Abstract: Invertible latices suitable for use in enhanced oil recovery are formed by adding a first inversion surfactant and a second inversion surfactant to a water-in-oil latex comprising about 15 wt % to 50 wt % of a water soluble polymer having a net ionic charge. The first inversion surfactant has a hydrophilic/lipophilic balance of about 15 to 35 and an ionic charge that is the opposite of the net ionic charge of the polymer. The second inversion surfactant has a hydrophilic/lipophilic balance of between about 8 and 20. The invertible latices are diluted in a single step to provide dilute latices having 10,000 ppm or less polymer solids.

Abstract: Methods and compositions for stimulating of the production of hydrocarbons (e.g., formation crude oil and/or formation gas) from subterranean formations, and methods of selecting a composition for treating an oil or gas well. In some embodiments, the compositions are emulsions or microemulsions, which may include water, a terpene, and a surfactant.

Abstract: Compositions and methods for in situ ground water remediation. The compositions comprise a colloidal biomatrix comprised of sorbent particles, such as zeolites, organoclays and activated carbon, dispersed in aqueous solution that are injectable into the permeable zones of an aquifer to be treated. Once deposited into the permeable zones of the aquifer, the groundwater concentrations of contaminants in those zones are depleted, thus increasing the rate of diffusion of contaminants of the less permeable zones. The compositions and methods of the present invention can be used to treat any organic contaminants and provide rapid remediation of contaminated ground water by adsorption and biodegradation of such contaminants.

Abstract: The present invention relates to highly concentrated, anhydrous amine salts of hydrocarbon polyalkoxy sulfates, wherein the salts are selected from the group of substituted amines, preferably alkanolamines. The products obtained are of low viscosity and pumpable at room temperature. Due to the absence of water, the salts are highly resistant to hydrolysis, even at high temperatures. The invention further relates to the use of the compositions according to the invention in an aqueous dilution for use in oil reservoirs with the aim of achieving enhanced oil production, or for the recovery of hydrocarbons from tar sands or other surfaces or materials provided with hydrocarbon.

Abstract: Aspects of the invention relate to compositions and methods that are used for remediation of near-wellbore damage. A specific aspect is a composition comprising an olefin sulfonate, a sulfosuccinate, and a chemical selected from the group consisting of an alcohol alkoxylated sulfate, an alcohol alkoxylated carboxylate, or a combination thereof.

Abstract: The present invention relates to highly concentrated, anhydrous amine salts of hydrocarbon polyalkoxy sulfates, wherein the salts are selected from the group of substituted amines, preferably alkanolamines. The products obtained are of low viscosity and pumpable at room temperature. Due to the absence of water, the salts are highly resistant to hydrolysis, even at high temperatures. The invention further relates to the use of the compositions according to the invention in an aqueous dilution for use in oil reservoirs with the aim of achieving enhanced oil production, or for the recovery of hydrocarbons from tar sands or other surfaces or materials provided with hydrocarbon.

Abstract: A method of selecting an injectate for recovering liquid hydrocarbons from a reservoir includes designing a plurality of injectates, calculating a net present value of each injectate, and selecting a candidate injectate based on the net present value. For example, the candidate injectate may be selected to maximize the net present value of a waterflooding operation.

Abstract: The invention relates to a temperature-stable hydrogel comprising electrolytic water and a copolymer cross-linked to multivalent metal ions. The invention is characterized in that the copolymer contains at least structural units which are derived at up to 0.005-20% by weight from an ethylenically unsaturated phosphonic acid and alkali metal salts thereof and/or ammonia salts, up to 5-40% by weight from an ethylenically unsaturated sulfuric acid and alkali metal salts thereof and/or ammonia salts and up to 5-94.995% by weight from an amide of an ethylenically unsaturated carboxylic acid selected from the group of acrylamide, methacrylamide and/or C1-C4 alkyl derivatives, wherein the percentages are based on the total mass of the monomers used during copolymerization, and that the multivalent metal ions for cross-linking of the copolymers belong to the groups IIIA, IVB, VB, VIIIB and/or VIIIB of the periodic system of elements.

