Abstract: The present invention concerns the use of at least one compound A comprising at least one —SH or —S—, M+group, at least one —C-G-C— chain, in which G represents an atom from column 16 of the periodic table, not comprising a carboxy group —C(?O)—OH or —C(?O)—O—, and of a molar mass of between 90 g·mol-1 and 1000 g·mol-1, as an additive in a formulation inhibiting corrosion in metals used in the oil industry, and more generally in any kind of industry involving the drilling of ores or fossil compounds, such as gas or oil, in order to improve both the anti-corrosion performance and the storage stability of same. The invention also concerns said corrosion-inhibiting formulations comprising at least one compound A.

Abstract: A degradable object including a shell comprising a degradable material, a substance disposed at least partially within the shell, the substance having a coefficient of thermal expansion greater than a coefficient of thermal expansion of the shell.

Abstract: Systems and methods for producing fluids from a subterranean well include introducing expandable beads into a target region of a production zone of the subterranean well, the expandable beads being formed of thermally expandable material in an unexpanded condition with a first diameter. A radial confining stress is increased and a hoop stress is decreased within the target region by thermally expanding the expandable beads so that the beads are in an expanded condition with a second diameter, the second diameter being greater than the first diameter.

Abstract: Embodiments of the present invention relate to drilling oil, and to a method of preparing the drilling oil, including converting C16 and/or C18 fatty acids derived from fat of biological origin into C15 and/or C17 olefins through decarbonylation.

Abstract: Disclosed herein are monoester-based lubricant compositions and methods of making these monoester-based lubricant compositions. The monoester lubricant compositions comprise an isomeric mixture of at least one monoester species having a carbon number ranging from C8 to C40. In some embodiments, the methods for making the monoester-based lubricants utilize a biomass precursor and/or low value Fischer-Tropsch (FT) olefins and/or alcohols to produce high value monoester-based lubricants. In some embodiments, the monoester-based lubricants are derived from FT olefins and fatty acids. The fatty acids can be from a bio-based source (i.e., biomass, renewable source) or can be derived from FT alcohols via oxidation.

Abstract: The present invention is directed to monoester-based drilling fluid compositions and the method of drilling a borehole with said compositions. In some embodiments, the methods for making such monoester-based lubricants utilize a biomass precursor and/or low value Fischer-Tropsch (FT) olefins and/or alcohols so as to produce high value monoester-based drilling fluids. In some embodiments, such monoester-based drilling fluids are derived from FT olefins and fatty acids. The fatty acids can be from a bio-based source (i.e., biomass, renewable source) or can be derived from FT alcohols via oxidation.

Abstract: A method for the encapsulation and triggered-release of water-soluble or water-dispersible materials. The method comprises a) providing an amount of electrolyte having a charge, b) providing an amount of counterion having a valence of at least 2, c) combining the polyelectrolyte and the counterion in a solution such that the polyelectrolyte self-assembles to form aggregates, d) adding a compound to be encapsulated, and e) adding nanoparticles to the solution such that nanoparticles arrange themselves around the aggregates. Release of the encapsulated species is triggered by disassembly or deformation of the microcapsules though disruption of the charge interactions. This method is specifically useful for the controlled viscosity reduction of the fracturing fluids commonly utilized in the oil field.

Abstract: A spacer fluid comprises a fluid and a viscosity agent. The viscosity agent is a mixture of at least two polyvinylalcohol compositions. A first polyvinylalcohol composition comprises polyvinylalcohols having a first degree of hydrolysis and a second polyvinylalcohol composition comprises polyvinylalcohols having a second degree of hydrolysis. The first and second degrees of hydrolysis are substantially different such that the rheology of the spacer fluid is stable during temperatures changes.

Abstract: Provided herein are inter alia novel compositions and methods having application in a variety of fields including the field of enhanced oil recovery, the cleaning industry as well as groundwater remediation. In particular, the alkoxy carboxylate compounds and mixtures thereof presented herein can be used, inter alia, for the recovery of a large range of crude oil compositions from challenging reservoirs.

