Abstract: A method of removing a sulfate scale from a surface is provided. The method includes contacting the sulfate-comprising scale with a conversion solution including 1 to 10 wt. % of an alkali metal carbonate, 0.5 to 10 wt. % of a borate salt or hydrate thereof, and 0.5 to 2.5 wt. % of a base to produce a carbonate-comprising scale. The method further includes exposing the carbonate-comprising scale with an acid solution including 2.5 to 25 wt. % of an acid.

Abstract: A method of removing a sulfate scale from a surface is provided. The method includes contacting the sulfate-comprising scale with a conversion solution including 1 to 10 wt. % of an alkali metal carbonate, 0.5 to 10 wt. % of a borate salt or hydrate thereof, and 0.5 to 2.5 wt. % of a base to produce a carbonate-comprising scale. The method further includes exposing the carbonate-comprising scale with an acid solution including 2.5 to 25 wt. % of an acid.

Abstract: A method of removing a sulfate scale from a surface is provided. The method includes contacting the sulfate-comprising scale with a conversion solution including 1 to 10 wt. % of an alkali metal carbonate, 0.5 to 10 wt. % of a borate salt or hydrate thereof, and 0.5 to 2.5 wt. % of a base to produce a carbonate-comprising scale. The method further includes exposing the carbonate-comprising scale with an acid solution including 2.5 to 25 wt. % of an acid.

Abstract: Ionic liquid containing compositions may be used in the production, recovery and refining of oil and gas. In addition, they may be used to treat cooling water and/or to inhibit and/or prevent corrosion of metals.

Abstract: a method of treating aqueous wellbore fluids, comprising (a) converting one or more multivalent cations in a multivalent cation-containing aqueous fluid to form a mixture comprising one or more insoluble compounds and a treated aqueous fluid, (b) separating the treated aqueous fluid from the one or more insoluble compounds, and (c) contacting the treated aqueous fluid with a sulfide-containing aqueous fluid to form a compatibilized aqueous fluid, wherein the multivalent cation-containing aqueous fluid, the sulfide-containing aqueous fluid, or both were recovered from wellbores prior to (c).

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: 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; (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: Of the many compositions and methods provided herein, one example composition includes a treatment fluid comprising: an aqueous fluid; and a tar stabilizing polymer comprising at least one polymer selected from the group consisting of a styrene polymer, an acrylate polymer, a styrene-acrylate polymer, and any combination thereof.

Abstract: Of the many compositions and methods provided herein, one method includes a method comprising: contacting tar resident in a well bore with a tar stabilizing polymer comprising at least one polymer selected from the group consisting of a styrene polymer, an acrylate polymer, a styrene-acrylate polymer, and any combination thereof; and allowing the tar stabilizing polymer to interact with the tar to at least partially reduce the tendency of the tar to adhere to a surface.

Abstract: A water-based fluid, containing: a non-ionic surfactant, which is stable in a temperature range from 10 to 90° C. and soluble in water; and a salt, wherein the non-ionic surfactant contains an alkyl polyglucoside selected from the group consisting of a C8 alkyl polyglucoside, a C10 alkyl polyglucoside, and mixtures thereof, and the salt is present, and is present in an amount up to 60%. In addition, a process for preventing the formation of a W/O inverse emulsion or resolving a W/O inverse emulsion that has already formed in an oil well in which an oil-based mud has been employed by injecting the water-based fluid into the oil well.

Abstract: A method for delivering a scale treatment agent to a hydrocarbon producing system. The method includes the steps of contacting the system with a foam comprising the scale treatment agent, and shutting the scale treatment agent in the system for at least 0.5 hour.

Abstract: Oil-based wellbore fluid in the form of an emulsion having a continuous phase containing an oil and, dispersed therein, a first dispersed liquid phase and a second separate dispersed liquid phase. The first dispersed liquid phase is a brine phase containing at least 5% by weight of a dissolved salt or a mixture of salts, and the second dispersed liquid phase is a polar organic liquid which is insoluble or sparingly soluble in the brine and contains the first dispersed liquid phase, but is soluble in pure water. The second dispersed liquid phase is in the form of droplets having an average diameter of not less than 5 microns.

Abstract: A method of cleaning a wellbore drilled with a drilling fluid that forms a filter cake that includes emplacing a breaker fluid into the wellbore, the breaker fluid comprising: an aqueous fluid; a fragmentation agent; and an amphoteric chemotrope; and shutting in the well for a period of time sufficient to initiate breaking of the filter cake is disclosed.