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: Surfactant compositions useful for oil recovery comprise from 10 to 80 wt. % of a prapoxylated 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. 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. Low interfaoial tensions and low microemulsion viscosities can be achieved when the ethoxylated alcohol sulfate accompanies the propoxytated 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: The present invention relates to a surfactant mixture comprising at least three ionic surfactants which differ in terms of the hydrocarbyl moiety (R1)(R2)—CH—CH2— and are of the general formula (I) where R1, R2, A0, k, X, o, Y, a, b, M are each as defined in the description and the claims. The invention further relates to the use and preparation thereof, and to aqueous surfactant formulations comprising the mixtures, and to processes for producing mineral oil by means of Winsor type III microemulsion flooding, in which the aqueous surfactant formulation is injected into a mineral oil deposit through injection wells and crude oil is withdrawn from the deposit through production wells.

Abstract: The present invention relates to a surfactant mixture comprising at least three ionic surfactants which differ in terms of the hydrocarbyl moiety (R1)(R2)—CH—CH2— and are of the general formula (I) where R1, R2, A0, k, X, o, Y, a, b, M are each as defined in the description and the claims. The invention further relates to the use and preparation thereof, and to aqueous surfactant formulations comprising the mixtures, and to processes for producing mineral oil by means of Winsor type III microemulsion flooding, in which the aqueous surfactant formulation is injected into a mineral oil deposit through injection wells and crude oil is withdrawn from the deposit through production wells.

Abstract: The present invention relates to a surfactant mixture comprising at least three ionic surfactants which differ in terms of the hydrocarbyl moiety (R1)(R2)—CH—CH2— and are of the general formula (I) where R1, R2, A0, k, X, o, Y, a, b, M are each as defined in the description and the claims. The invention further relates to the use and preparation thereof, and to aqueous surfactant formulations comprising the mixtures, and to processes for producing mineral oil by means of Winsor type III microemulsion flooding, in which the aqueous surfactant formulation is injected into a mineral oil deposit through injection wells and crude oil is withdrawn from the deposit through production wells.

Abstract: Methods and compositions for stimulating of the production of hydrocarbons (e.g., formation crude oil and/or formation gas) from subterranean formations, and methods of selecting a composition for treating an oil or gas well. In some embodiments, the compositions are emulsions or microemulsions, which may include water, a terpene, and a surfactant.

Abstract: A system and methodology enables improved quantification of an organic material, e.g. oil, in a sample. The technique comprises adding a substance to a two-phase sample containing the organic material and water. The substance is mixed through the sample until the constituents of the sample are solubilized to create an optically clear mixture. An optical technique is employed with respect to the optically clear mixture to quantitatively analyze the organic material in the sample.

Abstract: The use of a surfactant mixture comprising at least one surfactant having a hydrocarbon radical composed of from 12 to 30 carbon atoms and at least one cosurfactant having a branched hydrocarbon radical composed of from 6 to 11 carbon atoms for tertiary mineral oil extraction.

Abstract: A method for increasing oil production in a carbonate reservoir by incorporating a saline solution injection including a saline soluble surfactant and a saline soluble polymer. The method provides for increased oil production as compared to conventional waterflooding techniques.

Abstract: Amphiphilic macromolecules having repeating structural units: structural units to adjust molecular weight and molecular weight distribution and charging property effects, high stereo-hindrance structural units, and amphiphilic structural units, and are suitable for fields such as oil field well drilling, well cementation, fracturing, oil gathering and transfer, sewage treatment, sludge treatment and papermaking, etc., and can be used as an oil-displacing agent for enhanced oil production, a heavy oil viscosity reducer, a fracturing fluid, a clay stabilizing agent, a sewage treatment agent, a papermaking retention and drainage aid or a reinforcing agent, etc.

