described, and a proppant containing the cordierite is further described, as well as use of the proppant.

Abstract: Methods of treatment subterranean formations including providing a treatment fluid comprising a base fluid and a lubricating agent, wherein the lubricating agent is selected from the group consisting of bismuth dialkyl dithiophosphate; tungsten disulfide; a mixture of micronized graphite and micronized metal disulfide; and any combination thereof; and introducing the treatment fluid into a wellbore in the subterranean formation.

Abstract: In some embodiments, the present invention pertains to methods of detecting a contamination of an environment by a fracture fluid that comprises magnetic particles. In some embodiments, such methods include: (1) collecting a sample from the environment; and (2) measuring a magnetic susceptibility of the sample in order to detect the presence or absence of the magnetic particles. Further embodiments of the present invention pertain to methods of tracing fracture fluids in a mineral formation. In some embodiments, such methods include: (1) associating the fracture fluids with magnetic particles; (2) introducing the fracture fluids into the mineral formation; and (3) measuring a magnetic susceptibility of the fracture fluids. Additional embodiments of the present invention pertain to fracture fluids containing the aforementioned magnetic particles, the actual magnetic particles, and methods of making said magnetic particles.

Abstract: Nanomaterial compositions are useful for applications in drilling and completion fluids as enhancers of electrical and thermal conductivity, emulsion stabilizers, wellbore strength improvers, drag reduction agents, wettability changers, corrosion coating compositions and the like These nanomaterials may be dispersed in the liquid phase in low volumetric fraction, particularly as compared to corresponding agents of larger size. Nanofluids (fluids containing nano-sized particles) may be used to drill at least part of the wellbore. Nanofluids for drilling and completion applications may be designed including nanoparticles such as carbon nanotubes. These fluids containing nanomaterials, such as carbon nanotubes, meet the required rheological and filtration properties for application in challenging HPHT drilling and completions operations.

Abstract: A drilling fluid for discharging in a borehole to facilitate drilling operations, and hydraulic fracturing in particular, comprising amorphous silicas having a particle size ranging from about one to about ten nanometers and water, wherein the pH of the fluid is substantially neutral.

Abstract: Defoamer compositions are disclosed and methods for making and using same, where the defoamer has universal applicability at low concentrations. The defoamer compositions include between 40 vol. % and about 80 vol. % distilled water (other waters may be used instead), 10 vol. % and about 30 vol. % of silicon anti-foam agent and between about 10 vol. % and about 30 vol. % of active silicon anti-foam agent. The defoamer compositions are used in amount of less than or equal to 200 ppm in all foamed downhole fluid systems.

Abstract: A method for controlling the loss of drilling fluid from an oil well borehole into formations penetrated by a drill bit is disclosed by which resilient graphitic carbon particles having a resiliency greater than about 130% rebound after compression to 10,000 psi; a degree of graphitization greater than 85%, as measured by d002 using XRD; an average pore size larger than 0.035 micron; and an aspect ratio smaller than 0.63 are added to the drilling fluid.

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: According to an embodiment, a drilling fluid comprises: water and a set accelerator, wherein the drilling fluid has a 10 minute gel strength of less than 20 lb*ft/100 sq ft, wherein the drilling fluid has a density in the range of about 9 to about 14 pounds per gallon, wherein the drilling fluid remains pourable for at least 5 days, and wherein when at least one part of the drilling fluid mixes with three parts of a cement composition consisting of water and cement, the drilling fluid cement composition mixture develops a compressive strength of at least 1,200 psi. According to another embodiment, a method of using the drilling fluid comprises the steps of: introducing the drilling fluid into at least a portion of a subterranean formation, wherein at least a portion of the drilling fluid is capable of mixing with a cement composition.

Abstract: Nanomaterial compositions are useful for applications in drilling and completion fluids as enhancers of electrical and thermal conductivity, emulsion stabilizers, wellbore strength improvers, drag reduction agents, wettability changers, corrosion coating compositions and the like. These nanomaterials may be dispersed in the liquid phase in low volumetric fraction, particularly as compared to corresponding agents of larger size. Nanofluids (fluids containing nano-sized particles) may be used to drill at least part of the wellbore. Nanofluids for drilling and completion applications may be designed including nanoparticles such as carbon nanotubes. These fluids containing nanomaterials, such as carbon nanotubes, meet the required rheological and filtration properties for application in challenging HPHT drilling and completions operations.

