Abstract: Injection fluid tuning is provided. In one possible implementation, injection fluid can be tuned by accessing both surface properties of rock found in a hydrocarbon reservoir of interest and a chemical composition of oil found in the reservoir of interest. An ion effect on wettability of a contact surface of the rock can be acquired and then used to formulate a tuned ion solution based on the ion effect on wettability of the contact surface of the rock. In another possible implementation, an electrolyte solution has an ionic composition and an ionic concentration configured to enhance recovery of oil from a reservoir. The electrolyte solution includes a content of direct contact ions including monovalent ions with a static polarizability larger than a preset limit sufficient to influence a contact surface of a rock in the reservoir to reach a desired wettability.

Abstract: Surfactant compositions useful for oil recovery are disclosed. The compositions comprise from 10 to 80 wt. % of a propoxylated C12-C20 alcohol sulfate, from 10 to 80 wt. % of a C12-C20 internal olefin sulfonate, and from 0.1 to 10 wt. % of an ethoxylated C4-C12 alcohol sulfate. Surprisingly, including a minor proportion of the ethoxylated alcohol sulfate reduces or eliminates the need to rely on costly cosolvents for achieving good performance in enhanced oil recovery processes. In particular, low interfacial tensions and low microemulsion viscosities can be achieved when the ethoxylated alcohol sulfate accompanies the propoxylated alcohol sulfate and internal olefin sulfonate. Aqueous concentrates comprising water and the surfactant compositions described above are also disclosed. Dilution of the surfactant composition or aqueous concentrate with water or brine to the desired anionic actives level provides an injectable composition useful for EOR applications.

Abstract: A composition comprising an alcohol ether sulfonate and a quaternary ammonium salt is provided for use in methods of increasing recovery of crude oil from a subterranean hydrocarbon-containing formation.

Abstract: A method of servicing a well is disclosed. The method comprises mixing ingredients to form a well servicing fluid. The ingredients comprise (i) at least one surfactant chosen from alcohol ethoxylates, C4 to C12 primary alcohols and ethoxylated propoxylated alcohols, (ii) a zwitterionic polymer prepared by inverse emulsion polymerization of at least one monomer Ab comprising a betaine group and optionally one or more nonionic monomers Ba, and (iii) a saline based aqueous solution. The well servicing fluid is introduced into a hydrocarbon well.

Abstract: Recover petroleum from a subterranean formulation by injecting an aqueous solution comprising a polyethylene oxide nonionic surfactants and a disulfonated anionic surfactant.

Abstract: Additional oil recovery is obtained from a reservoir with a composition comprising at least a coupling solvent typically employed in waterborne coating compositions. Embodiments include recovering hydrocarbons using at least one coupling solvent, such as an oxygenated coupling solvent. The coupling solvent increases the mutual solubility with water at the injection temperature to facilitate the mixing and injection, particularly with an optional co-solvent. The coupling solvent helps mitigate formation plugging and improve performance when injected into a formation, as the solvent mixture moves from being miscible in the injection field water to being miscible in the reservoir oil, mobilizing the reservoir oil to increase oil recovery.

Abstract: An oil recovery method by the modification of the rock wettability from hydrophilic to oleophilic using hydrophobic compounds. Specifically, the method relates to the application of oil-type emulsions in water based on hydrophobic compounds free of silicon and fluorine to increase the oil recovery in mature sandstone-type reservoirs after the injection of water.

Abstract: A method of producing fluid from a formation containing hydrocarbons in which an aqueous polymer preflush fluid is injected into the formation followed by injection of an aqueous polymer displacement fluid, where the aqueous polymer preflush fluid has a total dissolved solids content that is greater than the total dissolved solids content of the aqueous polymer displacement fluid.

Abstract: Methods and compositions comprising an emulsion or a microemulsion for use in various aspects of the life cycle of an oil and/or gas well are provided. In some embodiments, the emulsion or the microemulsion comprises an aqueous phase, a non-aqueous phase comprising a terpene alcohol a non-oxygenated terpene, and a surfactant, and optionally, one or more additives.

Abstract: An oil recovery composition of an aqueous solution of one or more salts and dilute polymer and processes for enhanced oil recovery using the oil recovery composition are provided. An oil recovery composition may include an aqueous solution of one or more salts having a salinity of about 5000 parts-per-million (ppm) to about 6000 ppm and a polymer having a concentration of 250 ppm to 500 ppm. The one or more salts may include at least one of sodium chloride (NaCl), calcium chloride (CaCl2), magnesium chloride (MgCl2), sodium sulfate (Na2SO4) and magnesium sulfate (MgSO4). The polymer may include a copolymer of acrylamide and acrylamido tertiary butyl sulfonate (ATBS). The oil recovery compositions provided may be suited for enhancing oil recovery in carbonate reservoirs having in situ oil viscosities less than 3 centipoise (cP).