Abstract: A two-stage process for mineral oil production from mineral oil deposits with a deposit temperature of more than 70° C. and a salinity of 20 000 ppm to 350 000 ppm, in which an aqueous formulation comprising at least one glucan with a ?-1,3-glycosidically linked main chain, and side groups ?-1,6-glycosidically bonded thereto and having a weight-average molecular weight Mw of 1.5*106 to 25*106 g/mol, are injected into a mineral oil deposit through at least one injection borehole and crude oil is withdrawn from the deposit through at least one production borehole. The aqueous formulation is prepared in two stages, by first preparing an aqueous concentrate of the glucan, and diluting the concentrate on site with water to the use concentration.

Abstract: A combined injection and production method includes establishing a production well and an injection well into a hydrocarbon-bearing formation; introducing a mixture of a surfactant, a co-surfactant and a carrier fluid into each of the production well and the injection well so that the mixture flows into porous media surrounding the production well and the injection well; holding the mixture in the porous media surrounding the production well in the presence of water for a period of time sufficient to form a water film on surfaces of the porous media surrounding the production well; and injecting an injection fluid into the injection well while producing from the production well, whereby hydrocarbons flow from the porous media around the injection well toward the production well.

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: A method for recovering oil from a fractured reservoir having an oil-wettable matrix and comprising at least one injection well and one production well. This method comprises the following steps in such order: a)injecting by an injection well a solution of viscosity-enhancing surfactants, capable of penetrating into the array of fractures, having limited interaction with the matrix, and creating a plug in situ to reduce the perviousness of the fractures and to promote the passage of the solution of step b) into the matrix; b) injecting by an injection well a solution of surfactants, capable of interacting with the matrix to make water-wettable and to extract the oil therefrom; c) injecting by an injection well an aqueous solution to increasing the surface tension, impregnating the matrix and, after the plug in step a) is dissolved by the oil, driving the oil toward the production well.

Abstract: Multi-stage methods for the enhanced recovery of high viscosity oil deposits from low temperature, shallow subterranean formations. The methods may include the steps of heating potentially extractable hydrocarbons, such as high viscosity oil, by injecting a sufficient amount of a heating fluid having a temperature and viscosity sufficiently high to minimize channeling and to permit penetration into regions of the reservoir containing the potentially extractable hydrocarbons. Thereafter, there is injected an extraction fluid that forms a mobile emulsion with the oil, without need for a co-solvent. The extraction fluid may include either a surfactant-polymer formulation or an alkaline-surfactant-polymer formulation. This is followed by injecting a polymer drive medium into the reservoir to displace and drive hydrocarbons and fluids comprising oil to a production well. An aqueous driving medium is then injected into the reservoir to also drive hydrocarbons and fluids comprising oil to a production well.

Abstract: A method for enhancing foam stability in foaming compositions for use in oilfield treatment application, including but not limited to use in mobility control for gas flooding. The method comprises the step of adding to a foaming composition a foam stabilizer of formula (I): wherein R1 is an alkylamido group or a branched or linear alkyl group; R2 and R3 are individually hydrogen or a methyl group; R4, R5 and R6 are individually hydrogen or a hydroxy group, with the proviso that at least one of R4, R5 or R6 is a hydroxyl group; wherein the alkyl group has greater than about 10 carbon atoms. Also disclosed are methods to enhance foam stability in an aqueous foaming composition.

Abstract: A well servicing fluid is formulated by combining ingredients comprising: an aqueous based fluid comprising sulfate ions at a concentration greater than 50 mg/l; a chelating agent; and an acid in an amount sufficient to result in the well servicing fluid having a pH of 4.5 or less. A method of servicing a well is also disclosed.