Abstract: Viscoelastic compositions are disclosed herein containing an effective amount of one or more random or structurally defined polycationic quaternary ammonium compounds for controlling the viscoelasticity of the composition. In one aspect, the present technology provides polycationic quaternary ammonium compounds that comprise bis-quaternary compound. The bis-quaternary compounds of the present technology can be symmetric or dissymmetric. In another aspect, the present technology provides viscoelastic well bore treatment fluids comprising water, and at least one polycationic quaternary ammonium compound that comprises a bis-quaternary compound. In another aspect, the present technology provides polycationic carboxylates. Preferred viscoelastic compositions of the present technology maintain viscoelasticity at a temperature greater than about 80° C., preferably greater than about 100° C. or 110° C.

Abstract: A method for treating a subterranean formation includes forming a treatment fluid including a carrier fluid, a solid acid-precursor, and a solid scale inhibitor. The solid acid-precursor includes a material that forms an acid at downhole conditions in the subterranean formation. The method further includes adding a solid acid-responsive material into the treatment fluid, where the solid acid-responsive material enhances formation of acid from the solid acid-precursor in acidic conditions. The method includes performing an acid fracture treatment and inhibiting scale formation within the subterranean formation. The solid scale inhibitor allows for long-term scale inhibition after the treatment.

Abstract: A method comprises providing a drilling fluid comprising: an aqueous fluid; and a microemulsion surfactant; and drilling a well bore in a subterranean formation comprising an oleaginous fluid using the drilling fluid, wherein the microemulsion surfactant forms a microemulsion with the oleaginous fluid within the well bore. In accordance with the method, the subterranean formation has a retained producibility greater than about 50%.

Abstract: A method for treating a wellbore tubular or subsurface completion equipment to help remove scale is provided. In general, the method comprises the steps of: (A) determining the likelihood of the presence of carbonate scale in the wellbore tubular or subsurface completion equipment; (B) forming or providing a treatment fluid comprising: (i) water; (ii) a chelating agent capable of forming a heterocyclic ring that contains a metal ion attached to at least two nonmetal ions; and (iii) a viscosity-increasing agent; and (C) introducing the treatment fluid into the wellbore tubular or the subsurface completion equipment.

Abstract: Viscoelastic compositions are disclosed herein containing an effective amount of one or more random or structurally defined polycationic quaternary ammonium compounds for controlling the viscoelasticity of the composition. In at least one aspect, the present technology provides polycationic quaternary ammonium compounds comprising dissymmetric bis-quaternary compounds. In another aspect, the present technology provides viscoelastic compositions comprising polycationic quaternary ammonium compounds that comprise dissymmetric bis-quaternary compounds. In yet another aspect, the present technology provides polycationic quaternary ammonium compounds comprising a carboxylate functional polycationic quaternary ammonium compound. Preferred viscoelastic compositions of the present technology maintain viscoelasticity at a temperature greater than about 80° C., preferably greater than about 100° C. or about 110° C.

Abstract: A method of treating a subterranean formation penetrated by a wellbore of a well having iron-containing components is carried out by introducing a treatment fluid into the wellbore of the well. The treatment fluid is formed from an aqueous solution, a mineral acid, a viscoelastic surfactant gelling agent and corrosion inhibitor system containing at least one of an alkyl, alkenyl, alicyclic or aromatic substituted aliphatic ketone and aliphatic or aromatic aldehyde. The treatment fluid is substantially free of any formic acid or precursor formic acid. In certain embodiments, the corrosion inhibitor system comprises a mixture of at least one of an alkenyl phenone or ?,?-unsaturated aldehyde, an unsaturated ketone or unsaturated aldehyde other than the alkenyl phenone and ?,?-unsaturated aldehyde, a dispersing agent, an extender and an alcohol solvent. A corrosion inhibitor intensifier may also be used in certain embodiments, which may include a mixture of cuprous iodide and cuprous chloride.

Abstract: Viscoelastic compositions are disclosed herein containing an effective amount of one or more random or structurally defined polycationic quaternary ammonium compounds for controlling the viscoelasticity of the composition. In at least one aspect, the present technology provides polycationic quaternary ammonium compounds comprising bis-quaternary compounds. In another aspect, the present technology provides viscoelastic compositions that comprise polycationic quaternary ammonium compounds comprising bis-quaternary compounds. Preferred viscoelastic compositions of the present technology maintain viscoelasticity at a temperature greater than about 80° C., preferably greater than about 100° C. or about 110° C. when the amount of the one or polycationic quaternary compounds is less than about 10% by weight based on the total weight of the composition.