Abstract: A composition for enhancing fluid viscosity including a mixture of at least one cationic or cationizable polymer and at least one anionic or anionizable (hydrolysable) polymer. The composition has a zeta potential at 25° C. in the range of 0.5 to 100 mV or ?0.5 to ?100 mV, typically 1 to 60 mV or ?1 to ?60 mV, or is a precursor convertible at a temperature of 100 to 250° C. to the composition having a zeta potential at 25° C. of 0.5 to 100 mV or ?0.5 to ?100 mV, typically 1 to 60 mV or ?1 to ?60 mV. Typically the compositions exhibit salt tolerance and interaction of both polymers at very high temperatures (>300° F.) such that the system exhibits an increase of viscosity at extreme temperatures. The compositions are useful for hydraulic fracturing, enhanced oil recovery, subterranean acidization, personal care as well as home and industrial cleaners.

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: A well treatment fluid comprising a Pickering particle emulsion comprising particles of a first liquid phase dispersed in a continuous second liquid phase, and comprising a plurality of colloidal particles adsorbed to a liquid-liquid interface between the first liquid phase and the second liquid phase. Methods, equipment and/or systems for treating a subterranean formation utilizing such treatment fluids are also disclosed.

Abstract: Of the many compositions and methods provided herein, an example method includes a method of treating a subterranean formation that comprises combining components comprising water and a density-matched suspension to prepare a treatment fluid, wherein the density-matched suspension comprises a suspending liquid and a solid particle suspended in the suspending liquid, and introducing the treatment fluid into a well bore. An example composition includes a suspension that comprises a suspending liquid comprising a hydrophobic liquid, wherein the hydrophobic liquid hydrolyzes when placed in contact with an aqueous fluid to form hydrophilic products, and a solid particle suspended in the suspending liquid, wherein the suspension is a density-matched suspension.

Abstract: A method of treating a very high salinity high temperature hydrocarbon containing formation is described. The method includes (a) providing a hydrocarbon recovery composition to at least a portion of a hydrocarbon containing formation having a brine salinity of above about 13 wt % and a temperature of above about 7° C., wherein the composition comprises a C15-18 internal olefin sulfonate; and (b) allowing the composition to interact with hydrocarbons in the hydrocarbon containing formation.

Abstract: A wellbore fluid that includes an aqueous based fluid; an amphoteric, viscoelastic surfactant; and a modified starch is disclosed. Methods of drilling subterranean wells, methods of reducing the loss of fluid out of subterranean wells, and methods of completing wellbores using aqueous-based fluids having an ampoteric, viscoelastic surfactant and a modified starch are also disclosed.

Abstract: A method of cleaning a wellbore prior to the production of oil or gas is disclosed, wherein the wellbore has been drilled with an invert emulsion drilling mud that forms an invert emulsion filter cake. The method may include the steps of circulating a breaker fluid into the wellbore, where the breaker fluid includes an aqueous fluid, and imino diacetic acid or salt thereof. Optionally an acid buffering agent, and a weighting age are also included. The breaker fluid is formulated such that after a predetermined period of time and the filter cake present in the wellbore or on the wellbore face is substantially degraded. Other methods may also include drilling the wellbore with a water-based drilling mud that forms a water-based filter cake, wherein the method may include the steps of circulating a breaker fluid into the wellbore, where the breaker fluid may include an aqueous fluid, and an iminodiacetic acid or a salt thereof.

Abstract: Spray dried emulsifier compositions are described, which have desirable emulsifying and wetting characteristics. Among other advantages, the solid particulate emulsifier compositions greatly reduce transportation costs and simplify the logistics and environmental concerns associated with shipping large volumes of solvent-containing liquids. The emulsifier comprises (1) a carboxylic acid terminated fatty amine condensate or (2) a modified tall oil or (3) a blend of (1) and (2) that is converted to its alkali or alkaline earth metal salt and spray dried.