Abstract: Heavy oil recovery from oil sand reservoirs is enhanced through the creation of subsurface high permeability pathways distributed throughout the oil sand reservoirs. The high permeability pathways may be boreholes that extend through the oil sand reservoir. A portion of the high permeability pathway may be packed with high permeability particulate to provide structural support and allow for high permeability throughout the boreholes. After establishing the high permeability pathways throughout the oil sand reservoir, solvent may be introduced into the oil sand reservoir. The solvent has the beneficial effect of lowering the viscosity of the heavy oil, which aids in the extraction of the heavy oil. Thermal recovery processes and other enhancements may be combined with these methods to aid in reducing the viscosity of the heavy oil. Advantages of these methods include, accelerated hydrocarbon recovery, higher production efficiencies, lower costs, and lower extraction times.

Abstract: A method for altering flow conditions in a porous media containing hydrocarbons includes the steps of preparing a mixture of a surfactant, a co-surfactant and a carrier fluid; transporting the mixture to the porous media; and holding the mixture in the porous media in the presence of water for a period of time sufficient to form a water film on the surfaces of the porous media.

Abstract: A method of analyzing a wellbore fluid that includes treating a wellbore fluid with an emulsifying fluid, the emulsifying fluid comprising: a hydroxylated ether; an amphoteric chemotrope; and testing the treated wellbore fluid for at least one of turbidity and total suspended solids is disclosed. Methods of cleaning wellbores are also disclosed.

Abstract: A process for mineral oil production, in which an aqueous formulation comprising at least one water-soluble, hydrophobically associating copolymer is injected through at least one injection borehole into a mineral oil deposit, and crude oil is withdrawn from the deposit having a deposit temperature of 35° C. to 120° C., preferably 40° C. to 90° C., through at least one production borehole, wherein the water-soluble, hydrophobically associating copolymer comprises at least acrylamide or derivatives thereof, a monoethylenically unsaturated monomer having anionic groups and a monoethylenically unsaturated monomer which can bring about the association of the copolymer.

Abstract: In downhole treatments in the oilfield, ball sealers seated in perforations may not fully seal and may leak fluid through gaps and asperities between the balls and the perforations. A method is given for improving the sealing of ball sealers in perforations by adding a sealing agent that forms a plug in the gaps and severely restricts or eliminates fluid flow. The sealing agent is preferably degradable or soluble, malleable fibers slightly larger than the gaps. Optionally, the particles may be non-degradable, rigid, of different shapes, and smaller than the gaps but able to bridge them. Mixtures of sealing agents may be used. The sealing agent may be added with the ball sealers, after the ball sealers, or both.

Abstract: Embodiments of the present disclosure include compositions for use in enhanced oil recovery, and methods of using the compositions for recovering oil. Compositions of the present disclosure include a nonionic, non-emulsifying surfactant having a CO2-philicity in a range of about 1.5 to about 5.0, carbon dioxide in a liquid phase or supercritical phase, and water, where the nonionic, non-emulsifying surfactant promotes a formation of a stable foam formed of carbon dioxide and water.

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: A process for recovering oil from an oil-bearing formation is provided. A first oil recovery fluid is introduced into a formation through a first well for a first time period and oil is produced from a second well. A second oil recovery fluid different from the first oil recovery fluid is introduced into the formation through the second well for a second time period after the first time period, and oil is produced from a third well, where the second well is located on a fluid flow path extending between the first and third wells.

Abstract: The present invention provides a method for treating a formation containing crude oil hydrocarbons, comprising injecting an aqueous composition comprising an internal olefin sulfonate with a nominal carbon chain length between 24 to 44 into said formation and displacing said crude oil hydrocarbons toward one or more production wells. The invention further provides a method for treating a formation containing crude oil hydrocarbons, a method for improving the wettability of a subsurface surface in an subsurface formation containing crude oil hydrocarbons, and a method for separating crude oil hydrocarbons from crude oil hydrocarbons compositions.

Abstract: The present invention relates to a method for the assisted recovery of crude oil from an underground formation, comprising: a) injecting, via at least one injection means in contact with the underground formation containing the crude oil, a liquid containing a mixture of at least: i) a salty aqueous medium, ii) a mixture of two zwitterionic viscosising surfactants or a mixture of two populations of said surfactants having a bimodal characteristic of the narrow distribution of Ri groups as defined below, in a weight content of between 1 and 0.05 wt %, preferably between 0.5 and 0.1 wt %, and more preferably between 0.4 and 0.15 wt %, such that the liquid has an oil/water interface tension of about 10 mN/m (milinewton per meter) or less as measured at room temperature (25° C.) and a viscosity of about 3 cPs or more as measured at a temperature of 80° C.

