A slurry composition that includes (A) a solvent, (B) a suspension aid, (D) an alkoxylated fatty amine, (E) an active ingredient, and optionally (C) a polar activator. The slurry composition may be formulated with up to 75 wt. % of the active ingredient (E), based on a total weight of the slurry composition, and remain as a pumpable and stable suspension. A concentrated slurry base is also disclosed which includes the solvent (A), the suspension aid (B), the polar activator (C), and the alkoxylated fatty amine (D), all being present at a higher concentration in the concentrated slurry base than a slurry composition made therefrom. A method of treating a subterranean formation is also disclosed, whereby the slurry composition is mixed with an aqueous fluid to form a treatment fluid, and the treatment fluid is introduced through a wellbore penetrating the subterranean formation.

A slurry composition that includes (A) a solvent, (B) a suspension aid, (D) an alkoxylated fatty amine, (E) an active ingredient, and optionally (C) a polar activator. The slurry composition may be formulated with up to 75 wt. % of the active ingredient (E), based on a total weight of the slurry composition, and remain as a pumpable and stable suspension. A concentrated slurry base is also disclosed which includes the solvent (A), the suspension aid (B), the polar activator (C), and the alkoxylated fatty amine (D), all being present at a higher concentration in the concentrated slurry base than a slurry composition made therefrom. A method of treating a subterranean formation is also disclosed, whereby the slurry composition is mixed with an aqueous fluid to form a treatment fluid, and the treatment fluid is introduced through a wellbore penetrating the subterranean formation.

In one embodiment, the present technology provides a surfactant composition comprising an imide compound in an optional solvent for use in a hydrocarbon base fluid to improve the emulsification of an acidizing agent in the hydrocarbon base fluid. In another embodiment, the present technology provides a method of employing an acidizing well-bore stimulation fluid containing the surfactant composition to stimulate a reservoir.

A water-in-oil emulsion having an oil phase (O) and an aqueous phase (A) at an O/A ratio of from about 1:8 to about 10:1; wherein the water-in-oil emulsion includes the oil phase as a continuous phase that includes an inert hydrophobic liquid, and the aqueous phase as a dispersed phase of distinct particles in the oil phase that includes water, a water soluble polymer, and at least one surfactant; wherein the water soluble polymer includes from about 1 to about 60 weight percent of one or more cationic monomers, wherein the amount is by total weight of the water soluble polymer; wherein the water soluble polymer is present in an amount from about 5 to about 40 weight percent of the water-in-oil emulsion; and wherein an aqueous solution prepared by inverting the water-in-oil emulsion by adding it to water has at least comparable viscosity build to an aqueous solution made from a water-in-oil emulsion of the same composition containing 15 weight percent more water soluble polymer. Also provided is a method of treating a portion of a subterranean formation that includes the steps of: (a) providing a water-in-oil emulsion according to the present disclosure; (b) inverting the water-in-oil emulsion by adding it to water at from about 0.1 to about 5 gallons of water-in-oil emulsion per thousand gallons of water to form a friction reducing treatment solution containing from about 0.0005 weight percent to about 0.12 weight percent water soluble polymer based on the weight of the treatment solution; and (c) introducing the treatment solution into the portion of the subterranean formation.

A water-in-oil emulsion having an oil phase (O) and an aqueous phase (A) at an O/A ratio of from about 1:8 to about 10:1; wherein the water-in-oil emulsion includes the oil phase as a continuous phase that includes an inert hydrophobic liquid, and the aqueous phase as a dispersed phase of distinct particles in the oil phase that includes water, a water soluble polymer, and at least one surfactant; wherein the water soluble polymer includes from about 1 to about 60 weight percent of one or more cationic monomers, wherein the amount is by total weight of the water soluble polymer; wherein the water soluble polymer is present in an amount from about 5 to about 40 weight percent of the water-in-oil emulsion; and wherein an aqueous solution prepared by inverting the water-in-oil emulsion by adding it to water has at least comparable viscosity build to an aqueous solution made from a water-in-oil emulsion of the same composition containing 15 weight percent more water soluble polymer. Also provided is a method of treating a portion of a subterranean formation that includes the steps of: (a) providing a water-in-oil emulsion according to the present disclosure; (b) inverting the water-in-oil emulsion by adding it to water at from about 0.1 to about 5 gallons of water-in-oil emulsion per thousand gallons of water to form a friction reducing treatment solution containing from about 0.0005 weight percent to about 0.12 weight percent water soluble polymer based on the weight of the treatment solution; and (c) introducing the treatment solution into the portion of the subterranean formation.

Methods for intensification of oil production with the aim of increasing the oil recovery factor include the sequential treatment of BHZ with an emulsion, limiting water inflows by artificially reducing the permeability of highly permeable intervals of the reservoir, an oil pack, and preventing the interaction of the emulsion with an acid composition, which is injected after. The wettability of reservoir rock in the BHZ is preliminarily determined, and in the case of hydrophilicity of the reservoir rock a direct type of the emulsion with the following composition is used, % mass.: hydrocarbon phase—20-25, emulsifier—3-5, colloidal silicon dioxide nanoparticles—0.5-3, aqueous phase—rest. In the case of hydrophobicity of the reservoir rock in use the invert type of emulsion of the following composition, % mass.: hydrocarbon phase—40-45, emulsifier—3-5, colloidal silicon dioxide nanoparticles—1-3, aqueous phase—rest.