Abstract: The present invention relates to well drilling field in the petroleum industry, particularly to accelerator used for drilling fluids, water-based drilling fluid and usage thereof. The accelerator contains: sulfonated polyglycerol long-chain fatty acid ester, fatty alcohol polyoxyethylene ether, alcohol ether carboxylate, glycidyl ether, and polyoxyethylene alkylphenol ether; wherein, the weight ratio of the sulfonated polyglycerol long-chain fatty acid ester:the fatty alcohol polyoxyethylene ether:the alcohol ether carboxylate:the glycidyl ether:the polyoxyethylene alkylphenol ether is 100:1-10:0.5-10:1-10:1-10. The accelerator provided in the present invention can lubricate the drill bit and drilling tool, prevent accumulation of drill cuttings, reduce friction, and improve rate of penetrate.

Abstract: Gas and condensate productivities from a hydrocarbon reservoir can be enhanced using a chemical treatment composition. The chemical treatment composition includes a solvent mixture and a wettability alteration chemical. The solvent mixture includes a solvent that is operable to increase the relative permeability of gas within the hydrocarbon reservoir and the wettability alteration chemical is operable to alter the wettability of surfaces of the hydrocarbon reservoir, in each case enhancing the gas and condensate productivities from the hydrocarbon reservoir. The solvent mixture is selected to provide a chemical treatment composition with a flash point of at least 40° C. (104° F.).

Abstract: A method of preventing formation of a water and oil emulsion in a downhole formation containing oil, the method comprises preparing a dispersion of water and a plurality of nanoparticles, each nanoparticle in the plurality of nanoparticles having a size of at least 300 nanometers, and injecting the mixture downhole into contact with the oil downhole. Presence of the plurality of nanoparticles prevents formation of an emulsion between the injected water and the oil.

Abstract: A method of treating a subsurface formation with low permeability to increase total oil production from the formation is disclosed. The method may include providing a first fluid into two or more fractures emanating from a first wellbore. The first fluid may form additional fractures in the formation. The first fluid may also increase a minimum horizontal stress in zones substantially surrounding the fractures emanating from the first wellbore and the additional fractures formed. A zone having a lower minimum horizontal stress may be located between these zones. Additional fractures may be formed from a second wellbore in the formation with at least one of the additional fractures emanating from the second wellbore and propagating into the lower minimum horizontal stress zone. Hydrocarbons may be produced from the first wellbore and/or the second wellbore. A second fluid may be provided into the first wellbore after producing the hydrocarbons from the first wellbore.

Abstract: A flooding fluid for use in petroleum recovery from a petroleum-bearing formation is prepared by mixing an oxygen scavenger consisting essentially of an alkaline aqueous solution of at least one water-soluble borohydride with an aqueous or nonaqueous input fluid having oxygen dissolved therein to reduce the level of dissolved oxygen.

Abstract: A computer-implemented method for determining one or more operating modes for a crude oil displacement system is provided. The crude oil displacement system is arranged to inject an aqueous displacement fluid into one or more reservoirs, each reservoir comprising a porous and permeable rock formation, wherein crude oil and formation water are contained within a pore space of the rock formation. The crude oil displacement system is for use in displacing crude oil from the pore space of the rock formation. The computer-implemented method comprises the steps of receiving measurement data associated with one or more chemical characteristics of the displacement fluid and one or more chemical characteristics of the rock formation, the crude oil and the formation water of the one or more reservoirs, and inputting the measurement data and data representing a predetermined volume of oil into a computer-implemented predictive model.

Abstract: Stable water based High-Temperature-High-Pressure (HTHP) and/or Non-HTHP crosslinked copolymers for oil and gas applications consist of (i) a crosslinked, linear polyvinyl amide/polymerizable carboxylic acid) copolymer, having a composition, by weight, of 25-75 wt. % of a vinyl amide monomer selected from vinyl pyrrolidone, vinyl caprolactam, N-vinyl-N-methylacetamide and mixtures thereof, and 25-75 wt. % of a polymerizable carboxylic acid monomer selected from acrylic acid, (meth)acrylic acid, crotonic acid, itaconic acid, maleic acid and mixture thereof; and (ii) a crosslinker in an amount of 0.01-5% based on weight of total monomers. Also discloses relevant compositions comprising said copolymer and method of use thereof.