Abstract: Mineral particles may provide for wellbore fluids with tailorable properties and capabilities, and methods relating thereto. Mineral particles may be utilized in a method that comprises introducing a wellbore fluid into a wellbore penetrating a subterranean formation, the wellbore fluid comprising a base fluid and a plurality of mineral particles that comprise at least one selected from the group consisting of manganese carbonate, NixFe (x=2-3), copper oxide, and any combination thereof, the mineral particles having a median diameter between about 5 nm and about 5000 microns.

Abstract: Mineral particles may provide for wellbore fluids with tailorable properties and capabilities. In some instances, a dry wellbore additive may comprise a plurality of first mineral particles having a specific gravity of about 2.6 to about 20; a plurality of second mineral particles having a specific gravity of about 5.5 to about 20; a plurality of lubricant particles having a specific gravity of about 2.6 to about 20; wherein the first mineral particles, the second mineral particles, and the lubricant particles are different; and wherein the first mineral particles, the second mineral particles, and the lubricant particles have a multiparticle specific gravity of about 3 to about 20.

Abstract: A method of using precipitated particles in a wellbore may comprise circulating a wellbore fluid in a wellbore penetrating a subterranean formation, the wellbore fluid having a density of about 7 ppg to about 50 ppg and comprising a base fluid and a plurality of precipitated particles having a shape selected from the group consisting of ovular, substantially ovular, discus, platelet, flake, toroidal, dendritic, acicular, spiked with a substantially spherical or ovular shape, spiked with a discus or platelet shape, rod-like, fibrous, polygonal, faceted, star shaped, and any hybrid thereof.

Abstract: A method of treating a subterranean formation. The method may include providing a fluid-loss control pill that comprises an aqueous base fluid, a gelling agent, and an internal breaker that is selected from the group consisting of inorganic delayed acids or inorganic salts. The method can include introducing the fluid-loss control pill into a subterranean formation, allowing the internal breaker to reduce the viscosity of the pill after a delay period, and allowing the fluid-loss control pill to break.

Abstract: A method of formulating a wellbore fluid that includes precipitating a weighting agent from a solution; and adding the precipitated weighting agent to a base fluid to form a wellbore fluid is disclosed. Fluids and methods of formulating wellbore fluids that contain dispersant coated precipitated weighting agents are also disclosed.

Abstract: A treatment fluid comprises: a metal oxide, wherein the metal oxide is capable of forming a chelate complex or coordination complex with a ligand, wherein the chelate complex or coordination complex has a setting time of less than 90 minutes at a temperature of 71° F. and a pressure of 1 atmosphere. A method of treating a portion of a subterranean formation comprises: introducing the treatment fluid into the subterranean formation; allowing or causing a chelate complex or coordination complex to form between the metal oxide and a ligand; and allowing or causing the chelate complex or coordination complex to set.

Abstract: The present invention relates to oil well drilling comprising a weighting agent consisting of microfine, particulate ilmenite having a FeTiO3 content of at least 85% by weight, a specific surface area (BET) between 1 and 5 m2/g, where 90% by volume of the particles have a size of less than 12.5 ?m and a D50 between 3 ?m and 6 ?m by volume measured by laser diffraction using Malvern laser diffraction particle size analyzer, where the particles have an average circularity of at least 0.85 determined by image analysis. The invention further relates to high density oil well cement slurry comprising water, Portland cement, a weighting material and optionally silica flour, microsilica, fiber, rubbery particles a fluid loss addition and a retarder, where the weighting material is particulate microfine ilmenite having a FeTiO3 content of at least 85% by weight, a specific surface area (BET) between 1 and 5 m2/g, and where 90% by volume of the particles have a size of less than 12.

