Abstract: Methods for providing corrosion inhibition in conduits, containers, and wellbores penetrating subterranean formations are provided. In some embodiments, the methods comprise contacting a metal surface with a fluid comprising a corrosion inhibitor additive. In certain embodiments, the corrosion inhibitor additive comprises a compound comprising a hydrophobic cation moiety, one or more lipophilic tails, and a linking moiety.

Abstract: Uses of aryl sulfonium salts for lowering sulfide concentrations and for preventing growth of microbes in a water injection system, a hydrocarbon extraction system, or a hydrocarbon production system are disclosed. Treating oilfield injection and produced fluids containing high levels of microbes with aryl sulfonium salts can significantly decrease the amount of hydrogen sulfide produced, which can be used to measure sulfidogenesis. The treatment can also decrease the number of active microbes in the injection and produced fluids. Thus, these aryl sulfonium salts can be effectively used as inhibitors of hydrogen sulfide generation and as biocides in oilfield fluids.

Abstract: Dual function viscoelastic surfactants (VES) which, when used in a pesticide formulation, are capable of producing a spray pattern between the patterns formed by spraying water and an aqueous pesticide solution containing guar gum as a way to reduce the drifting of the small drops to unintended targets while providing enhanced efficacy to the pesticide.

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.

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: Methods and compositions including a method comprising: providing a treatment fluid comprising an aqueous fluid, a relative permeability modifier, and a chelating agent; introducing the treatment fluid into a well bore that penetrates a subterranean formation; and allowing at least a first portion of the treatment fluid to penetrate into a portion of the subterranean formation so as to substantially divert a second portion of the treatment fluid to another portion of the subterranean formation.

Abstract: Methods are disclosed for improved sand control, fines control, load recovery and well productivity, where the compositions comprise reaction products of an amine and a phosphate-containing compound.

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

Abstract: 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: Nanoemulsions, miniemulsions, microemulsion systems with excess oil or water or both (Winsor III) or single phase microemulsions (Winsor IV) may be formed in situ during hydrocarbon recovery operations after drilling with OBM or SBM using one or more fluid pills. The nanoemulsions, miniemulsions, microemulsion systems with excess oil or water or both or single phase microemulsions remove oil and solids from the well and wellbore surfaces. In one non-limiting embodiment, a single phase microemulsion (SPME) or other in situ-formed fluid may be created from a polar phase, a nonpolar phase, at least one viscosifier, and at least one surfactant.

Abstract: A method for treating a zone of a well with a viscosified fluid is provided, wherein the fluid is adapted to break in the well. The method includes the steps of: (A) introducing a well fluid into the zone of the well, wherein the well fluid includes: (i) a water phase; (ii) a water-soluble polymer in the water-phase; and (iii) a source of a hydroxylamine or salt thereof; and (B) allowing the viscosity of the well fluid to break in the zone.

Abstract: The present invention relates to the use of an oil formulation in the field of the oil industry, in particular for the prevention of water penetration. The formulation according to the invention is in particular intended to be injected into underground formations, such as injection wells or production wells.

Abstract: Coacervate gels having excellent shear viscosities and other properties are made with anionic or cationic polymers, a smaller amount of a surfactant having a charge opposite that of the polymer, and a hydrophobic alcohol and an effective amount of a phosphorus-containing compound sufficient to increase the viscosity of coacervate gels up to 3 times as compared to the gels in the absence of the phosphorus-containing compound. The Zeta Potential of the gel is maintained at an absolute value of at least 20. Optional gel promoting additives include betaines and amine oxides. A preferred gel comprises poly diallyl dimethyl ammonium chloride, a lesser amount of sodium lauryl sulfonate, and lauryl alcohol. The gels are particularly useful in well drilling fluids and well fracturing fluids.

Abstract: The invention is directed to long lasting crosslinked water-soluble swellable polymers, methods for making same, and their uses. More particularly, the invention relates to a composition comprising expandable polymeric particles having cationic sites as well as labile crosslinkers and stable crosslinkers, said particle mixed with a fluid. A particularly important use is as an injection fluid in petroleum production, where the expandable polymeric particles are injected into a target zones in the reservoirs and when the heat and/or a suitable pH in the reservoir cause degradation of the labile crosslinker and when the particle expands, the cationic sites in the polymer adsorb to negative sites of the rock in the formation, thus diverting water to lower permeability regions and improving oil recovery. However, many other uses are possible.

