Abstract: A method comprises obtaining or providing a treatment fluid comprising an imidazolinium compound and placing the treatment fluid in a subterranean formation. The imidazolinium compound functions as a viscoelastic surfactant (VES) gelling agent and as a corrosion inhibitor.

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 relates to the use of a specific group of alkoxylated and/or acylated non-quaternary nitrogen-containing compounds as anti-agglomerants for gas hydrates. The invention also relates to a method for inhibiting the agglomeration of gas hydrates in a conduit, and compositions comprising the gas hydrate anti-agglomerant, a corrosion inhibitor and/or a paraffin deposition inhibitor.

Abstract: A dual-phase acid-based fracturing composition with corrosion inhibitors and method for use in acid-based matrix and fracturing operations in oil and gas wells is provided. The composition includes an acid, a hydrocarbon, a hydrocarbon-soluble corrosion inhibitor, an acid-soluble corrosion inhibitor, and an acid-soluble inhibitor aid.

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: A method and a thermo-chemical system for removing organic deposits such as wax, asphaltenes and resins in oil well borehole, and oil production and transportation tubing and pathway.

Abstract: Methods of reducing the viscosity of a viscosified treatment fluid; providing a clean-up composition comprising a carboxylic acid; a chlorite-based breaker system comprising an alkali metal compound and an activator wherein the activator comprises a metal and an amine. Placing a viscosified treatment fluid in a subterranean formation via a well bore penetrating the subterranean formation; first contacting the viscosified treatment fluid with the chlorite-based breaker; and then contacting the viscosified treatment fluid with the clean-up composition; and, allowing the viscosity of the viscosified treatment fluid to reduce.

Abstract: The use of free, aromatic acids which contain at least two aromatic ring systems or at least two acid functions, and/or salts thereof, for influencing rock formations in the exploitation of underground mineral oil and/or natural gas deposits is described. The free acids are used in particular for influencing and especially controlling the flow of acid into rock formations in so-called acidizing methods. Suitable salts of said aromatic acids serve for reducing the rock permeability and in particular reducing the inflow of water into the well bore. In addition to this use, corresponding methods are also claimed.

Abstract: Amines or ammonia and amines may be used to enhance recovery of heavy hydrocarbons. The amines or ammonia and amines alone or with water, steam or an oil solvent are combined with the heavy hydrocarbons to promote the transport of the heavy hydrocarbons. The amines or ammonia and amines may be injected downhole or admixed with heavy hydrocarbon containing ore on the surface, optionally with water or steam. Ammonia may be used alone with high quality steam.

Abstract: A well treatment microemulsion for use in a subterranean formation is disclosed, the microemulsion comprises a solvent blend comprising a solvent and a co-solvent; a surfactant blend comprising a surfactant, wherein the surfactant blend is able to give formation intermediate wettability properties; an alcohol; and a carrier fluid; wherein the alcohol, the solvent and surfactant blends are combined with the carrier fluid to produce the well treatment microemulsion. By intermediate wettability it is meant that the water has an advancing contact angle on the surface between 62 and 133 degrees. The associate method of treating a subterranean formation of a well with the microemulsion and the associate method of modifying the wettability of the formation with the microemulsion are also disclosed.

Abstract: Of the many methods presented herein, one method comprises: providing a stabilized emulsion composition formed by combining components that comprise: an oleaginous fluid, a fluid that is at least partially immiscible with the oleaginous fluid, and an emulsion stabilizing agent, wherein the emulsion stabilizing agent comprises a first ionic compound soluble in the oleaginous fluid or the fluid that is at least partially immiscible with the oleaginous fluid, and a second ionic compound with a charge of opposite sign of the first ionic compound and that is at least partially soluble in the opposite fluid as the first ionic compound, and placing the stabilized emulsion composition in a subterranean formation as part of a subterranean application.

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: An aqueous, foamable composition useful for formation fracturing is disclosed, which includes an ionically coupled gel system. These compositions are well suited in fracturing formation where there are insufficient or non-existent hydration units. Methods for making the compositions and methods using the foamable compositions to fracture formation with insufficient hydration units.

Abstract: The invention relates to surfactant based viscoelastic fluids for enhancing the productivity of a hydrocarbon-bearing formations, such as oil wells. The viscoelastic fluids of the invention have particular applicability in acid fracturing of subterranean formations surrounding oil and gas wells. The viscoelastic fluid contains an inorganic acid and at least one C10 to C24 alkyl trialkyl quaternary ammonium aromatic salt such as quaternary ammonium salicylate or phthalate. An anionic surfactant may also be present in the viscoelastic fluid. The addition of the C10 to C24 alkyl trialkyl quaternary ammonium aromatic salt to the inorganic acid causes gellation of the acid.