Abstract: Viscoelastic compositions are disclosed herein containing an effective amount of one or more random or structurally defined polycationic quaternary ammonium compounds for controlling the viscoelasticity of the composition. In one aspect, the present technology provides polycationic quaternary ammonium compounds that comprise bis-quaternary compound. The bis-quaternary compounds of the present technology can be symmetric or dissymmetric. In another aspect, the present technology provides viscoelastic well bore treatment fluids comprising water, and at least one polycationic quaternary ammonium compound that comprises a bis-quaternary compound. In another aspect, the present technology provides polycationic carboxylates. Preferred viscoelastic compositions of the present technology maintain viscoelasticity at a temperature greater than about 80° C., preferably greater than about 100° C. or 110° C.

Abstract: Methods for treating wellbores using fluids containing a sphingan heteropolysaccharide which contributes viscosity stability and a decrease in friction pressure. Some methods are clean-out operations using recyclable-viscosity fluids containing at least a sphingan heteropolysaccharide and an optional salt. Others include methods of pumping fluids incorporating sphingan heteropolysaccharides to reduce pumping frictional pressure.

Abstract: Viscoelastic compositions are disclosed herein containing an effective amount of one or more random or structurally defined polycationic quaternary ammonium compounds for controlling the viscoelasticity of the composition. In at least one aspect, the present technology provides polycationic quaternary ammonium compounds comprising dissymmetric bis-quaternary compounds. In another aspect, the present technology provides viscoelastic compositions comprising polycationic quaternary ammonium compounds that comprise dissymmetric bis-quaternary compounds. In yet another aspect, the present technology provides polycationic quaternary ammonium compounds comprising a carboxylate functional polycationic quaternary ammonium compound. Preferred viscoelastic compositions of the present technology maintain viscoelasticity at a temperature greater than about 80° C., preferably greater than about 100° C. or about 110° C.

Abstract: Disclosed is a method for the treatment of hydrogen sulfide. The method preferably includes forming a solvent-surfactant blend, preparing a microemulsion by combining the solvent-surfactant blend with a carrier fluid and contacting the hydrogen sulfide with the microemulsion. In preferred embodiments, the solvent-surfactant blend includes a surfactant and a solvent selected from the group consisting of terpenes and alkyl or aryl esters of short chain alcohols.

Abstract: A dissolved oxygen releasing blend is disclosed utilizing magnesium peroxide blended with powdered Bentonite and/or vegetable oil. The Bentonite (or other clay material) reduces the hydraulic conductivity of magnesium peroxide, thereby reducing the rate of magnesium peroxide disassociation.

Abstract: Treating compositions containing mutual solvents suitable for forming and maintaining single-phase aqueous fluid treating compositions containing very high concentrations of acids and/or chelating agents are described. Methods of use of these treating compositions for dissolving and removing scale and formation matrix material in oil-field treatments such as stimulation and remediation are given.

Abstract: A formulation containing a copolymer derived from a cationic monomer effectively inhibits and controls the formation of inorganic scales. Suitable copolymers include those comprising an acrylamide unit and a quaternary ammonium salt group, and optionally an acrylate and/or nitrogen heterocyclic monomer including those wherein the quaternary ammonium salt is a unit of the formula: wherein R is methyl or hydrogen; R4 is a C1 to C6 alkyl group, optionally substituted with halogen, hydroxyl and alkoxy groups, X is halogen; and R1, R2 and R3 are independently selected from the group consisting of alkyl and alkoxy groups. Suitable nitrogen heterocyclic compounds include N-vinylpyrrolidone, N-vinylformamide, N-vinylacetamide, N-vinylcaprolactam, N-vinylimidazole and N-vinylpyridine.

Abstract: A formulation containing a copolymer derived from a cationic monomer effectively inhibits and controls the formation of inorganic scales. The formulation has particular application in the removal of zinc sulfide and iron sulfide scales formed when zinc bromide brines are used as completion fluids. The copolymer exhibit high solubility in high-density brines, such as zinc bromide brines. The polymers may be introduced into an oil or gas well as a portion of a carrier fluid or with brine. The preferred copolymer for use in the invention contains an acrylamide unit and a diallyldimethylammonium salt and, optionally, an acrylic acid or a salt thereof. The weight average molecular weight of such inhibitor copolymers is generally between from about 500,000 to about 5,000,000.

Abstract: Methods of increasing the permeability of a portion of a subterranean formation may comprise providing a remediation fluid capable of decreasing the tackiness of a tackifying agent, the remediation fluid comprising a surfactant; introducing the remediation fluid into the portion of the subterranean formation, wherein a plurality of tackified particulates at least partially coated with formation fines are located within the portion; and allowing at least a substantial portion of the formation fines to detach from the plurality of tackified particulates.