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: Solid, particulate dicarboxylic acids may be fluid loss control agents and/or viscosifying agents for viscoelastic surfactant (VES) fluids in treatments such as well completion or stimulation in hydrocarbon recovery operations. The fluid loss control agents may include, but not be limited to, dodecanedioic acid, undecanedioic acid, decanedioic acid, azelaic acid, suberic acid, and mixtures thereof having a mesh size of from about 20 mesh to about 400 mesh (about 841 to about 38 microns). A mutual solvent or a blend of at least two alcohols subsequently added to the aqueous viscoelastic surfactant treating fluid will at least partially dissolve the solid, particulate dicarboxylic acid fluid loss control agents, and optionally also “break” or reduce the viscosity of the aqueous viscoelastic surfactant treating fluid.

Abstract: Apparatus and methods to prevent the proliferation of undesired life forms in a subterranean formation, comprising forming a fluid comprising an inhibitor; and introducing the inhibitor to a surface in the formation. Apparatus and methods to prevent the proliferation of undesired life forms along a surface of tubular or equipment for use in the oil field services industry, comprising forming a coating comprising an inhibitor; and introducing the coating to a surface of the tubular or equipment. Apparatus and methods to prevent the proliferation of undesired life forms along a surface of tubular or equipment for use in the oil field services industry, comprising forming a material comprising an inhibitor; and embedding the material into a surface of the tubular or equipment.

Abstract: An aqueous fracturing fluid comprises an environmentally friendly flowback aid. The flowback aid includes an amine oxide having the formula (CH3)NO(R1)(R2), where R1 and R2 are independently selected from linear or branched alkyl groups having from 8 to 16 carbon atoms. Optionally, the fracturing fluid may further comprise an alcohol ethoxylate of the formula R3—(OC2H4)x—OH, wherein R3 is a linear or branched alkyl group having from 6 to 18 carbon atoms, and wherein x ranges from 3 to 25. One example of an amine oxide is didecylmethyl amine oxide, and one example of an alcohol ethoxylate is ethoxylated isodecylalcohol (also known as ethoxylated isodecanol). The fracturing fluid is introduced through a well bore into the subterranean formation and pressurized to fracture the subterranean formation. The fracturing fluid is then allowed to flow back into the well bore from the subterranean formation.

Abstract: Alkaline earth metal compounds may be fluid loss control (FLC) agents for viscoelastic surfactant (VES) fluids used for fluid loss control pills, lost circulation material pills and kill pills in hydrocarbon recovery operations. The FLC agents may include, but not be limited to oxides and hydroxides of alkaline earth metal, and in one case magnesium oxide where the particle size of the magnesium oxide is between 1 nanometer to 0.4 millimeter. The FLC agent may alternatively be transition metal oxides and/or transition metal hydroxides. The FLC agent appears to associate with the VES micelles and together form a novel pseudo-filter cake quasi-crosslinked viscous fluid layer that limits further VES fluid flow into the porous media. The FLC agent solid particles may be added along with VES fluids. The pills may also contain internal breakers to reduce the viscosity thereof so that the components of the pill may be recovered.

Abstract: A method for affecting the viscosity of an aqueous fluid gelled with a VES includes providing an aqueous fluid and adding to the aqueous fluid, in any order: at least one VES comprising a non-ionic surfactant, cationic surfactant, amphoteric surfactant or zwitterionic surfactant, or a combination thereof, in an amount sufficient to form a gelled aqueous fluid comprising a plurality of elongated micelles, a glyceride oil comprising a fatty acid, and a plurality of metallic particles to produce a mixture comprising dispersed metallic particles. The method also includes dissolving at least a portion of the metallic particles in the aqueous fluid to provide a compound comprising a metallic base and forming in situ a soap reaction product of the fatty acid with the compound, wherein the soap reaction product is present in an amount effective to increase, decrease, or increase and then decrease a viscosity of the gelled aqueous fluid.