Abstract: An aqueous slurry composition for use in industries such as petroleum and pipeline industries comprises an aqueous liquid, particulates, a hydrophobizing agent that renders the particulate surface hydrophobic and a hydrophobic polymer. The slurry is produced by rendering the surface of the particulate hydrophobic during or prior to making the slurry. The method and composition can find many applications in different industries, particularly in petroleum industry.

Abstract: The invention belongs to the field of oilfield chemistry and specifically relates to a zirconium gel particle combination flooding system. The zirconium gel particle combination flooding system comprises multi-scale 1 zirconium gel particles, polyether nonionic surfactant, and water as mixing liquid; the weight percentage of multi-scale zirconium gel particles in the combination flooding system ranges from 0.16% to 0.24%; the weight percentage of polyether nonionic surfactant in the combination flooding system ranges from 0.1% to 0.4%; the rest is water, and the sum of the weight percentage of the each component is 100%.

Abstract: The present invention relates to a composition comprising a lignin polyol, a method for the manufacturing of said composition and use thereof in different application areas, such as in adhesives, binders, castings, foams (such as in rigid polyurethane and polyisocyanurate foams for thermal insulation and construction applications, semi-rigid, flexible, moulded, laminated, microcellular and viscoelastic polyurethane foams), fillers, glues, sealants, elastomers and rubbers. The present invention also relates to a method for the manufacturing of a foam and use of this foam.

Abstract: An emulsion includes at least one polymeric surfactant, water and at least one organophosphorous compound. The emulsion may include from about 1% to about 40% of the polymeric surfactant and from about 40% to about 80% of the organophosphorous compound. The emulsion may further include at least one salt or additional surfactant. The at least one polymeric surfactant may include silicone-based surfactants, polyoxypropylene-based surfactants, graft copolymers of polysaccharides, and combinations thereof. The at least one polymeric surfactant may account for about 25% to about 100% by weight of the surfactant content in the emulsion and the at least one secondary surfactant, if present, may account for up to about 75% by weight of the surfactant content in the emulsion. The emulsion may have an average dispersed phase drop size of less than about 5 micron, or less than about 1 micron, after 6 months.

Abstract: Provided herein are, inter alia, compositions including a surfactant and a phenol-alkoxylate co-solvent useful in enhanced oil recovery. The compositions and methods provided herein are particularly useful for oil recovery under a broad range of reservoir conditions (e.g. high to low temperatures, high to low salinity, highly viscous oils).

Abstract: Provided herein are, inter alia, compositions including a surfactant and a phenol-alkoxylate co-solvent useful in enhanced oil recovery. The compositions and methods provided herein are particularly useful for oil recovery under a broad range of reservoir conditions (e.g. high to low temperatures, high to low salinity, highly viscous oils).

Abstract: A method of hydraulically fracturing a subterranean formation penetrated by a wellbore comprises: providing a diverting fluid comprising a carrier fluid, a first superabsorbent polymer and a second superabsorbent polymer, the second superabsorbent polymer having a shape, or a composition, or a combination thereof different from that of the first superabsorbent polymer; injecting the diverting fluid into the subterranean formation; and injecting a fracturing fluid into the formation after injecting the diverting fluid. A viscosity modifying agent can be present in the diverting fluid. Superabsorbent polymers can also be used to develop a temporary filter cake at the formation face to reduce or eliminate the fluid leakoff out of the wellbore.

Abstract: Oil sands may be surface mined and transported to a treatment area or may be treated directly by means of an in situ process of oil sand deposits that are located too deep for strip mining. A bitumen recovery process may be used to extract bitumen from oil sands. Specifically, the bitumen recover process involves a step of treating oil sands with a propylene oxide capped glycol ether described by the structure: RO—(C2H4O)n—CH2CH(CH3)OH wherein R is a linear, branched, or cyclic alkyl, phenyl, alkyl phenyl group and n is 1 to 10.

Abstract: A method of preventing formation of a water and oil emulsion in a downhole formation containing oil, the method comprises preparing a dispersion of water and a plurality of non-functionalized nanoparticles, each nanoparticle in the plurality of nanoparticles having a size of at least 300 nanometers, and injecting the dispersion into contact with the oil downhole. Presence of the plurality of nanoparticles prevents formation of an emulsion between the injected water and the oil.