Abstract: An aqueous-based composition containing cesium formate and at least one chelating agent is described. Methods of removing scaling deposits, which may include alkaline earth metal sulfates, present on surfaces, including porous media, such as alkaline earth metal sulfate buildup in a well bore, is also described, wherein the method includes contacting the alkaline earth metal sulfate with the compositions of the present invention to remove the scaling deposits. A completion fluid containing at least one alkali metal formate, at least one acid and/or at least one chelating agent, and optionally at least one surfactant or mutual solvent is also described. Methods of removing a filter cake from a well bore surface, which may include weighting agents such as calcium carbonate, is also described, wherein the method includes contacting the filter cake with the completion fluid of the present invention.

Abstract: A formulation containing a copolymer derived from a cationic monomer effectively inhibits and controls the formation of inorganic scales. The formulation has particular application in the removal of zinc sulfide and iron sulfide scales formed when zinc bromide brines are used as completion fluids. The copolymer exhibit high solubility in high-density brines, such as zinc bromide brines. The polymers may be introduced into an oil or gas well as a portion of a carrier fluid or with brine. The preferred copolymer for use in the invention contains an acrylamide unit and a diallyldimethylammonium salt and, optionally, an acrylic acid or a salt thereof. The weight average molecular weight of such inhibitor copolymers is generally between from about 500,000 to about 5,000,000.

Abstract: A method to synthesize a chlorine dioxide block remover in a well is described. The method includes dissolving a chlorate aqueous solution and some acidic substances in water and to produce a hydrogen ion. The chlorate aqueous solution and acidic substances are quickly injected into the well by an injection pump, so they react with each other and produce chlorine dioxide. The synthesis of the chlorine block remover in the well removes oil layer blocks induced by polymers and microbes, while reducing the risk of explosion caused by leaked chlorine dioxide, and reducing the corrosion of equipment and pipes caused by chlorine dioxide.

Abstract: Apparatus and methods for determining suitable displacement fluids for use in subterranean cementing operations, and methods of cementing that use such displacement fluids, are provided. Examples of methods include methods of water-wetting an annulus in a subterranean formation having an oleaginous-external/aqueous-internal fluid disposed on at least a portion of one or more surfaces of the annulus. Another example of a method is a method of using an inverter fluid in a subterranean formation that includes a tubular string disposed therein having an annular region adjacent the outer surface of the tubular string, at least part of the annular region having an oleaginous-external/aqueous-internal fluid on a surface thereof. Another example of a method of the present invention is a method of identifying an inverter fluid to use for inverting an oleaginous-external/aqueous-internal fluid in a subterranean formation.

Abstract: Improved methods and compositions for degrading filter cake deposited in a subterranean formation are provided. These methods and compositions utilize particulates coated with acid-releasing degradable material wherein the released acid is used to degrade a filter cake.

Abstract: Compositions and methods for the inhibition of salt formation in oil and gas wells are disclosed. In particular, nitrilotriacetamide and its salts are effective at treating existing salt formations, and in inhibiting formation of new deposits.

Abstract: Methods are provided for removing filter cake containing a bridging agent soluble in a carboxylic acid salt from a formation fluids producing zone penetrated by a well bore. The methods basically comprise the steps of introducing in an aqueous carrier liquid a carboxylic acid ester and a base for slowly catalyzing the hydrolysis of the ester and forming a carboxylic acid salt therewith into the producing zone, and allowing the base to catalyze the hydrolysis of the carboxylic acid ester to form the carboxylic acid salt so that the carboxylic acid salt dissolves the bridging agent and the filter cake is removed.

Abstract: Barium sulfate and/or calcium carbonate scale inhibitor composition composed of a water-soluble polymer having incorporated phosphate functionality, the polymer being formed from at least one ethylenically unsaturated carboxylic acid monomer, at least one ethylenically unsaturated vinyl sulfonate monomer, or a mixture thereof. The scale inhibitor composition can be used as a means of detecting inhibitor composition in downhole and topside oilfield treatments by means that are faster and more accurate than turbidometric measurement.

Abstract: A method to clean the wellbore and the near wellbore formation adjacent to the wellbore of the gas bearing formation adjacent to the production zone of the wellbore. The method includes the steps of injecting a treatment liquid containing from 84.5 to 100% of liquid carbon dioxide, 0 to 15% of an alcohol, and 0 to 0.5% of a surfactant into the well in a predetermined quantity and maintaining the pressure of the treatment liquid in the near wellbore formation of the gas bearing formation below the fracturing pressure of the formation, releasing the pressure on the wellbore and allowing the liquid CO2 to vaporize and other materials to blow out of the well.