Abstract: A pill for wellbore operations, that includes a base fluid; and at least two polymers that interact to form a gelatinous structure characterized as isolating and controllably transmitting hydrostatic pressure between a first wellbore fluid above the pill in a wellbore and a second wellbore fluid below the pill in the wellbore is disclosed.

Abstract: A wellbore treatment fluid is formed from an aqueous medium, a gas component, a viscosifying agent, and a surfactant. The surfactant is represented by the chemical formula: [R—(OCH2CH2)m—Oq—YOn]pX wherein R is a linear alkyl, branched alkyl, alkyl cycloaliphatic, or alkyl aryl group; O is an oxygen atom; Y is either a sulfur or phosphorus atom; m is 1 or more; n is a integer ranging from 1 to 3; p is a integer ranging from 1 to 4; q is a integer ranging from 0 to 1; and X is a cation. The fluid may be used in treating a subterranean formation penetrating by a wellbore by introducing the fluid into the wellbore. The fluid may be used in fracturing a subterranean formation penetrated by a wellbore by introducing the fluid into the formation at a pressure equal to or greater than the fracture initiation pressure.

Abstract: The invention discloses a method of for changing the water permeability of a subterranean formation of a well, the method comprising: providing a fluid comprising a liquid carrier and a viscoelastic surfactant; introducing the fluid into the well; and contacting the fluid and the subterranean formation wherein the action of the liquid carrier and the viscoelastic surfactant is able to change the water permeability of the subterranean formation. The fluid may further comprise methanol, or a salt which can be embodied within the carrier fluid. Advantageously, no further RPM polymer is used. In a first aspect the method is used for reducing the amount of water produced, in as second aspect for improving the oil recovery.

Abstract: Biphenylmono- and polysulphonic acids and salts thereof, fluorenemono- and polysulphonic acids and salts thereof as well as p-terphenylmono- and polysulphonic acids and salts thereof may be used successfully as tracers for surveying, monitoring and/or measuring movements of aqueous fluids in aqueous and/or non-aqueous media. Said substances are especially suited for surveying or monitoring movements of fluids in oil wells or reservoirs as well as for fluid movements in hydrothermal reservoirs.

Abstract: A treatment fluid comprising: water; a formate; and a corrosion inhibitor, wherein the corrosion inhibitor is capable of providing: (A) a pH of at least 10; and (B) a corrosion rate equal to or less than 4 mils per year wherein carbon dioxide accounts for at least 100 psi (0.7 MPa) of the total pressure, for a test fluid consisting essentially of: the water; the formate; and the corrosion inhibitor, and in the same proportions as in the treatment fluid, whereas a substantially identical test fluid without the corrosion inhibitor has a pH of less than 10 and a corrosion rate of greater than 4 mils per year under the testing conditions. The treatment fluid can further comprise a scale inhibitor. A method of treating a portion of a well comprises: forming the treatment fluid; and introducing the treatment fluid into the well.

Abstract: A treatment fluid comprising: water; a formate; and a corrosion inhibitor, wherein the corrosion inhibitor is capable of providing: (A) a pH of at least 10; and (B) a corrosion rate equal to or less than 4 mils per year wherein carbon dioxide accounts for at least 100 psi (0.7 MPa) of the total pressure, for a test fluid consisting essentially of: the water; the formate; and the corrosion inhibitor, and in the same proportions as in the treatment fluid, whereas a substantially identical test fluid without the corrosion inhibitor has a pH of less than 10 and a corrosion rate of greater than 4 mils per year under the testing conditions. The treatment fluid can further comprise a scale inhibitor. A method of treating a portion of a well comprises: forming the treatment fluid; and introducing the treatment fluid into the well.