Abstract: A method for simulating fluid flows in a petroleum reservoir to improve final oil recovery. The fluid comprises water, hydrocarbon, and surfactant components. The method comprises a flash step for calculating compositions via two stages. A first stage comprises a first flash to determine first compositions of the water, oil and gas phases and is performed by omitting the surfactant component in the fluid. A second stage comprises a second flash to determine a microemulsion composition of the microemulsion phase.

Abstract: Various embodiments disclosed relate to compositions including a viscosifier polymer and a polyamine viscosity modifier and methods of using the same for treatment of subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in a subterranean formation a composition including a viscosifier polymer and a polyamine viscosity modifier.

Abstract: An oil recovery composition of an aqueous solution of one or more salts and dilute polymer and processes for enhanced oil recovery using the oil recovery composition are provided. An oil recovery composition may include an aqueous solution of one or more salts having a salinity of about 5000 parts-per-million (ppm) to about 6000 ppm and a polymer having a concentration of 250 ppm to 500 ppm. The one or more salts may include at least one of sodium chloride (NaCl), calcium chloride (CaCl2), magnesium chloride (MgCl2), sodium sulfate (Na2SO4) and magnesium sulfate (MgSO4). The polymer may include a copolymer of acrylamide and acrylamido tertiary butyl sulfonate (ATBS). The oil recovery compositions provided may be suited for enhancing oil recovery in carbonate reservoirs having in situ oil viscosities less than 3 centipoise (cP).

Abstract: Provided herein are inter alia non-surfactant aqueous compositions and methods having application in the field of enhanced oil recovery. In particular, non-surfactant compositions including light co-solvents and an alkali agent presented herein can be used, inter alia, for the recovery of a large range of crude oil compositions from challenging reservoirs.

Abstract: The present invention relates to a method for thickening a hydrophobic liquid. When a hydrophobic liquid is thickened in accordance with the invention, the liquid becomes significantly denser. Preferably, the hydrophobic liquid becomes a gel.

Abstract: Methods for extracting oil from a multiphasic liquid are provided. The method can comprise: introducing the multiphasic liquid to a plurality of nanoparticles, and allowing oil in the multiphasic liquid to be adsorbed by the polymeric shell. The nanoparticles comprise a core and a polymeric shell. The method can further comprise removing the nanoparticles from the multiphasic liquid, and/or recovering the oil adsorbed by the polymeric shell after removing the nanoparticles from the multiphasic liquid. The multiphasic liquid can comprise oil and water (e.g., oil and sea water, such as sea water in an area of an oil spill), stomach fluid and a food-grade oil (e.g., olive oil, vegetable oil, canola oil, or a mixture thereof), or other multiphasic liquids having an oil component.

Abstract: Herein are provided tools and processes for extracting oil from subterranean formation. The processes can include lightening the oil in the formation prior to extraction by the addition of a nanogas solution. The tools include injectors for the formation of the nanogas solution within the subterranean formation.

Abstract: A method for increasing production in a liquid hydrocarbon reservoir formation comprising the steps of introducing a nanoencapsulated composition solution capable of reducing the surface tension of a liquid hydrocarbon fraction, where the nanoencapsulated composition solution comprises a nanocapsule and a carrier fluid, such that the nanocapsule is dispersed in the carrier fluid; allowing the nanoencapsulated composition solution to interact with the liquid hydrocarbon fraction such that the surface tension of the liquid hydrocarbon fraction is reduced such that at least a portion of the liquid hydrocarbon fraction is capable of being displaced; introducing a water fraction into the wellbore under conditions such that at least a portion of the liquid hydrocarbon fraction is displaced from the liquid hydrocarbon reservoir formation; and recovering the at least a portion of the liquid hydrocarbon fraction and at least a portion of the nanoencapsulated composition solution using the wellbore.

Abstract: Methods including providing a treatment fluid comprising a base fluid, a wettability altering surfactant, and a chelating agent, wherein the treatment fluid has a pH of at least about 5; introducing the treatment fluid into a subterranean formation; altering a wettability of the subterranean formation from oil-wet to either mixed-wet or water-wet with the wettability altering surfactant; and complexing metal ions in the subterranean formation with the chelating agent.

