Abstract: The present invention provides a method of forming a viscosified treatment fluid comprising: providing a treatment fluid that comprises water and a gelling agent; contacting the treatment fluid with a boronic acid crosslinking agent so as to form a crosslinked gelling agent, wherein the boronic acid crosslinking agent comprises a compound having the formula: The present invention also provides methods of crosslinking gelling agent molecules, methods of treating a subterranean formation, methods of reusing viscosified treatment fluids, methods of fracturing subterranean formations, and methods of placing a gravel pack in subterranean formations. The present invention also provides boronic acid crosslinking agents and viscosified treatment fluids that comprise crosslinked gelling agents, the crosslinked gelling agent being formed from a reaction comprising a gelling agent and a boronic acid crosslinking agent.

Abstract: In one embodiment, the present invention provides a method of increasing the viscosity of a treatment fluid comprising the steps of: adding a networking agent to the treatment fluid, wherein the networking agent is represented by the formula: Y—X—[B(OR)2]n, wherein: Y is at least partially capable of forming a crosslink between a gelling agent molecule, a second networking agent, and/or a combination thereof; X is at least partially capable of preventing or inhibiting a reaction represented by the formula: ROH+R?B(OR)2?R?OH+B(OR)3; R and R? are a hydrogen, an alkyl group, an aryl group, or a combination thereof; and n is a positive integer greater than or equal to 1; allowing at least one crosslink to form between the networking agent and a gelling agent molecule, a second networking agent, and/or a combination thereof; and allowing the viscosity of the treatment fluid to increase.

Abstract: A fluid for use in a subterranean formation penetrated by a wellbore, the fluid comprising: (a) water; (b) an orthoester; and (c) a surfactant comprising a tertiary alkyl amine ethoxylate generally represented by the following formula: (CH2—CH2—O)XH R—N< (CH2—CH2—O)YH wherein R is an alkyl group or aryl group, and wherein X and Y are each independently at least one. A method of fracturing a subterranean formation, comprising the step of forming a foamed fracturing fluid comprising water; an orthoester; a surfactant comprising a tertiary alkyl amine ethoxylate generally represented by the formula above; and a gas. The method also provides the step of introducing the foamed fracturing fluid into a subterranean formation at a pressure sufficient to create a fracture in the subterranean formation.

Abstract: A composition of a microemulsion including a mixture of a combination of surfactants and co-surfactants, an oil phase and an aqueous phase is described. In addition, a method for the advanced recovery of heavy oils is described which includes the steps of injecting a bank containing a microemulsion composition, injecting a bank of a polymer solution, and injecting water. The microemulsion composition can be applied in arenitic and carbonatic reservoirs, containing oils with API below 22.3° API, in both onshore and offshore fields.

Abstract: In a method for optimizing gas lift operations in the production of crude oil, a surfactant is injected with the lift gas into the an oil well such that the surface tension between the lift gas and the formation fluid being produced is reduced and/or a lift gas-formation fluid foam is formed. The reduction in surface tension and/or foam formation increases the efficiency of the lift gas for lifting the formation fluid to the surface. The surfactant is selected to minimize corrosion. The surfactants consist essentially of sultaines, hydroxy sultaines, and their salts. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims. 37 CFR 1.72(b).

Abstract: A synergistic blend for foaming concentrated brines comprises at least one foaming agent (in an amount between from about 10 to about 90 weight percent of the blend) and a compound of the formula: CnH2n+1—N—[(CH2)mCOOM]2??(I) wherein n is 4 to 11, M is an alkali metal and m is 1 to 3. Especially suitable as foaming agent are quaternary ammonium salts, alkyl betaines, alkylamidopropyl betaines, sulfabetaines, hydroxysultaines, amphoteric perfluorohydrocarbons, as well as alkylether sulfates. Such synergistic blends are especially useful in the foaming of saturated or near saturated brines.

