Abstract: Anti-corrosion metal pretreatment compositions comprising a Group IVB metal, a Group IB metal and polyamidoamine polymers; replenisher compositions for the metal pretreatment compositions; methods of making the metal pretreatment compositions; methods of forming an anti-corrosion Group IVB oxide coating on at least one metal substrate surface by contacting the surface with the metal pretreatment composition; and coated metal substrates having anti-corrosion coatings deposited on the metal substrates from chrome VI free, anti-corrosion metal pretreatment compositions having enhanced corrosion resistance of the Group IVB metal oxide coatings and adhesion of the anti-corrosion and primer coating layers to metal substrates.

Abstract: Methods and systems for processing production fluid include embodiments for removal of injected chemicals from the production fluid. An embodiment of a method includes receiving production fluid from a borehole in an earth formation, the production fluid including surfactants injected into the earth formation to stimulate production of hydrocarbons therefrom. The method also includes processing the production fluid to separate the production fluid into at least an oil phase and produced water, introducing a treatment fluid from a treatment fluid source into at least one of the production fluid and the produced water, and removing the surfactants from at least the produced water. The treatment fluid includes a concentration of multivalent cations, the multivalent cations configured to reduce water solubility of the surfactants.

Abstract: This disclosure relates to anti-agglomerant low dosage hydrate inhibitors that can inhibit the formation of hydrate agglomerants and/or plugs. The anti-agglomerant low dosage hydrate inhibitors may be surfactants. The hydrate inhibitors may be used for inhibiting, retarding, mitigating, reducing, controlling and/or delaying formation of hydrocarbon hydrates, agglomerants of hydrates, and/or plugs. The hydrate inhibitors may be applied to prevent, reduce, and/or mitigate plugging of conduits, pipes, transfer lines, valves, and other places or equipment where hydrocarbon hydrate solids may form. The hydrate inhibitors may be cationic ammonium surfactants having an ionizable secondary amine.

Abstract: Fluid treatment systems and compositions are provided including (a) at least one material including (1) at least one carboxylic acid functional group and (2) at least one sulfur-containing group selected from the group consisting of sulfonyl functional groups, sulfonate functional groups and mixtures thereof; and (b) at least one friction reducing agent selected from the group consisting of guar gums, polyacrylamides, hydratable cellulosic materials, viscoelastic surfactants, and mixtures thereof. The fluid treatment systems and compositions can be used to treat aqueous systems, for example as fracturing fluids for use in fracturing subterranean formations. Methods for inhibiting formation and/or precipitation of metal oxides in an aqueous composition using the fluid treatment systems or compositions also are provided.

Abstract: Fluid treatment systems and compositions are provided including (a) at least one material including (1) at least one carboxylic acid functional group and (2) at least one sulfur-containing group selected from the group consisting of sulfonyl functional groups, sulfonate functional groups and mixtures thereof; and (b) at least one scale control agent. The fluid treatment systems and compositions can be used to treat aqueous systems, for example as fracturing fluids for treating aqueous compositions found in subterranean formations. Methods for inhibiting formation and/or precipitation of calcium salts in an aqueous composition using the fluid treatment systems or compositions also are provided.

Abstract: A water-in-oil type emulsion having a dispersed particle volume fraction of greater than about 60 volume percent, based on the based on the total volume of the emulsion. Methods to produce the emulsion, treatment fluids comprising the emulsion, and uses thereof are also disclosed.

Abstract: The present invention includes the use of anhydride compositions, including alkyl and aryl anhydrides, for use as a demulsifier in resolving emulsions of water and oil. In particular, the anhydride composition can be used alone or in a blend with other demulsifiers. Suitable anhydrides suitable for the present invention include acetic and propionic, with acetic anhydride being preferred. The anhydride composition can be added directly to crude oil or other compositions to be resolved. As such, the demulsifier composition includes an anhydride, such as acetic anhydride, alone or in combination with other demulsifiers. The anhydride can be used in an amount ranging between trace and 100% by weight of the demulsifier composition.