Abstract: Methods of treating a subterranean formation including providing a treatment fluid comprising an oil-based fluid component and an oil-soluble weighting agent that comprises a metal, wherein the oil-soluble weighting agent has a density in the range of from about 1.1 g/cm3 to about 22 g/cm3; solubilizing the oil-soluble weighting agent in the oil-based fluid component of the treatment fluid, wherein the oil-soluble weighting agent increases the density of the oil-based fluid component of the treatment fluid; introducing the oil-based treatment fluid into a wellbore in a subterranean formation.

Abstract: Controlling microbial growth and activity during Microbial Enhanced Oil Recovery processes is disclosed. Specific control of microbial growth and activity in this process results in prevention of nutrient loss in transit and allows better targeting of microbial activity to the desired subsurface location(s).

Abstract: A wellbore fluid for dissolving a filtercake includes a chelating agent and an aqueous solution of carboxylate salt. The concentration of the chelating agent is up to 50 percent volume per volume (v/v) in the aqueous solution of carboxylate salt. A method of treating a well includes preparing a wellbore fluid up to 50 percent volume per volume (v/v) chelating agent in an aqueous solution of carboxylate salt. The method further includes emplacing the wellbore fluid downhole such that the wellbore fluid dissolves a filtercake in the well.

Abstract: Proppants for use in fractured or gravel packed/frac packed oil and gas wells are provided with a contaminant removal component to remove one or more of the contaminants found in subterranean water/hydrocarbon from a production well. The water/hydrocarbon cleaning proppant solids may be used as discrete particles in a proppant formulation, as a coating on proppant solids in pores of a porous proppant solid or as part of the proppant's internal structure. The contaminant removal component removes contaminants, especially dissolved contaminants, in the subterranean water or hydrocarbon before the water/hydrocarbon leaves the well. For those contaminant removal components that can be regenerated, such as ion exchange resins, a measured quantity of an acidic regeneration solution can be injected into the fractured stratum for regeneration and recovered when the well resumes production.

Abstract: A process for mineral oil production, especially Winsor type III microemulsion flooding, in which an aqueous surfactant formulation which comprises at least one alkylpolyalkoxysulfate comprising propoxy groups, and at least one further surfactant differing therefrom is used, is forced through injection wells into a mineral oil deposit and crude oil is removed from the deposit through production wells. The alkylpolyalkoxysulfate comprising propoxy groups is prepared in this case by sulfating an alkoxylated alcohol, the alkoxylated alcohol being prepared by alkoxylating an alcohol using double metal cyanide catalysts or double hydroxide clays.

Abstract: Breaking compositions are disclosed for controlled breaking of borate cross-linked fracturing fluids, and to method for making and using same, where the composition includes an oxidative component and an ester component.

Abstract: Provided herein are inter alia novel compositions and methods having application in a variety of fields including the field of enhanced oil recovery, the cleaning industry as well as groundwater remediation. In particular, the alkoxy carboxylate compounds and mixtures thereof presented herein can be used, inter alia, for the recovery of a large range of crude oil compositions from challenging reservoirs.

Abstract: A method for improving the performance of fracturing processes in oil production fields may rely on polymer coated particles carried in the fracturing fluid. The particles may include heavy substrates, such as sand, ceramic sand, or the like coated with polymers selected to absorb water, increasing the area and volume to travel more readily with the flow of fluid without settling out, or allowing the substrate to settle out. Ultimately, the substrate may become lodged in the fissures formed by the pressure or hydraulic fracturing, resulting in propping open of the fissures for improved productivity.

Abstract: A method of converting an inactive biocide into an active biocide comprises: contacting the inactive biocide with an activating agent, wherein the activating agent is capable of chemically reacting with the inactive biocide; and causing or allowing a chemical reaction to take place between the inactive biocide and the activating agent, wherein the chemical reaction produces the active biocide. The methods can also include deactivating the active biocide via a chemical reaction between the active biocide and a deactivating agent.