Abstract: A method of servicing a wellbore comprising preparing a cement slurry by premixing at least one latex, at least one stabilizer, and optionally water to form a homogeneous solution, further mixing the homogeneous solution with an ionic compound, cement, and optionally additional water to form the slurry, and placing the slurry in the wellbore. A method of stabilizing latex in cement slurry containing saltwater, comprising premixing the latex with a stabilizer until a homogenous solution forms prior to contacting the latex with the saltwater. A cement slurry comprising a latex, a stabilizer, a cement, an ionic compound, and water wherein the latex and stabilizer are contacted prior to contact of the latex with the ionic compound.

Abstract: A microemulsion system is disclosed which comprises a solvent subsystem, a co-solvent subsystem and a surfactant subsystem comprises at least one monoalkyl branched propoxy sulfate anionic surfactant, where the microemulsion system are useful in drilling, producing, remediation, and fracturing application to reduce water blocks and water blocking in formation of a producing formation.

Abstract: A microemulsion system is disclosed which comprises a solvent subsystem, a co-solvent subsystem and a surfactant subsystem comprises at least one monoalkyl branched propoxy sulfate anionic surfactant, where the microemulsion system are useful in drilling, producing, remediation, and fracturing application to reduce water blocks and water blocking in formation of a producing formation.

Abstract: The invention provides a surface active ingredient composition, which includes a base liquid including water which has dispersed therein in percentages by volume: Sodium Chloride 1 to 3% Magnesium 1 to 2% Calcium 1 to 2% Potassium 1 to 2% Sulphate 1 to 2% Carbon 0.5 to 1% Nitrate 1 to 2% and Phosphate 1 to 2% sodium chloride dissolved in the base liquid; and sodium alkyl ether sulphate dissolved in the base liquid, with the portion of the base liquid to sodium chloride and sodium alkyl ether sulphate being between 1:1:1.5 and 1:1:5. The invention further provides a process for producing same and uses thereof.

Abstract: A composition for inhibiting or preventing the formation of emulsions and asphaltic sludges in the presence of treating acids during the acid stimulation of hydrocarbon wells is provided. The composition includes an alkyl aryl sulfonic acid or salt thereof, an acetylenic alcohol, an alkyl diphenyl oxide sulfonic acid or derivative thereof, in an alkyl alcohol solvent. The disclosed compositions can be used in an acid treatment solution, such as 15% hydrochloric acid, to prevent and resolve live acid and spent acid emulsions for a wide range of crude oils.

Abstract: A surfactant blend for servicing wells includes a first non-ionic surfactant having a hydrophilic-lipophilic balance of between about 10 and about 15; a second non-ionic surfactant having a hydrophilic-lipophilic balance of between about 2 and about 6; and an anionic surfactant.

Abstract: Foamed treatment fluids comprising water, a gas, and a foaming and foam stabilizing surfactant mixture comprising an alkali salt of an alkyl ether sulfate, wherein the alkali salt of the alkyl ether sulfate comprises an alkali salt of a C6-10 alkyl ether sulfate, and an alkali salt of a C4 alkyl ether sulfate, an alkyl amidopropyl amphoteric surfactant selected from the group consisting of an alkyl amidopropyl hydroxysultaine, an alkyl amidopropyl betaine, and combinations thereof, and an alkyl amidopropyl dimethylamine oxide. Methods comprising providing the foamed treatment fluid and introducing the foamed treatment fluid into a subterranean formation.

Abstract: The invention provides a fluid for use in a subterranean formation penetrated by a wellbore, the fluid comprising: (a) water; (b) delayed release acid; (c) a surfactant comprising a tertiary alkyl amine etboxylate generally represented by the following formula: wherein R is an alkyl group or groups, X is about 2 to about 15, and Y is about 2 to about 15; and (e) a gelling agent. The invention also provides a method of fracturing a subterranean formation, comprising the step of forming a foamed fracturing fluid comprising water; a surfactant comprising a tertiary alkyl amine ethoxylate generally represented by the formula above; a gelling agent; and a gas. The method also provides the step of introducing the foamed fracturing fluid into a subterranean formation at a pressure sufficient to create a fracture in the subterranean formation. The method also provides the step of introducing an acid into the subterranean formation.