Abstract: A composition comprises: a treatment fluid comprising a lost-circulation material, wherein the lost-circulation material comprises a ceramic, and wherein the lost-circulation material has a median particle size in the range from about 0.001 millimeters to about 25.4 millimeters. According to another embodiment, a composition comprises: the treatment fluid comprising a lost-circulation material, wherein the lost-circulation material comprises a ceramic, and wherein the median particle size and the concentration of the lost-circulation material is selected such that the treatment fluid has a sealing pressure of at least 50 psi (0.3 MPa). A method of eliminating or reducing lost circulation from a well comprises: introducing the treatment fluid into at least a portion of the well.

Abstract: According to one aspect of the invention, a method of converting an oxy halide salt into a halide dioxide in a reaction zone under certain conditions is provided. More specifically, the method includes generating chlorine dioxide from a stable composition comprising an oxy halide salt by introducing said composition to a reducing agent and minimum temperature within the reaction zone. According to another aspect of the invention, a composition for a stable chlorine dioxide precursor comprising an oxy halide salt is provided.

Abstract: A composition and method for use in drilling or completing a subterranean well comprising a solidsfree, high-density brine composed of alkali metal polytungstate and blends thereof. These high-density brines are also useful as wellbore fluids and other non-oilfield fluids requiring high density properties.

Abstract: A wellbore treatment fluid comprising one or more high-density weighting materials selected from the group consisting of tungsten-containing materials, bismuth-containing materials, and tin-containing materials.

Abstract: The invention provides a method of manufacturing a solid phase barite containing material for use in a wellbore. The method includes the steps of providing the barite containing material having relatively small particles with a particle size distribution of at least 50 vol % particles having a diameter in the range of 1 ?m to 10 ?m and at least 90 vol % particles having a diameter in the range of 4 ?m to 20 ?m; and contacting the barite containing material with a liquid in order to form relatively large particles having a particle size distribution with at least 90 vol % of the particles having a diameter of at least 30 ?m. There is also described a method of treating a wellbore with a fluid including the barite containing material.

Abstract: A method of drilling a gas or oil well consists of use of a water-based drilling fluids containing high molecular weight crosslinked polyacrylic acid as viscosifying agent. The drilling fluid may further contain a lubricant, weighting agent and/or a wetting agent as well as a synthetic silicate or smectite clay. The aqueous based drilling fluid exhibits a coefficient of friction which is substantially close to the coefficient of friction of oil based drilling muds. The drilling fluid exhibits stability at well temperatures in excess of 150° C.

Abstract: According to one aspect of the invention, a method of converting an oxy halide salt into a halide dioxide in a reaction zone under certain conditions is provided. More specifically, the method includes generating chlorine dioxide from a stable composition comprising an oxy halide salt by introducing said composition to a reducing agent and minimum temperature within the reaction zone. According to another aspect of the invention, a composition for a stable chlorine dioxide precursor comprising an oxy halide salt is provided.

Abstract: Various salt crystal and agglomeration settling inhibiting agents may aid the ability to keep salt crystals of a desired particle size undissolved and dissolved in an aqueous drilling fluid, including, whey, wine-making residues, “steepwater solubles” or an organic liquid formed from the residue of wet processing of grains, sugar cane, sugar beets, and similar plants for the food and beverage industries for consumption by human or animals, and combinations thereof. A fluid so treated has more uniform properties and a reduced tendency for the salt therein to settle out as compared to an otherwise identical fluid absent an effective proportion or amount of the salt crystal agglomeration and settling inhibiting agent, even for saturated salt fluids. The salt crystal agglomeration and settling inhibiting agents are also believed to be useful in inhibiting or preventing the formation of gas hydrates under gas hydrate forming conditions of low temperature and high pressure.

Abstract: An engineered composition for reducing lost circulation in a well includes a mixture of coarse, medium and optional fine particles, and a blend of long fibers and short fibers. The long fibers are rigid and the short fibers are flexible. The long fibers form a tridimensional mat or net in the lost-circulation pathway that traps the mixture of particles and short flexible fibers to form a mud cake. The mixture of particles and blend of fibers may be added to water based and oil-based drilling fluids. The composition, size, and concentration of each component of the mixture of particles and blend of fibers may be fine-tuned for each application.