Abstract: A biodegradable and environmentally friendly oil external emulsion for the removal of asphaltenes, paraffin's, and/or scales which accumulate in the well bores and walls of the pipes used to bring the oil up from the underground deposits, and methods of using and formulating the composition are disclosed. The emulsion comprises oil extracted from orange peels as the external continuous phase and acid as the internal phase. The emulsion has a particular utility in cleaning asphaltenes and paraffin residues from the well formation surface, well cuttings, and down hole and surface oil well drilling and production equipment.

Abstract: Formulation for a natural product as a replacement for the use of traditional acidic chemical stimulation methods for the emulsification, removal and release of paraffin and asphaltenes from low producing or pumped off wells and reservoirs with the use of traditional methodologies. Also a method of use of formulation for stimulating an oil well consisting of introducing into the wellbore a biodegradable, non-reactive fluid system containing a water-miscible fatty acid solvent, a solution of fatty acids, an amino alcohol, and at least one non-ionic surfactant. The fluid system may be further in the form of a nanoemulsion that is formed by combining a colloidal solution with one or more emulsifiers, an alcohol, and water. The fluid system may be used in well remediation and stimulation as well as additional, alternative applications such as the cleaning of surface and/or downhole equipment.

Abstract: A breaker fluid may include a base fluid; and an inactive chelating agent. A process may include pumping a first wellbore fluid comprising an inactive chelating agent into a wellbore through a subterranean formation; and activating the inactive chelating agent to release an active chelating agent into the wellbore.

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: Manufactures particles comprising a chemical treatment agent which are useful in wells are provided. The particles have the advantage of being able to chemically treat a well, e.g. to remove filter cake. Embodiments of the invention improve well production by providing sand control and/or increasing permeability of a gravel pack. Methods of using the particles and a gravel pack comprising the particles are also provided.

Abstract: A method and apparatus for combining multiple sources of intake water for use in hydraulic fracturing and other oil and gas drilling operations and treating the water with peracetic acid prior to discharging into one or more frac tanks or into a well. The apparatus includes a manifold assembly that combines water from multiple sources prior to entering a mixer where PAA is injected in a finely dispersed spray under pressure to thoroughly mix the PAA and intake water prior to be discharged into one or more frac tanks. By using a manifold assembly, the apparatus is easily transported to different job site-locations and permits the use of standard connection fittings to easily connect the apparatus to existing fracturing equipment. A method for injecting the PAA and testing and adjusting the level of PAA is also disclosed.

Abstract: Adding a lubricant having a metal stearate and polytetrafluoroethylene (PTFE) to a downhole fluid may lubricate a first surface once the downhole fluid has been circulated within a subterranean reservoir wellbore. Friction, torque, and/or drag may be reduced when the lubricated first surface contacts a second surface. The first surface may be or include, but is not limited to a wellbore casing, a drill string, a pipe, a formation, a drill bit, a metal surface within a mud motor, formation evaluation tool, at least one drilling tool, and combinations thereof. One or both of the first and second surfaces may be metal. The downhole fluid may be or include, but is not limited to, a drilling fluid, a completion fluid, a fracturing fluid, a drill-in fluid, a workover fluid, and combinations thereof.

Abstract: A substantially liquid gellant formed as one or more reaction products of a metal carboxylate or metal carboxylate amine salt, one or more organic acids, an ester which drives the reaction so that the reaction products are asymmetrical in structure, and a rheology modifier which preferentially interacts between the reaction products for prevent solidifying of the gellant reaction products until such time as the gellant is mixed with the fracturing fluid containing an activator after which the reaction products preferentially interact with the activator to gel the fracturing fluid. The resulting gellant is capable of gelling a hydrocarbon base fluid in less than about 30 seconds.