Abstract: Fluid treatment systems and compositions are provided including (a) at least one material including (1) at least one carboxylic acid functional group and (2) at least one sulfur-containing group selected from the group consisting of sulfonyl functional groups, sulfonate functional groups and mixtures thereof; (b) at least one friction reducing agent selected from the group consisting of guar gums, polyacrylamides, hydratable cellulosic materials, viscoelastic surfactants, and mixtures thereof; and (c) at least one scale control agent. The fluid treatment systems and compositions can be used to treat aqueous systems, for example as fracturing fluids for treating aqueous compositions found in subterranean formations. Methods for inhibiting formation and/or precipitation of metal oxides in an aqueous composition using the fluid treatment systems or compositions also are provided.

Abstract: Chemical compounds that are N-lauroyl amino acids containing a polyethylene oxide segment were found to have oil-releasing activity. Solutions containing these compounds may be introduced into oil reservoirs or onto oil-contaminated surface sites to release oil from oil-coated surfaces. The released oil may be recovered for further processing or waste disposal.

Abstract: Fluids viscosified with viscoelastic surfactants (VESs) may have their fluid loss properties improved with the presence of at least one mineral oil slurried together in combination with at least one particulate fluid loss control agent that may be an alkaline earth metal oxides, alkaline earth metal hydroxides, transition metal oxides, transition metal hydroxides, and mixtures thereof. The mineral oil having the particulate fluid loss control agents slurried within it may initially be dispersed oil droplets in an internal, discontinuous phase of the fluid. In one non-limiting embodiment, the slurry is added to the fluid after it has been substantially gelled. The mineral oil/particulate slurry may enhance the ability of a particulate fluid loss control agent to reduce fluid loss. The presence of the mineral oil may also eventually reduce the viscosity of the VES-gelled aqueous fluid.

Abstract: Methods of treating flowback water from a subterranean formation penetrated by a well bore are provided, comprising: (a) providing remediated flowback water having a ferrous iron (Fe+2) ion concentration of less than about 100 milligrams of ferrous iron ion per liter of flowback water, a barium ion (Ba+2) concentration of less than about 500 milligrams of barium ion per liter of flowback water, and a calcium ion (Ca+) concentration of at least about 1,000 milligrams of calcium ion per liter of remediated flowback water; and (b) treating the flowback water with: (i) at least one friction reducing agent; and (ii) at least one scale formation inhibiting agent and/or at least one iron precipitation control agent to provide treated flowback water which can be reused as fracturing fluid in a well drilling operation.

Abstract: Methods of stimulating a well comprising providing a stimulation fluid comprising at least one surfactant and submicron particles, the submicron particles having a particle size between about 200 nm and about 800 nm and a specific surface area greater than about 5 square meters per gram; and introducing the stimulation fluid into a wellbore. Additional methods to enhance oil recovery from subterranean reservoirs accessible via a well are described.

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 well treatment composition is well-designed for the simultaneous enhancement of the production of both liquid and gaseous hydrocarbons from the same reservoir on a non-selective basis. The well treatment composition includes a first surfactant and a second surfactant, wherein the second surfactant is selected from the group consisting of ethoxylated alkylene amines, ethoxylated alkyl amines, propoxylated alkylene amines, propoxylated alkyl amines, ethoxylated-propoxylated alkylene amines and ethoxylated-propoxylated alkyl amines. The well treatment composition also includes a first solvent, a second solvent and water. Methods for using the well treatment composition include the steps of emplacing the well treatment composition into wells having high and low gas-to-oil ratios.

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.

Abstract: The invention relates to the use of compounds comprising three hydrophobic groups as additives to a stream of crude oil containing carboxylic acids, in particular naphthenic acids, and salt water, to prevent the formation of calcium carboxylates when the fluid is exposed to shear forces. Preferably, the compounds are added to a crude oil/water stream containing organic acids Ca2+ ions at a point between the well and the pressure reduction valve in the crude oil receiving station.