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: Methods in which temperature is used to control the foaming and/or defoaming of foamed treatment fluids comprising an aqueous liquid, an ionic foaming surfactant, and a gas are provided. A method of treating at least a portion of a subterranean formation is provided, the method comprising: providing a treatment fluid having a foam transition temperature, the treatment fluid comprising an aqueous liquid, and an ionic foaming surfactant; foaming the treatment fluid to form a foamed treatment fluid; circulating the foamed treatment fluid in a well bore penetrating the subterranean formation; and defoaming at least a substantial portion of the foamed treatment fluid, the defoaming comprising lowering the temperature of the foamed treatment fluid to about at or below the foam transition temperature.

Abstract: Well completion foamed spacer fluids and methods of using the foamed spacer fluids are provided. A method of the invention for displacing a first fluid from a well bore with an incompatible second fluid comprises the following steps. A foamed spacer fluid is placed between the first and second fluids to separate the first and second fluids and to remove the first fluid from the walls of the well bore. Thereafter, the first fluid and the foamed spacer fluid are displaced from the well bore with the second fluid.

Abstract: Improved methods of generating gas in and foaming well treating fluids introduced into a subterranean zone are provided. A method of the invention includes the steps of combining one or more gas generating chemicals with the well treating fluid and combining one or more delayed encapsulated activators having selected release times with the well treating fluid containing the gas generating chemicals so that the gas generating chemicals react with the delayed encapsulated oxidizing agent activators and gas and foam are formed in the treating fluid while the treating fluid is being pumped and after being placed in the subterranean zone.

Abstract: A wellbore fluid composition effective to reduce oil-containing residue and water wet wellbore surfaces is provided. The fluid composition comprises a terpene composition and a surfactant. Methods for use of the fluid composition as a single spacer or as a multiple spacer in conjunction with a second fluid are provided. Methods for use of the composition in reduction or removal of oil-containing residue from wellbore surfaces, as a clean-up fluid, in wellbore completions, as a displacement fluid, and in wellbore treatment are provided.

Abstract: Drilling fluid additives are designed to increase the density of drilling fluids while minimizing the increase in the resistance to flow of the drilling fluid. In particular, barite particles are added to the drilling fluid as a weight material where the barite particles include at least 85% by weight particles less than 75 microns and greater than 6 microns in equivalent spherical diameter.

Abstract: An acid corrosion inhibitor composition is provided for petroleum wells and water wells subjected to stimulation with acid solutions. The inhibitor combines cinnamaldehyde and an organo-sulfur compound. The inhibitor provides a reduced rate of corrosion and fewer instances of pitting than inhibitors which include cinnamaldehyde alone. The inhibitor does not suffer from the well-known oil field aldehyde/polyacrylamide crosslinking incompatibility. The enhanced performance by the inhibitor of the present invention is provided by a synergistic action between the cinnamaldehyde and an organo-sulfur compound.

Abstract: The present invention provides improved foamed well cement slurries, additives and methods. The additives, which foam and stabilize a cement slurry containing fresh water or salt water, are basically comprised of a mixture of an ethoxylated alcohol ether sulfate surfactant, an alkyl or alkene amidopropyl betaine surfactant and an alkyl or alkene amidopropyl dimethyl amine oxide surfactant.

Abstract: Improved methods of cementing in a well are provided whereby stress failures in the resulting set cement are prevented or reduced. The methods basically comprise the steps of placing a foamed cement composition in a zone in the well to be cemented which when set has sufficient elastic properties to resist stress failure comprised of hydraulic cement, water, a gas present in an amount in the range of from about 5% to about 75% by volume of the cement composition and a foaming agent, and then allowing the cement composition to set across the zone.

Abstract: A method for recovering surfactants from produced fluids by mixing with produced fluids about 0.1% to about 5% of a nonionic surfactant having a phase inversion temperature above the temperature of the produced fluids, heating the mixture above the phase inversion temperature, mixing the phase containing oil and the surfactants with water, and cooling the mixture below the phase inversion temperature to extract the surfactants into an aqueous phase, provided that if a sufficient concentration of the nonionic surfactant is already in the produced fluids, it need not be added.