Abstract: Aqueous treating fluids may include a viscoelastic surfactant (VES) and an aqueous base fluid, e.g. a drilling fluid, whereby the VES may increase and/or maintain the viscosity of the aqueous treating fluid. Metal ions may be present within the aqueous treating fluid that break, reduce, and/or digest the VES within the aqueous treating fluid. An effective amount of complexation particles may be added to the aqueous treating fluid for complexing at least a portion of these metal ions and thereby disallowing the metal ions from breaking, reducing, and/or altering the VES within the aqueous treating fluid.

Abstract: Nanoemulsions, miniemulsions, microemulsion systems with excess oil or water or both (Winsor III) or single phase microemulsions (Winsor IV) may be pre-formed and used as one or more fluid pills during hydrocarbon recovery operations after drilling with OBM or SBM. The nanoemulsions, miniemulsions, microemulsion systems with excess oil or water or both or single phase microemulsions remove oil and solids from the well and wellbore surfaces. In one non-limiting embodiment, a single phase microemulsion (SPME) or other pre-formed fluid may be created from a polar phase, a nonpolar phase, an optional viscosifier, and at least one surfactant.

Abstract: Incorporating water-based polymer breakers, such as oxidizers, enzymes and/or acids, into a mixture of an oil and oil-soluble surfactants creates an emulsion that can then perform as a dual-functional breaker for reducing the viscosity of hybrid fluids gelled with both a viscoelastic surfactant (VES) and a polymer. The outer phase of the dual-functional breaker emulsion is oil, e.g. a mineral oil, containing an oil-soluble surfactant that will, over time and with heat, break the VES portion of the gel. As it does so, the polymer breaker in the internal aqueous phase will be released to then break the polymer portion of the gel. The polymer breaker will not start to break the polymer gel before the oil-soluble surfactant starts to break the VES gel. The overall breaking using the emulsion is slower as compared to introducing the polymer breaker and the oil-soluble surfactant in a non-emulsified form.

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: Fluids viscosified with viscoelastic surfactants (VESs) may have their viscosities affected (increased or reduced, e.g. gels broken) by the indirect or direct action of a composition that contains at least one fatty acid that has been affected, modified or reacted with an alkali metal base, an alkali earth metal base, ammonium base, and/or organic base compound, optionally with an alkali metal halide salt, an alkali earth metal halide salt, and/or an ammonium halide salt. The composition containing the resulting saponification product is believed to either act as a co-surfactant with the VES itself to increase viscosity and/or possibly by disaggregating or otherwise affecting the micellar structure of the VES-gelled fluid. In a specific, non-limiting instance, a brine fluid gelled with an amine oxide surfactant may have its viscosity broken with a composition containing naturally-occurring fatty acids in canola oil or corn oil affected with CaOH, MgOH, NaOH and the like.

Abstract: An aqueous, viscoelastic fluid gelled with a viscoelastic surfactant (VES) is stabilized and improved with an effective amount of an alkaline earth metal oxide, alkaline earth metal hydroxide, alkali metal oxides, alkali metal hydroxides, transition metal oxides, transition metal hydroxides, post-transition metal oxides, and post-transition metal hydroxides. These fluids are more stable and have a reduced or no tendency to precipitate, particularly at elevated temperatures. The additives may reduce the amount of VES required to maintain a given viscosity. These stabilized, enhanced, aqueous viscoelastic fluids may be used as treatment fluids for subterranean hydrocarbon formations, such as in hydraulic fracturing. The particle size of the magnesium oxide or other agent may be nanometer scale, which scale may provide unique particle charges that use chemisorption, crosslinking and/or other chemistries to associate and stabilize the VES fluids.

Abstract: Coacervate gels having excellent shear viscosities and other properties are made with anionic or cationic polymers, a smaller amount of a surfactant having a charge opposite that of the polymer, and a hydrophobic alcohol and an effective amount of a phosphorus-containing compound sufficient to increase the viscosity of coacervate gels up to 3 times as compared to the gels in the absence of the phosphorus-containing compound. The Zeta Potential of the gel is maintained at an absolute value of at least 20. Optional gel promoting additives include betaines and amine oxides. A preferred gel comprises poly diallyl dimethyl ammonium chloride, a lesser amount of sodium lauryl sulfonate, and lauryl alcohol. The gels are particularly useful in well drilling fluids and well fracturing fluids.