Abstract: A well treatment microemulsion for use in a subterranean formation is disclosed, the microemulsion comprises a solvent blend comprising a solvent and a co-solvent; a surfactant blend comprising a surfactant, wherein the surfactant blend is able to give formation intermediate wettability properties; an alcohol; and a carrier fluid; wherein the alcohol, the solvent and surfactant blends are combined with the carrier fluid to produce the well treatment microemulsion. By intermediate wettability it is meant that the water has an advancing contact angle on the surface between 62 and 133 degrees. The associate method of treating a subterranean formation of a well with the microemulsion and the associate method of modifying the wettability of the formation with the microemulsion are also disclosed.

Abstract: Invert emulsion compositions including an oleaginous, a non-oleaginous and an amine surfactant that are useful in the oil and gas well drilling art are disclosed. The amine surfactant is selected so that the invert emulsion can be converted form a water-inoil type emulsion to a oil-in-water type emulsion upon the protonation of the amine surfactant. Deprotonation of the amine surfactant reverses the conversion. This solution also permits the conversion of oil-wet solids in the fluid into water-wet solids.

Abstract: An environmentally friendly corrosion inhibiting formulation for the oil-water interface of pipe lines and oil well drilling systems which is prepared pursuant to a process including the steps of reacting an acid selected from the group consisting of a fatty acid anhydride and a 21 carbon dibasic acid with an amine or imidazoline to form a corrosion inhibitor consisting essentially of a fatty acid derivative; dissolving the inhibitor in a fatty acid oil or ester selected from the group consisting of soybean oil or methyl soya ester; adding water dispersing agents consisting of sulfonates and a long chain ethoxylated alcohol; and adjusting the viscosity with an alcohol comprising isopropanol.

Abstract: A method for the enhanced recovery of oil comprises injecting into an oil-containing formation an aqueous surfactant system having at least (1) a blend containing an unmodified Kraft lignin, an oil-soluble amine and a water-soluble sulfonate, and (2) water; driving the surfactant system through the formation and producing the oil mobilized by the surfactant system. A surfactant composition useful for enhanced oil recovery methods is also provided having at least an unmodified Kraft lignin, an oil-soluble amine and a water-soluble sulfonate.

Abstract: A high internal phase ratio water-in-oil emulsion containing an emulsifier comprising a block or graft copolymer the general formula (A-COO).sub.mB or a reaction product of a polyalk(en)yl succinic anhydride and a polar compound having at least one hydroxyl or amino group demonstrates surprisingly low pumping friction pressure losses, high temperature stability and excellent proppant carrying capacity for use as a fracturing fluid in the hydraulic fracturing of subterranean formation.

Abstract: In the removal of particulates from a wellbore, such as in air drilling for hydrocarbon recovery, a mixture of an amphoteric foaming agent and, typically, an anionic surfactant is employed. An aqueous solution thereof having a pH of at least 9.5 is used to generate a foam for removing the particulates; then the foam is collapsed by the introduction of acid to reduce the pH below about 4, the particles are removed mechanically, the pH is restored to greater than 9.5, and the foaming solution is returned to the wellbore. The solution may be used several times; partial losses of foaming agent in the process may be easily replenished with each cycle. Cationic surfactants may be used instead of anionic, with foaming and foam collapse being controlled at opposite pH's. Savings are realized in water, drilling chemicals, and settling pits and the like for removing particulates from the foam.

Abstract: The invention is a foam method for improving conformance during a steam flood or carbon dioxide flood in a subterranean, oil-containing formation penetrated by at least one injection well and at least one production well. In a steam flood oil recovery process, sweep efficiency is improved by injecting steam until steam breakthrough occurs at the production well after which a mixture of steam, a noncondensible gas, and an aqueous surfactant-polypeptide solution is injected into the formation. The aqueous surfactant-polypeptide solution forms a stable foam with the formation oil at formation conditions that reduce the permeability of the highly permeable steam swept zones thereby diverting the steam to other portions of the formation containing unswept oil. The polypeptide is used as a partial substitute for the surfactant to improve the cost of the foam-forming mixture without reducing its effectiveness in increasing sweep efficiency.