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: Disclosed and claimed is a microemulsion flowback aid composition and a method of enhancing recovery of oil or gas during fracturing or stimulation processes. The microemulsion flowback aid composition includes (i) an oil-like phase comprising at least one nonionic surfactant having a hydrophilic-lipophilic balance (HLB) of less than about 9; (ii) a coupling agent capable of stabilizing the microemulsion flowback aid composition; (iii) at least one water-soluble or dispersible nonionic surfactant that is different from the at least one nonionic surfactant in the oil-like phase; (iv) at least one additional surfactant selected from anionic, cationic, amphoteric, and combinations thereof; and (v) water.

Abstract: There is a viscoelastic fluid. The fluid has one or more cationic surfactants selected from the group consisting of certain quaternary salts, certain amines, and combinations thereof; one or more anionic polymers/anionic surfactants; one or more of certain zwitterionic/amphoteric surfactants; and water. There is also a method of fracturing a subterranean formation. The viscoelastic fluid is pumped through a wellbore and into a subterranean formation at a pressure sufficient to fracture the formation. There is also a method for gravel packing a subterranean formation.

Abstract: A composition for providing a stable foam with high tolerance to hydrocarbons includes (a) an aqueous liquid; (b) at least one water soluble or dispersible silicon-containing polyether foamant contained within the aqueous liquid; and (c) a non-aqueous liquid. The aqueous liquid includes water and brine. The non-aqueous liquid includes liquid hydrocarbons.

Abstract: Use of a mixture comprising a surfactant and a cosurfactant in the form of an aqueous solution for flooding underground deposits of hydrocarbons for mobilizing and recovering the hydrocarbons from the underground deposits, the cosurfactant being a substance or a group of substances selected from the following list: an amphiphilic comb polymer having a backbone with two or more side chains attached to the backbone, the side chains differing from one another and/or the side chains differing from the backbone in their amphiphilic character, an amphiphilic polymer having one or more hydrophobic subunits [A2] based on a polyisobutene block, at least 50 mol % of whose polyisobutene macromolecules have terminally arranged double bonds, and one or more hydrophilic subunits [B2], or an amphiphilic polymer having the general structural formula

Abstract: A method for replacing glycol-based mutual solvents in an oil field application comprising: obtaining an alternative solvent and solvent blends and replacing all or a portion a glycol-based mutual solvent, which forms a component of an oil field formulation, with the alternative solvent or solvent blends, wherein the oil field formulation can be utilized in an oil field application.

Abstract: Guard bed compositions for protecting metal surfaces in a wellbore from corrosion may comprise a variety of constituent components. Exemplary guard bed compositions may include: one or more surfactants selected from the group comprising amine surfactants; one or more co-surfactants selected from the group comprising C3 to C15 alcohols; and one or more non-surfactant amines. Other exemplary guard bed compositions may comprise: a hydrocarbon fluid and an overbased detergent. Still other exemplary guard bed compositions may comprise: a hydrocarbon fluid; one or more surfactants; one or more co-surfactants; and one or more non-surfactant amines. The one or more surfactants may be selected from the group comprising alkyl alkoxylated surfactants. Still further, exemplary guard bed compositions may comprise: a hydrocarbon fluid and one or more associating surface active polymers selected from the group comprising amphiphilic polymers.

Abstract: Chemical compounds that are N-lauroyl amino acids containing a polyethylene oxide segment were found to have oil-releasing activity. Solutions containing these compounds may be introduced into oil reservoirs or onto oil-contaminated surface sites to release oil from oil-coated surfaces. The released oil may be recovered for further processing or waste disposal.

Abstract: The process for making amphoteric surfactants derived from ether amine s is described. The ether amines may be derived from natural products such as animal, marine or vegetable oils or from petroleum derived raw materials. The application of these amphoteric surfactants to the recovery of residual oil by Enhanced Oil Recovery methods is disclosed.

Abstract: A method of servicing a wellbore comprising placing a composition comprising a microemulsion surfactant and a completion fluid into a wellbore, wherein the composition is substantially free of an organic solvent. A method of servicing a wellbore having a permeable zone comprising introducing a composition comprising a brine and a microemulsion surfactant to the wellbore proximate to the permeable zone wherein at least a portion of the composition enters the permeable zone and wherein the composition excludes an organic solvent. A wellbore servicing fluid comprising a microemulsion surfactant and a completion fluid.