Abstract: A method of servicing a wellbore in a subterranean formation comprising placing a composition comprising an acid and/or an acid precursor, a surfactant, and an aqueous base fluid into contact with oil-wet solids in the wellbore; wherein the acid and/or acid precursor is selected from the group consisting of acetic acid; lactic acid; glycolic acid; oxalic acid; propionic acid; butyric acid; monochloroacetic acid; dichloroacetic acid; trichloroacetic acid; hydrochloric acid; nitric acid; sulphuric acid; sulphonic acid; sulphinic acid; phosphoric acid; phosphorous acid; phosphonic acid; phosphinic acid; sulphamic acid; aliphatic polyesters; glucono-delta-lactone; glucoheptonic lactone; poly(?-caprolactones); poly(hydroxybutyrates); poly(anhydrides); aliphatic polycarbonates; poly(amino acids); polyphosphazenes; poly(ortho esters); or combinations thereof.

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: Methods comprising: providing an aqueous treatment fluid comprising an aqueous fluid, a friction reducing polymer, and an antiflocculation additive; and introducing the treatment fluid into a subterranean formation. Methods of fracturing a subterranean formation comprising: providing an aqueous treatment fluid comprising an aqueous fluid, a friction reducing polymer, and an antiflocculation additive; and introducing the treatment fluid into a well bore penetrating the subterranean formation at rate in the range of from about 30 barrels to about 250 barrels per minute so as to create or enhance one or more fractures in the subterranean formation. Aqueous treatment fluids comprising: an aqueous fluid, a friction reducing polymer in an amount sufficient to reduce friction without forming a gel, and an antiflocculation additive.

Abstract: The present invention includes compositions and methods for using an anionic surfactant composition for treating a hydrocarbon-bearing formation or a reservoir, of formula (I): wherein R1 and R2 are identical or different and may independently be alkyl, alkenyl, alkynyl, alkylene, aryl, propylene oxide, ethylene oxide or hydrogen groups in a straight or branched chain with 16 or more carbon atoms, X1 and X2 are identical or different and are selected from the group consisting of phosphate, sulfate, carboxylate, sulfonate or other suitable anionic groups, S is a spacer group selected from short or long arkyl, alkenyl, alkynyl, alkylene, stilbene, polyethers, and other suitable aliphatic or aromatic groups comprising 2 to 12 carbon atoms.

Abstract: Fracturing fluid compositions and methods of fracturing subterranean formations using polyboronic compounds as crosslinking agents are provided. The compositions and methods of the present invention allow for lower polymer loadings because achieving higher fracturing fluid viscosities can be achieved using less polymer than in traditional crosslinked systems.

Abstract: A method of converting an inactive biocide into an active biocide comprises: contacting the inactive biocide with an activating agent, wherein the activating agent is capable of chemically reacting with the inactive biocide; and causing or allowing a chemical reaction to take place between the inactive biocide and the activating agent, wherein the chemical reaction produces the active biocide. The methods can also include deactivating the active biocide via a chemical reaction between the active biocide and a deactivating agent.

Abstract: A method of cleaning a wellbore prior to the production of oil or gas, wherein the wellbore has been drilled with an invert emulsion drilling mud that forms an invert emulsion filter cake is disclosed. The method may include circulating a breaker fluid into the wellbore, where the breaker fluid includes a non-oleaginous internal phase and an oleaginous external phase, where the non-oleaginous phase includes a water soluble polar organic solvent, a hydrolysable ester of a carboxylic acid, and a weighting agent, and the oleaginous external phase includes an oleaginous fluid and an emulsifier, and where the hydrolysable ester is selected so that upon hydrolysis an organic acid is released and the invert emulsion of the filter cake breaks.

Abstract: A gelled organic-based fluid system and method of forming and using the system. The fluid system is prepared by gelling an organic solvent, a viscoelastic surfactant, and a nitrogen compound having a free electron pair such as urea in an amount effective to both increase viscosity and increase a rate of breaking the viscosity, relative to the gelled system without the nitrogen compound. In a further aspect, the method is used to treat a well penetrating a subterranean formation, for example, in a coiled tubing cleanout, or the like.

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: A fluid comprising a plurality of particulates having an Apollonian particle size distribution dispersed in a carrier fluid optionally comprising a surfactant, the particulates, the carrier fluid, or both comprising a degradable oleaginous fluid. Methods to utilize the fluid are also disclosed.