Abstract: Acid based micro-emulsions are disclosed comprising water, an acid blend, an anionic surfactant, a nonionic surfactant, a co-solvent, a solvent and an oxidizer. The micro-emulsions have particular utility in cleaning oil sludges and drilling mud residues from well cuttings, well formations and down hole and surface oil well drilling and production equipment.

Abstract: A method for treating a wellbore (or well casing) and the contiguous wellbore area to remove scale (mineral deposits comprised of, e.g., BaSO4, CaCO3, etc.) in the context of hydrocarbon recovery and other applications is disclosed, said method including contacting the scale with a fluid comprised of an ionic liquid or liquids.

Abstract: Viscous well treating fluids and methods of treating subterranean zones penetrated by well bores are provided. The viscous fluids are basically comprised of water, a gelling agent and a delayed viscosity breaker comprising pentanedione peroxide.

Abstract: A composition, formulation, and method for removing water from a near-wellbore portion of a subterranean formation containing a crude oil and penetrated by a wellbore. The formulation contains alkylpolyglycoside, ethoxylated alcohol and linear alkyl alcohols. The composition contains a hydrocarbonaceous liquid, alkylpolyglycoside, ethoxylated alcohol and linear alkyl alcohol.

Abstract: A method to clean the wellbore and the near wellbore formation adjacent to the wellbore of the gas bearing formation adjacent to the production zone of the wellbore. The method includes the steps of injecting a treatment liquid containing from 84.5 to 100% of liquid carbon dioxide, 0 to 15% of an alcohol, and 0 to 0.5% of a surfactant into the well in a predetermined quantity and maintaining the pressure of the treatment liquid in the near wellbore formation of the gas bearing formation below the fracturing pressure of the formation, releasing the pressure on the wellbore and allowing the liquid CO2 to vaporize and other materials to blow out of the well.

Abstract: The present invention provides methods and compositions for treating subterranean zones penetrated by well bores utilizing environmentally safe viscous fluids. A method of the invention comprises the following steps. A viscous treating fluid composition is provided comprised of water, a viscosity increasing polymer and a water soluble delayed polymer breaker that comprises a mixture of sodium perborate tetrahydrate and a solubility increasing boron complex or ester forming compound. The viscous treating fluid composition is introduced into the subterranean zone wherein the viscous treating fluid is allowed to break into a thin fluid of reduced viscosity.

Abstract: Compositions and methods for treating systems, especially oil and/or gas wells, characterized by metal sulfide deposits are provided. Compositions according to the invention generally comprise a thioacid, an amine salt, and a diphosphonic acid. Methods according to the invention may comprise introducing such composition into a system characterized by metal sulfide deposits, or alternatively, introducing into the system individual quantities of the composition components.

Abstract: The present invention provides methods and compositions for removing a water-based drilling fluid from surfaces in a well bore and leaving the surfaces water-wet. A method of the invention basically comprises the following steps. A water-based drilling fluid removal solution comprised of water and a mixture of a sulfonated kraft lignin salt and an N-methyl-N-oleyltaurine salt dissolved therein is provided. The drilling fluid is displaced from the well bore and the well bore surfaces are contacted with the removal solution to thereby remove the drilling fluid from the surfaces and make the surfaces water-wet.

Abstract: Present invention relates to high brine carrier fluid, said carrier fluid selected from the group consisting of organic acids, organic acid salts, inorganic salts and combination of one or more organic acids or organic acid salts, a co-surfactant and an amount of a zwitterionic surfactant. The invention also relates to methods of treating a subterranean wellbore, including drilling, hydraulic fracturing, gravel placement, scale removing, mud cake removing, using said high brine carrier fluid.

Abstract: The present invention relates to biodegradable chemical compositions wherein core substrates, particularly oil well chemicals, are adsorbed onto particulate starch, particularly granular starch, providing a stable, controlled release formulation suitable for use in oil field applications. The invention further relates to the process of preparing obtaining these compositions.

Abstract: Improved mud additive compositions are provided which are especially formulated to control hole enlargement due to salt bed erosion during drilling, and to assist in solubilization of deposited salt during well operations. The compositions include a first ingredient such as sodium or potassium ferrocyanide and mixtures thereof, and a second ingredient such as the a phosphonic acid, alkali or alkaline earth metal phosphonic acid salts, or mixtures thereof. The first ingredient is generally present at a level of from about 50-95% by weight in the particulate, dilutable form of the invention, whereas the second ingredient is present at a level of from about 5-50% by weight. The compositions hereof may be added to drilling mud during drilling operations or to fresh water for removing salt depositions.