A water-in-oil emulsion, having an oil phase (0) and an aqueous phase (A) at an O/A ratio of from about 1:8 to about 10:1, may include the oil phase as a continuous phase that includes an inert hydrophobic liquid, and the aqueous phase as a dispersed phase of distinct particles in the oil phase that includes water, a water soluble polymer, and at least one surfactant: wherein the water soluble polymer includes from about 1 to about 60 weight percent of one or more cationic monomers, wherein the amount is by total weight of the water soluble polymer; wherein the water soluble polymer is present in an amount from about 5 to about 40 weight percent of the water-in-oil emulsion; and wherein an aqueous solution prepared by inverting the water- in-oil emulsion by adding it to water has at least comparable viscosity build to an aqueous solution made from a water-in-oil emulsion of the same composition containing 15 weight percent more water soluble polymer. Also provided is a method of treating a portion of a subterranean formation that includes the steps of: (a) providing a water-in- oil emulsion according to the present disclosure; (b) inverting the water-in-oil emulsion by adding it to water at from about 0.1 to about 5 gallons of water-in-oil emulsion per thousand gallons of water to form a friction reducing treatment solution containing from about 0.0005 weight percent to about 0.12 weight percent water soluble polymer based on the weight of the treatment solution; and (c) introducing the treatment solution into the portion of the subterranean formation.

A water-in-oil emulsion, having an oil phase (0) and an aqueous phase (A) at an O/A ratio of from about 1:8 to about 10:1, may include the oil phase as a continuous phase that includes an inert hydrophobic liquid, and the aqueous phase as a dispersed phase of distinct particles in the oil phase that includes water, a water soluble polymer, and at least one surfactant: wherein the water soluble polymer includes from about 1 to about 60 weight percent of one or more cationic monomers, wherein the amount is by total weight of the water soluble polymer; wherein the water soluble polymer is present in an amount from about 5 to about 40 weight percent of the water-in-oil emulsion; and wherein an aqueous solution prepared by inverting the water- in-oil emulsion by adding it to water has at least comparable viscosity build to an aqueous solution made from a water-in-oil emulsion of the same composition containing 15 weight percent more water soluble polymer. Also provided is a method of treating a portion of a subterranean formation that includes the steps of: (a) providing a water-in- oil emulsion according to the present disclosure; (b) inverting the water-in-oil emulsion by adding it to water at from about 0.1 to about 5 gallons of water-in-oil emulsion per thousand gallons of water to form a friction reducing treatment solution containing from about 0.0005 weight percent to about 0.12 weight percent water soluble polymer based on the weight of the treatment solution; and (c) introducing the treatment solution into the portion of the subterranean formation.

A water-in-oil emulsion having an oil phase (O) and an aqueous phase (A) at an O/A ratio of from about 1:8 to about 10:1; wherein the water-in-oil emulsion includes the oil phase as a continuous phase that includes an inert hydrophobic liquid, and the aqueous phase as a dispersed phase of distinct particles in the oil phase that includes water, a water soluble polymer, and at least one surfactant; wherein the water soluble polymer includes from about 1 to about 60 weight percent of one or more cationic monomers, wherein the amount is by total weight of the water soluble polymer; wherein the water soluble polymer is present in an amount from about 5 to about 40 weight percent of the water-in-oil emulsion; and wherein an aqueous solution prepared by inverting the water-in-oil emulsion by adding it to water has at least comparable viscosity build to an aqueous solution made from a water-in-oil emulsion of the same composition containing 15 weight percent more water soluble polymer. Also provided is a method of treating a portion of a subterranean formation that includes the steps of: (a) providing a water-in-oil emulsion according to the present disclosure; (b) inverting the water-in-oil emulsion by adding it to water at from about 0.1 to about 5 gallons of water-in-oil emulsion per thousand gallons of water to form a friction reducing treatment solution containing from about 0.0005 weight percent to about 0.12 weight percent water soluble polymer based on the weight of the treatment solution; and (c) introducing the treatment solution into the portion of the subterranean formation.

A water-in-oil emulsion having an oil phase (O) and an aqueous phase (A) at an O/A ratio of from about 1:8 to about 10:1; wherein the water-in-oil emulsion includes the oil phase as a continuous phase that includes an inert hydrophobic liquid, and the aqueous phase as a dispersed phase of distinct particles in the oil phase that includes water, a water soluble polymer, and at least one surfactant; wherein the water soluble polymer includes from about 1 to about 60 weight percent of one or more cationic monomers, wherein the amount is by total weight of the water soluble polymer; wherein the water soluble polymer is present in an amount from about 5 to about 40 weight percent of the water-in-oil emulsion; and wherein an aqueous solution prepared by inverting the water-in-oil emulsion by adding it to water has at least comparable viscosity build to an aqueous solution made from a water-in-oil emulsion of the same composition containing 15 weight percent more water soluble polymer. Also provided is a method of treating a portion of a subterranean formation that includes the steps of: (a) providing a water-in-oil emulsion according to the present disclosure; (b) inverting the water-in-oil emulsion by adding it to water at from about 0.1 to about 5 gallons of water-in-oil emulsion per thousand gallons of water to form a friction reducing treatment solution containing from about 0.0005 weight percent to about 0.12 weight percent water soluble polymer based on the weight of the treatment solution; and (c) introducing the treatment solution into the portion of the subterranean formation.