Abstract: Fluids viscosified with viscoelastic surfactants (VESs) may have their viscosities affected (increased or reduced, e.g. gels broken) by the indirect or direct action of a composition that contains at least one fatty acid that has been affected, modified or reacted with an alkali metal base, an alkali earth metal base, ammonium base, and/or organic base compound, optionally with an alkali metal halide salt, an alkali earth metal halide salt, and/or an ammonium halide salt. The composition containing the resulting saponification product is believed to either act as a co-surfactant with the VES itself to increase viscosity and/or possibly by disaggregating or otherwise affecting the micellar structure of the VES-gelled fluid. In a specific, non-limiting instance, a brine fluid gelled with an amine oxide surfactant may have its viscosity broken with a composition containing naturally-occurring fatty acids in canola oil or corn oil affected with CaOH, MgOH, NaOH and the like.

Abstract: A method of servicing a wellbore comprising placing a composition comprising a surfactant, brine, an oleaginous fluid, and optionally a co-surfactant in an annular space of the wellbore, wherein the composition forms a microemulsion under low shear conditions.

Abstract: This invention relates to fluid compositions used in treating a subterranean formation. In particular, the invention is aqueous wellbore treatment compositions which are foams containing a viscosifying agent, a foam extender, a gas component, and a surfactant, as well as methods of forming such fluids, and uses thereof. The viscosifying agent may be a hydratable polymer, viscoelastic surfactant, or heteropolysaccharide. The foam extender may be a material such as a polyoxyalkyleneamines, ethylenepolyamines, tertiary polyamines, bicarbonate, carbonate, phosphate, or sesquicarbonate.

Abstract: Viscoelastic surfactant (VES) gelled aqueous fluids containing water, a VES, an internal breaker, a VES stabilizer, a fluid loss control agent and a viscosity enhancer are useful as treating fluids and particularly as fracturing fluids for subterranean formations. These VES-based fluids have faster and more complete clean-up than polymer-based fracturing fluids. The use of an internal breaker permits ready removal of the unique VES micelle based pseudo-filter cake with several advantages including reducing the typical VES loading and total fluid volume since more VES fluid stays within the fracture, generating a more optimum fracture geometry for enhanced reservoir productivity, and treating reservoirs with permeability above the present VES limit of approximately 400 md to at least 2000 md.

Abstract: Solid, particulate dicarboxylic acids may be fluid loss control agents and/or viscosifying agents for viscoelastic surfactant (VES) fluids in treatments such as well completion or stimulation in hydrocarbon recovery operations. The fluid loss control agents may include, but not be limited to, dodecanedioic acid, undecanedioic acid, decanedioic acid, azelaic acid, suberic acid, and mixtures thereof having a mesh size of from about 20 mesh to about 400 mesh (about 841 to about 38 microns). A mutual solvent or a blend of at least two alcohols subsequently added to the aqueous viscoelastic surfactant treating fluid will at least partially dissolve the solid, particulate dicarboxylic acid fluid loss control agents, and optionally also “break” or reduce the viscosity of the aqueous viscoelastic surfactant treating fluid.

Abstract: An asphaltene and resin precipitation inhibiting solution formed of an asphaltene and resin precipitation inhibiting compound and a solvent miscible in a carbon dioxide liquid or supercritical fluid. The inhibiting compound includes a head region with an affinity for asphaltene and resin components of a hydrocarbon mixture that is greater than its affinity for water, carbon dioxide, and aliphatic components of the hydrocarbon mixture. The head region includes one or more unsaturated hydrocarbon groups or one or more nonionic dipolar groups. The inhibiting compound also includes a tail region with an affinity for carbon dioxide that is greater than its affinity for substantially all components of the hydrocarbon mixture and water. The tail region includes one or more nonionic quadrupolar groups. An effective amount of solution is added to a hydrocarbon mixture in an underground reservoir when employing a carbon dioxide fluid to flush the hydrocarbon mixture from the reservoir.