Abstract: Disclosed herein are inversion systems and methods of diluting w/o lattices including about 10 wt % to 80 wt % of a water soluble polymer. Using the inversion systems and methods described herein, dilution of w/o lattices is carried out in a single step to form dilute lattices having 10,000 ppm or less polymer; the dilute lattices form polymer solutions with no further addition of mixing force or water. The solution viscosities of the polymer solutions obtained using the systems and methods of the invention are at least about 80% of solution viscosity expected in the absence of shear.

Abstract: The invention relates to a method of treating a hydrocarbon containing formation, comprising the following steps: a) preparing an internal olefin sulfonate, comprising sulfonating an internal olefin into sulfonated internal olefin followed by contacting sulfonated internal olefin with a base containing solution resulting in the internal olefin sulfonate, wherein sulfonated internal olefin is contacted with the base containing solution in the presence of a non-ionic surfactant, and/or after step a) but before step b), the internal olefin sulfonate and said non-ionic surfactant are combined; b) transporting an aqueous solution comprising the internal olefin sulfonate and the non-ionic surfactant to the location of the hydrocarbon containing formation; c) providing the internal olefin sulfonate and the non-ionic surfactant to at least a portion of the hydrocarbon containing formation; and d) allowing the internal olefin sulfonate and the non-ionic surfactant to interact with the hydrocarbons in the hydrocarbon c

Abstract: Methods for selecting a surfactant for treating a subterranean formation based on the performance of the surfactant and the characteristics of the subterranean formation and the treatment fluids that may be used to treat that formation are provided. In one embodiment, the method may comprise providing a treatment fluid, formation materials, hydrocarbon, and a plurality of surfactants, wherein the hydrocarbon is acquired from a subterranean formation; selecting at least two surfactants from the plurality of surfactants by determining whether each of the plurality of surfactants separates a mixture of the treatment fluid and the hydrocarbon; and selecting at least one surfactant from the at least two surfactants by determining whether the hydrocarbon displaces the treatment fluid from the formation materials in the presence of each of the at least two surfactants.

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

Abstract: The present disclosure provides a surfactant formulation for use in treating and recovering fossil fluid from a subterranean formation. The surfactant formulation includes a primary surfactant, a formulation stability agent and injection water. The surfactant formulation may be injected into one or more injection wells located within the subterranean formation and fossil fluids can then be subsequently recovered from one or more producing wells.

Abstract: A process for the recovery of heavy oil from an underground reservoir, comprising: injecting an oil-in-water nanoemulsion into one or more injection wells; recovering said heavy oil from one or more production wells. Said process is particularly advantageous for enhancing the recovery of heavy oils from underground reservoirs within the range of technologies for tertiary recovery, usually known as “EOR” (Enhanced Oil Recovery”).

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

Abstract: A composition comprising an alcohol ether sulfonate and a quaternary ammonium salt is provided for use in methods of increasing recovery of crude oil from a subterranean hydrocarbon-containing formation.

Abstract: The present disclosure relates generally to a composition comprising a low molecular weight graft polymer. The graft polymer is a graft homopolymer, copolymer or terpolymer. Additionally, the present disclosure relates to a scale inhibitor composition comprising the low molecular weight graft polymer. Furthermore, the present disclosure relates to a process for preventing the deposition of scale from water or aqueous solution and a method for scale inhibition treatment of an oil or gas production well by using the low molecular weight graft polymer. The scale inhibitor is low corrosive for application in the oilfield.

Abstract: The object of the present invention is a composition comprising amine compound and carboxylic acid compounds, wherein at least the amine compounds are alkoxylated, use thereof as a drilling fluid, and a method for using the drilling fluid.

Abstract: Disclosed are spacer fluids and methods of use in subterranean formations. Embodiments may include use of consolidating spacer fluids in displacement of drilling fluids from a well bore annulus.

Abstract: The present disclosure provides methods of using a nonionic surfactant for enhanced oil recovery, where the nonionic surfactant is prepared with a double metal cyanide catalyst. The present disclosure also provides for an emulsion that includes carbon dioxide, a diluent and the nonionic surfactant.

Abstract: Provided herein are inter alia novel compositions and methods having application in the field of enhanced oil recovery. In particular, the short hydrophobe 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, 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: An effective amount of at least one anionic surfactant may be present within a high salinity foamed fluid composition in an effective amount to generate an IFT as low as 10?3 mN/m. The anionic surfactant may be a sulfonate surfactant and/or a sulfate surfactant. The foamed fluid composition may be used to perform an operation, including but not limited to, a gas lift operation, a drilling operation, a completion operation, a stimulation operation, a fracturing operation, an injection operation, an enhanced oil recovery operation, and combinations thereof.