Abstract: The invention relates to the use of salts of compound of the formula (1) and amines of the formula (2), where R1 means C8- to C30-Alkyl or C8- to C30-Alkenyl, R2 means hydrogen or a group of the formula -(A-O)x—H, R3, R4 mean hydrogen, C1- to C4-Alkyl or a group of the formula -(A-O)x—H, A means C2- to C4-Alkylene, and x means a number from 1 to 10, as water-soluble or water-dispersible corrosion inhibitors.

Abstract: A low toxicity composition and method of reducing the swelling of clay in well comprising circulating in the well a water-based fluid comprising a functionally effective concentration of the additive formed from the following reaction of a tertiary amine of the following general formula: wherein R1 and R2 are alkyl or hydroxyalkyl groups with one to three carbon atoms or combinations thereof, and R3 is a hydroxyalkyl group with one to three carbon atoms, with an alkylating agent of the following general formula: R-A wherein R is an alkyl radical with one to three carbon atoms, and A is an organic or inorganic anion selected from the group consisting of sulfate, phosphate, carbonate, and combinations thereof.

Abstract: A composition for isolating a zone in a wellbore comprising: an aqueous liquid hydrophobic solid particles, and an oil.

Abstract: Disclosed herein is a method comprising displacing a first oil-based fluid present in an open hole interval of a wellbore with a second fluid; and contacting the second fluid with an acidic indigenous formation fluid to produce a third fluid wherein the second fluid an aqueous fluid dispersed as a discontinuous phase within an oleaginous fluid, and an amine surfactant, wherein the amine surfactant is selected such that contacting the second fluid with indigenous fluid protonates at least a portion of the amine surfactant in the second fluid to produce the third fluid comprising an emulsion comprising the oleaginous fluid reversibly dispersed as a discontinuous phase within the aqueous fluid. A system for treating a subterranean well and a fluid are also disclosed.

Abstract: The present invention relates to a method of using threshold scale inhibitors of the formula: wherein n is 2 or 3 and M is hydrogen or an alkali metal cation, for preventing calcium carbonate, iron carbonate, and calcium sulfate scale formation in oilwell brines containing dissolved iron.

Abstract: An oil-in-water emulsion that includes a brine continuous phase; and an oleaginous discontinuous phase stabilized by an emulsifier blend, the emulsifier blend comprising: an emulsifier having an HLB greater than 11; and an amphoteric chemotrope is disclosed. Emulsifier blends comprising an emulsifier having an HLB greater than 11 and an amphoteric chemotrope and methods of using emulsifier blends are also disclosed.

Abstract: A sand slurry composition and a method for making sand slurries are disclosed. The sand slurry composition is comprised of sand, an aqueous liquid and a chemical compound that renders the surface sand of hydrophobic. The method is comprised of rendering sand surface hydrophobic during or before making the slurry. This method and composition can find many applications in different industries, especially in various oil field applications.

Abstract: There is a viscoelastic fluid. The fluid has one or more cationic surfactants selected from the group consisting of certain quaternary salts, certain amines, and combinations thereof; one or more anionic polymers/anionic surfactants; one or more of certain zwitterionic/amphoteric surfactants; and water. There is also a method of fracturing a subterranean formation. The viscoelastic fluid is pumped through a wellbore and into a subterranean formation at a pressure sufficient to fracture the formation. There is also a method for gravel packing a subterranean formation.

Abstract: The present invention provides treatment fluids useful for subterranean operations, and more particularly, in at least one aspect, a treatment fluid that comprises a carrier fluid and a cationic surfactant comprising a cationic head group, a polar group attached to the head group, and a hydrophobic group that is either a saturated or unsaturated, branched or straight chain alkyl, and comprises about 6 carbons to about 22 carbons. The treatment fluids of the present invention are at least suitable for use as a remedial treatment for the reduction of existing water blocks, oil blocks, and/or gas condensates.