Abstract: Alkaline earth metal compounds may be fluid loss control (FLC) agents for viscoelastic surfactant (VES) fluids used for fluid loss control pills, lost circulation material pills and kill pills in hydrocarbon recovery operations. The FLC agents may include, but not be limited to oxides and hydroxides of alkaline earth metal, and in one case magnesium oxide where the particle size of the magnesium oxide is between 1 nanometer to 0.4 millimeter. The FLC agent may alternatively be transition metal oxides and/or transition metal hydroxides. The FLC agent appears to associate with the VES micelles and together form a novel pseudo-filter cake quasi-crosslinked viscous fluid layer that limits further VES fluid flow into the porous media. The FLC agent solid particles may be added along with VES fluids. The pills may also contain internal breakers to reduce the viscosity thereof so that the components of the pill may be recovered.

Abstract: Adding relatively low molecular weight water-soluble friction loss reduction polymers to an aqueous fluid gelled with a viscoelastic surfactant (VES) increases the critical generalized Reynold's number at which the Fanning friction factor increases and friction pressure starts to increase rapidly. The water-soluble polymeric friction loss reduction additives lower surface pumping pressure in VES-gelled fracturing fluids for a given pump rate, thus lowering hydraulic horsepower (HHP) requirements for pumping fluids downhole, e.g. for hydraulic fracturing or frac packing treatments of subterranean formations.

Abstract: In hydrocarbon recovery applications, viscoelastic surfactant (VES) gelled fluids may be preheated to a temperature that will increase viscosity of the VES gelled fluid. The preheated VES gelled fluid retains at least a portion of its preheated viscosity when cooled such as by introduction into a low temperature condition. In an embodiment, the VES gelled fluid may be a drilling fluid, completion fluid, or fracturing fluid, and the low temperature condition may be an offshore operation, an operation in a locality having a cold climate, and/or a shallow oil, gas, or both land-based operation where the formation temperature is 120° F. or less. The surfactant in the VES gelled fluid may be one or more of an amine, amine salt, quaternary ammonium salt, betaine, amidoamine oxide, amine oxide, and combinations thereof.

Abstract: The present invention relates to the preparation of foaming formulations for high temperature, salinity and concentration of divalent ions, such as Calcium and Magnesium, that apply the synergistic effect of sodium alpha olefin sulfonates and alkyl amido propyl betaines; said inventions may use, as solvent, water, sea water, connate water, alcohols or mixtures all thereof. Said formulations control the piping of gas in reservoirs of the naturally fractured carbonate type.

Abstract: Fluids viscosified with viscoelastic surfactants (VESs) may have their viscosities affected (increased or reduced) by the indirect or direct action of a composition that contains at least one fatty acid that has been affected, modified or reacted with an alkali metal halide salt, an alkaline earth metal halide salt, and/or an ammonium salt and a water soluble base. The composition containing the resulting saponification product is believed to either act as a co-surfactant with the VES itself to increase viscosity and/or possibly by disaggregating or otherwise affecting the micellar structure of the VES-gelled fluid. In a non-limiting instance, a brine fluid gelled with an amine oxide surfactant has its viscosity broken with a composition containing naturally-occurring fatty acids in canola oil reacted with a water soluble base such as NaOH, KOH, NH4OH, and the like with an alkali halide salt such as CaCl2, MgCl2, NaCl, NH4Cl and the like.

Abstract: Many methods are provided including a method comprising: providing a surfactant gel having a first viscosity that comprises an aqueous base fluid and a surfactant; providing an ortho ester breaker; contacting the surfactant gel with the ortho ester breaker; allowing the ortho ester breaker to hydrolyze to produce an acid and an alcohol; and allowing the acid and/or the alcohol to interact with the surfactant gel so as to reduce the first viscosity of the surfactant gel to a second viscosity.

Abstract: The invention is directed to a chemical system of gas evolving oil viscosity diminishing compositions (GEOVDC) for stimulating the productive layer of an oil reservoir, that is to chemical compositions for a thermochemical treatment of an oil reservoir, more specifically for initiating a chemical reaction in the productive layer zone of the oil reservoir to produce heat and evolve gases so that the extraction of oil (petroleum) is improved. The invention is further directed to a method of thermochemically treating an oil reservoir by means of this chemical system, and to an apparatus for performing thermochemical treatment of an oil reservoir.