Abstract: Systems and methods for transporting seawater from a seawater source to an inland site for utilization as a drilling and/or fracturing fluid are disclosed. In an aspect, systems and methods are disclosed wherein seawater is pumped from an ocean at a coastal location and transported to an inland drilling and hydraulic fracturing site, thereby providing a consistent, large volume supply of seawater for use in drilling and/or hydraulic fracturing operations. Such systems and methods may eliminate usage of locally-sourced fresh water, eliminating the unsustainable burden that drilling and hydraulic fracturing places on local water tables.

Abstract: Method for recovery of hydrocarbon includes: a. injecting mixture of high salinity brine and low salinity brine into the formation, wherein the mixture is injected into the formation through a first pump, wherein the first pump is an automated control pump, at a flow rate based on physical characteristics of the formation, the flow rate of the mixture gradually and continuously decreases, b. injecting fresh water into the formation, wherein the mixture is injected into the formation through a second pump, wherein the second pump is an automated control pump, wherein the fresh water is injected into the formation at a flow rate based on the physical characteristics of the formation, wherein the flow rate gradually and continuously increases; and c. introducing surfactants or polymers into the formation, wherein the surfactant acts as a motive force to drive the hydrocarbons towards one or more production wells.

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 for enhancing recovery of oil from an oil-bearing carbonate formation within a reservoir. The method has the steps of (a) introducing a viscous gel under pressure into the oil-bearing carbonate formation and (b) extracting oil. The aqueous viscous gel has water and an amount of a non-polymeric viscosifying surfactant sufficient to provide the flooding fluid with an oil/water interfacial surface tension of about 10 mN/m or less and a viscosity of about 10 cP or more of the one or more non-polymeric surfactants. The one or more non-polymeric, viscosifying surfactants is selected from the group of one or more cationic surfactants, one or more zwitterionic surfactants, one or more anionic surfactants, one or more amphoteric surfactants, and combinations thereof. In a preferred embodiment, the aqueous viscous gel is also substantially free of solids.

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: A mechanism for pressurized delivery of material into a well without exposure to a high pressure pump. The mechanism may include material delivery equipment that is coupled to the high pressure pump or other pressure inducing equipment through a material carrier that intersects a fluid line from the pump. The material carrier may include chambers that are reciprocated or rotated between positions that are isolated from the fluid line and in communication with the fluid line. While isolated from the fluid line, the chambers may be filled with oilfield material which may then be delivered to the fluid line when positioned in communication therewith. In this manner, a supply of the oilfield material may be retained in a substantially isolated state relative to the pump and components thereof which may be susceptible to damage from exposure to the oilfield material.

Abstract: A method for mobilizing viscous hydrocarbons in a reservoir includes (a) injecting an aqueous solution into the reservoir with the reservoir at the reservoir ambient temperature. The aqueous solution includes water and a water-soluble chemical agent that is substantially non-decomposable and substantially non-reactive in the reservoir at the reservoir ambient temperature. In addition, the method includes (b) adding thermal energy to the reservoir at any time after (a) to increase the temperature of at least a portion of the reservoir to an elevated temperature greater than the ambient temperature of the reservoir. Further, the method includes (c) in response to the elevated temperature in (b), mobilizing at least a portion of the hydrocarbons in the reservoir by reducing the viscosity of the hydrocarbons and allowing the chemical agent to enhance mobilization of the hydrocarbons.