Abstract: The invention concerns a treatment fluid for wells drilled in oil mud in the form of an emulsion of water in oil comprising: a continuous organic phase comprising at least one emulsion-breaking organo-soluble additive; a dispersed aqueous phase including at least one solid-dissolving agent for the controlled destabilization of the processing fluid; at least one emulsifying agent; at least one weight-increasing agent; the proportion and the nature of the hydrosoluble additive being chosen so as to obtain a delay effect for the destabilization of the emulsion so as to be compatible with the tank fluids. The invention also concerns a method of processing wells bored with oil-based muds, using said processing fluid.

Abstract: Use of a mixture comprising a surfactant and a cosurfactant in the form of an aqueous solution for flooding underground deposits of hydrocarbons for mobilizing and recovering the hydrocarbons from the underground deposits, the cosurfactant being a substance or a group of substances selected from the following list: an amphiphilic comb polymer having a backbone with two or more side chains attached to the backbone, the side chains differing from one another and/or the side chains differing from the backbone in their amphiphilic character, an amphiphilic polymer having one or more hydrophobic subunits [A2] based on a polyisobutene block, at least 50 mol % of whose polyisobutene macromolecules have terminally arranged double bonds, and one or more hydrophilic subunits [B2], or an amphiphilic polymer having the general structural formula

Abstract: The invention relates to gemini surfactants of formula IA wherein A is a core derived from an organic polyhydroxy compound; R1 and R2 are each independently a hydrophobic group; and R3 and R4 are each independently a surfactant head group. Such surfactants can be used as components of fluids used in the petroleum industry or used in formulating cleansing compositions or detergent compositions.

Abstract: The present invention relates to an additive, and its use for inhibiting nucleation, growth and agglomeration of gas hydrates by adding an effective amount of an inhibitor to a multiphasic mixture which tends to hydrate formation and consists of water, gas and optionally condensate, or to a drilling fluid which tends to form gas hydrates. Said inhibitor comprising dialkoxylated quaternary ammonium compounds of the formula 1 where R1, R2 are each independently radicals of the formulae -(A-O)n—(C)—CO—O—R5, R3 is C1- to C30-alkyl or C2- to C30-alkenyl, R4 is an organic radical which optionally contains heteroatoms and has from 1 to 100 carbon atoms, R5 is an alkyl or an alkenyl, n is a number from 1 to 20, A is an alkylene group, B is an alkylene group, C is a C1- to C6-alkylene group and X is an anion, are used as gas hydrate inhibitors.

Abstract: A composition for inhibiting the formation of an emulsion between naphthenic acid and metal ions in a hydrocarbon body, the composition including at least one alkoxylated amine in an amount of up to 30% w/w, at least one acid in an amount of from 2 to 10% w/w and at least one alcohol in an amount of from 30 to 70% w/w. A method for inhibiting the formation of an emulsion between naphthenic acid and metal ions in a hydrocarbon body using such a composition is also proposed.

Abstract: There is a viscoelastic fluid. The fluid has one or more cationic surfactants selected from the group consisting of certain quaternary salts, certain amines, and combinations thereof; one or more anionic polymers/anionic surfactants; one or more of certain zwitterionic/amphoteric surfactants; and water. There is also a method of fracturing a subterranean formation. The viscoelastic fluid is pumped through a wellbore and into a subterranean formation at a pressure sufficient to fracture the formation. There is also a method for gravel packing a subterranean formation.

Abstract: The present invention provides drilling fluids that comprise a base fluid and a water-soluble relative permeability modifier. In addition, the present invention provides methods of reducing the permeability of a subterranean formation to aqueous-based fluids during the drilling phase that comprises providing a water-soluble relative permeability modifier; and placing the water-soluble relative permeability modifier into the subterranean formation during the drilling phase. The present invention provides methods of drilling a well bore in a subterranean formation comprising providing a drilling fluid that comprises a base fluid and a water-soluble relative permeability modifier, and placing the drilling fluid in the subterranean formation. The water-soluble relative permeability modifiers of the present invention generally may comprise hydrophilically modified polymers, hydrophobically modified polymers, or water-soluble polymers without hydrophobic or hydrophilic modification.