Abstract: An aqueous composition for treating hydrocarbon wells contains (a) a scale inhibitor and (b) a viscoelastic surfactant, and further contains from 0 to less than 1% by weight of acid selected from the group consisting of hydrochloric acid, sulfuric acid, phosphoric acid, formic acid, acetic acid, citric acid, maleic acid, hydrofluoric acid, and mixtures thereof.

Abstract: An aqueous fluid system that contains an aqueous dicarboxylic acid solution, a viscoelastic surfactant as a gelling agent to increase the viscosity of the fluid, and an internal breaker such as mineral oil and/or fish oil to controllably break the viscosity of the fluid provides a self-diverting acid treatment of subterranean formations. The internal breaker may be at least one mineral oil, a polyalphaolefin oil, a saturated fatty acid, and/or is an unsaturated fatty acid. The VES gelling agent does not yield viscosity until the organic acid starts to spend. Full viscosity yield of the VES gelling agent typically occurs at about 6.0 pH. The internal breaker allows the VES gelling agent to fully viscosify the spent organic acid at 6.0 pH and higher, but as the spent-acid VES gelled fluid reaching reservoir temperature, controllable break of the VES fluid viscosity over time can be achieved.

Abstract: Methods of treating a wellbore comprise displacing a drilling fluid comprising an organophilic clay treated with a quaternary ammonium surfactant having an amide linkage into the wellbore. Methods of drilling a wellbore comprise: applying torque to a bit within the wellbore and concurrently applying force to urge the bit to extend through the wellbore; and circulating a drilling fluid past the bit to remove cuttings therefrom, the drilling fluid comprising an organophilic clay treated with a quaternary ammonium surfactant having an amide linkage. Methods of preparing a drilling fluid comprise: forming an organophilic clay treated with a quaternary ammonium surfactant having an amide linkage; and combining the organophilic clay with an oil-based fluid.

Abstract: A method of servicing a wellbore comprising placing a composition comprising a surfactant, brine, an oleaginous fluid, and optionally a co-surfactant in an annular space of the wellbore, wherein the composition forms a microemulsion under low shear conditions.

Abstract: A method comprising contacting a zwitterionic surfactant, co-surfactant, and water to form a microemulsifier, and contacting the microemulsifier with an oleaginous fluid under low shear conditions to form a microemulsion. A method comprising introducing a first wellbore servicing fluid comprising at least one oleaginous fluid into a wellbore, wherein the first wellbore servicing fluid forms oil-wet solids and/or oil-wet surfaces in the wellbore, and contacting the oil-wet solids and/or oil-wet surfaces in the wellbore with a second wellbore servicing fluid comprising a zwitterionic surfactant, a co-surfactant, and a brine to form a microemulsion.

Abstract: A method for treating solid materials is disclosed, where the treating compositions coats surfaces or portions of surfaces of the solid materials changing an aggregation or agglomeration propensity of the materials. Treated solid materials are also disclosed. The methods and treated materials are ideally suited for oil field applications.

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

Abstract: An aqueous composition for treating hydrocarbon wells contains (a) a scale inhibitor and (b) a viscoelastic surfactant, and further contains from 0 to less than 1% by weight of acid selected from the group consisting of hydrochloric acid, sulfuric acid, phosphoric acid, formic acid, acetic acid, citric acid, maleic acid, hydrofluoric acid, and mixtures thereof.

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 method comprising contacting a zwitterionic surfactant, co-surfactant, and water to form a microemulsifier, and contacting the microemulsifier with an oleaginous fluid under low shear conditions to form a microemulsion. A method comprising introducing a first wellbore servicing fluid comprising at least one oleaginous fluid into a wellbore, wherein the first wellbore servicing fluid forms oil-wet solids and/or oil-wet surfaces in the wellbore, and contacting the oil-wet solids and/or oil-wet surfaces in the wellbore with a second wellbore servicing fluid comprising a zwitterionic surfactant, a co-surfactant, and a brine to form a microemulsion.