Abstract: A method for recovering viscous hydrocarbons from a reservoir in a subterranean formation includes (a) injecting steam into the reservoir. In addition, the method includes (b) injecting a surfactant into the reservoir with the steam during (a). Further, the method includes (c) decreasing the viscosity of the hydrocarbons in the reservoir with thermal energy from the steam. Still further, the method includes (d) emulsifying the hydrocarbons with the surfactant during (b) and (c). Moreover, the method includes (e) mobilizing at least some of the hydrocarbons in the reservoir.

Abstract: A method for recovering viscous hydrocarbons from a reservoir in a subterranean formation includes (a) injecting steam into the reservoir. In addition, the method includes (b) injecting a thermally activated chemical species into the reservoir with the steam during (a). The thermally activated chemical species decomposes at a temperature between 40° and 200° C. Further, the method includes (c) decreasing the viscosity of the hydrocarbons in the reservoir during (a) and (b). Still further, the method includes (d) mobilizing at least some of the hydrocarbons in the reservoir.

Abstract: A system for and methods of producing hydrocarbons from a formation. A method may include drilling a wellbore in a formation, forming a first fracture in the formation that emanates from the wellbore, forming a second fracture in the formation that emanates from the wellbore and is approximately parallel to the first fracture, and simultaneously (a) injecting a fluid from an injection tubing string in communication with the second fracture and (b) producing hydrocarbons that travel from the first fracture into a production tubing string that is substantially parallel to the injection tubing string. The wellbore may be substantially horizontal. The fluid may increase pressure in an area of the formation adjacent to the first fracture.

Abstract: The present disclosure includes a nonionic surfactant and a method of providing the nonionic surfactant, where the nonionic surfactant is soluble in carbon dioxide and is used as part of a dispersion for enhanced crude oil recovery. The nonionic surfactant can be part of an emulsion that includes carbon dioxide and a diluent.

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

Abstract: Enhanced oil recovery techniques include introduction of alkali metal silicides into subterranean reservoirs to generate hydrogen gas, heat, and alkali metal silicate solutions in situ upon contact with water. The alkali metal silicides, such as sodium silicide, are used to recover hydrocarbons, including heavier crudes where viscosity and low reservoir pressure are limiting factors. Hydrogen, which is miscible with the crude oil and can beneficiate the heavier fractions into lighter fractions naturally or with addition of catalytic materials, is generated in-situ. It. Heat is also generated at the reaction site to reduce viscosity and promote crude beneficiation. The resulting alkaline silicate solution saponifies acidic crude components to form surfactants which emulsify the crude to improve mobility toward a production well. The silicate promotes profile modification passively via consumptive reactions or actively via addition of acidic gelling agents.

Abstract: A process for the enhanced recovery of oil in a deposit introduces into the deposit an alkaline aqueous solution of a water-soluble polymer containing a surfactant. The aqueous solution of water-soluble polymer introduced is prepared with an aqueous solution initially containing Ca2+ and Mg2+ ions treated with an alkaline agent and a dispersant, so as, prior to the introduction of the polymer and the surfactant into the aqueous solution, to precipitate, under the action of the alkaline agent and of CO2 optionally dissolved in the aqueous solution, the Ca2+ and Mg2+ ions. The precipitates are especially in the form of precipitates of calcium carbonate and of magnesium hydroxide and are dispersed owing to the dispersant, which is chosen in order to limit the size of the calcium carbonate and magnesium hydroxide precipitates.

Abstract: Compositions and methods of synthesis of anionic surfactants by alkoxylation of a Guerbet alcohol (GA) having 12 to 36 carbon atoms using butylene oxide, and optionally propylene oxide and/or ethylene oxide followed by the incorporation of a terminal anionic group are described herein. The GA of the present invention is made by a facile and inexpensive method that involves high temperature base catalyzed dimerization of alcohols with 6 to 18 carbon atoms. The large hydrophobe ether surfactants of the present invention find uses in enhanced oil recovery (EOR) applications where it is used for solubilization and mobilization of oil and for environmental cleanup. Further, the hydrophobe alkoxylated GA without anionic terminal group can be used as an ultra-high molecular weight non-ionic surfactant.