Abstract: Methods and compositions useful in inhibiting the formation, growth, and/or maintenance of gas hydrates in a fluid mixture. The gas hydrate inhibitors comprise polyetheramines and acids that are exothermically reacted in situ to produce polyetherammonium compounds.

Abstract: A low toxicity composition and method of reducing the swelling of clay in well comprising circulating in the well a water-based fluid comprising a functionally effective concentration of the additive formed from the following reaction of a tertiary amine of the following general formula: wherein R1 and R2 are alkyl or hydroxyalkyl groups with one to three carbon atoms or combinations thereof, and R3 is a hydroxyalkyl group with one to three carbon atoms, with an alkylating agent of the following general formula: R-A wherein R is an alkyl radical with one to three carbon atoms, and A is an organic or inorganic anion selected from the group consisting of sulfate, phosphate, carbonate, and combinations thereof.

Abstract: A well treatment composition is formed from a fluid mixture of a viscoelastic surfactant and a liquid carrier fluid. The fluid mixture has rheological properties wherein the mixture exhibits shear-thickening behavior when the shear rate is increased from a first shear rate to a second higher shear rate. The fluid mixture may further include a shear activation additive that interacts with the viscoelastic surfactant to facilitate the shear-thickening behavior. The method is accomplished by introducing the fluid mixture into a wellbore formed in a subterranean formation. In certain applications, the fluid mixture may be recycled by bringing the fluid mixture to the surface and reintroducing the fluid into the same or a different wellbore.

Abstract: A method for shortening the shear recovery time of cationic, nonionic, anionic, zwitterionic, and amphoteric viscoelastic surfactant fluid systems by adding an effective amount of an amphiphilic polymeric rheology enhancer. The rheology enhancer is a grafted polymer of polydimethylsiloxane, for example polydimethylsiloxanes grafted with ethylene/propylene glycol. The rheology enhancer also increases fluid viscosity and very low rheology enhancer concentration is needed.

Abstract: An aqueous, viscoelastic fluid gelled with a viscoelastic surfactant (VES) is inhibited against hydrate formation with an effective amount of an additive that could be one or more halide salts of alkali metals and alkali earth metals, formate salts, alcohols, glycols, glycol amines, sugars, sugar alcohols, amidoamine oxides, polymers such as polyamines, polyvinylpyrrolidones and derivatives thereof, polyvinyl alcohols and derivatives thereof, polycaprolactams and derivatives thereof, hydroxyethylcellulose, and mixtures thereof. These fluids are inhibited against hydrate formation and may have increased viscosity as well. The additives may increase viscosity to the point where less VES is required to maintain a given viscosity. These inhibited, aqueous, viscoelastic fluids may be used as treatment fluids for subterranean hydrocarbon formations, such as in stimulation treatments, e.g. hydraulic fracturing fluids.

Abstract: A composition for mitigating or preventing the formation of an emulsion between naphthenic acid and metal cations in a hydrocarbon body, the composition including at least one alkoxylated amine and at least one acid and/or alcohol is disclosed.

Abstract: A powder composition comprising viscoelastic surfactant forms, in aqueous solution, a viscoelastic wellbore treatment fluid.

Abstract: The present invention relates to acidic treatment fluids that comprise an acid fluid and an ester-containing quaternary ammonium compound (“esterquat”) and methods of their use. One embodiment of the present invention provides a method of inhibiting metal corrosion during a subterranean treatment operation comprising using an acidic treatment fluid comprising an acidic fluid and an esterquat. Another embodiment of the present invention provides a method of reducing sludge formation during a subterranean treatment operation formation comprising the step of using an acidic treatment fluid comprising an acidic fluid and an esterquat. Another embodiment of the present invention provides a method of inhibiting the formation of emulsions during a subterranean treatment operation comprising using an acidic treatment fluid comprising an acidic fluid and an esterquat. Another embodiment of the present invention provides an acidic subterranean treatment fluid comprising an acidic fluid and an esterquat.