Abstract: A treatment fluid and method for simultaneously swelling an oil-swellable elastomer and breaking a filtercake in a well. The treatment fluid includes an emulsion comprising: (i) a continuous oil phase, wherein the oil phase comprises: (a) an oil; and (b) an emulsifier; and (ii) an internal aqueous phase, wherein the aqueous phase comprises: (a) water; and (b) a water-soluble hydrolyzable ester of a carboxylic acid; wherein the emulsion is stable to hydrolysis of the water-soluble hydrolyzable ester of the carboxylic acid. A method of treating a well includes the steps of: (A) forming the treatment fluid; and (B) introducing the treatment fluid into the portion of the wellbore, wherein: (i) a filtercake has been previously formed in the portion of the wellbore, wherein the filtercake comprises an acid-soluble or an acid-degradable material; and (ii) an oil-swellable elastomer has been previously deposited or positioned in the portion of the wellbore.

Abstract: Methods for forming proppant pillars in a formation during formation fracturing include include periods of pumping a first fracturing fluid including a proppant and an aggregating composition including a reaction product of a phosphate compound or a plurality of phosphate and an amine, periods of pumping a second fracturing fluid excluding a proppant and an aggregating composition including a reaction product of a phosphate compound and periods of pumping a third fracturing fluid including an aggregating composition including a reaction product of a phosphate compound, where the pumping of the three fracturing fluids may be in any order and may involve continuous pumping, pulse pumping, or non-continuous pumping.

Abstract: Compositions include (1) aggregating compositions capable of forming deformable partial or complete coatings on formation surfaces, formation particle surfaces, downhole fluid solid surfaces, and/or proppant surfaces, where the coatings increase aggregation and/or agglomeration propensities of the particles and surfaces to form particles clusters or pillars having deformable coatings, and (2) aggregation stabilizing and/or strengthening compositions capable of altering properties of the coated clusters or pillars to form consolidated, stabilized, and/or strengthened clusters or pillars. Methods for stabilizing aggregated particle clusters or pillars include (1) treating the particles with an aggregating composition to form aggregated clusters or pillars and (2) treating the aggregated particle clusters or pillars with a stabilizing or strengthening composition to form consolidated, stabilized, and/or strengthened clusters or pillars.

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: A method for forming a well and pipeline treating fluid is provided. The method comprises combining a cross-linkable gelling polymer, a scavenging compound capable of reducing a concentration of divalent and polyvalent metal ions and salts thereof available for reaction, a hydration solvent and optionally an acid. The resulting mixture has a pH ranging from about 3 to about 7 and a first viscosity. The mixture is maintained at conditions suitable for hydration of the cross-linkable gelling polymer until the mixture has a second viscosity that is greater than the first viscosity. The mixture is combined with an aqueous based fluid and at least one cross-linking agent. The pH of the mixture is raised to a sufficient level to allow a desired degree of cross-linking to occur. Other methods, a well and pipeline treating gel and a well and pipeline treating fluid are also provided.

Abstract: A method for drilling through a producing zone in a subterranean formation or for completing a wellbore in a subterranean formation, using a drill-in and completion fluid comprising a blend of a phosphate brine and water.

Abstract: A gelling agent for a hydrocarbon fracturing fluid is disclosed, comprising the general formula of: in which X is an OR1, NR1R2, or SR1 group, R1 is an organic group having 2-24 carbon atoms, and R2 is an organic group or a hydrogen. Y is an NR3R4 or SR3 group, R3 is an organic group having 2-24 carbon atoms, and R4 is an organic group or a hydrogen. A method of making a gelling agent for a hydrocarbon fracturing fluid is also disclosed. Phosphorus oxyhalide is reacted with a chemical reagent to produce substantially only diester phosphorus oxyhalide, the chemical reagent comprising at least one of an organic alcohol having 2-24 carbon atoms, an organic amine with an organic group having 2-24 carbon atoms, and an organic sulfide having 2-24 carbon atoms. The diester phosphorus oxyhalide is then hydrolyzed to produce diester phosphoric acid.

Abstract: A variety of methods and compositions are disclosed, including, in one embodiment, a method of cementing in a subterranean formation, comprising: providing a set-delayed cement composition comprising water, pumice, hydrated lime, and a set retarder; activating the set-delayed cement composition; introducing the set-delayed cement composition into a subterranean formation; and allowing the set-delayed cement composition to set in the subterranean formation.

Abstract: An aqueous hydraulic fluid composition comprising a first lubricant comprising at least one phospholipid and a second lubricant comprising an alkoxylate salt. The aqueous hydraulic fluid composition contains less than about 20% by weight (preferably none or substantially none) of an oil selected from the group consisting of mineral oils, synthetic hydrocarbon oils, and mixtures thereof. The use of alkoxylate salts provides increased lubricity and also acts as an emulsion stabilizer for the composition.

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: A composition and method of fracturing a subterranean formation. The composition includes: about 0.25 wt. % to about 3.0 wt. %, based on a weight of the hydrocarbon liquid, of a mixture of phosphate esters, said esters selected from the group consisting of: monoester PO(OR1)(OH)2, PO(OR2)(OH)2; diester PO(OH)(OR1)m(OR2)2?m where m=0, 1, or 2; triester PO(OH)(OR1)n(OR2)3?n where n=0, 1, 2 or 3; and phosphoric acid H3PO4 wherein R1 and R2 each have 2 to 18 carbon atoms; and about 0.2 wt. % to about 1.0 wt. %, based on the weight of the hydrocarbon liquid, of an acidic polynuclear aluminum compound having an Al:Cl mole ratio ranging from about 1.40:1 to about 2.2:1. The composition is added to a hydrocarbon liquid to fracture the subterranean formation with this hydrocarbon liquid. The hydrocarbon liquid containing the composition exhibits a substantially constant viscosity.

Abstract: The present invention relates to functional fluid compositions containing antioxidants, and specifically stable compositions containing antioxidants with limited solubility in and/or limited compatibility with the functional fluids with which they are used. In particular the present invention deals with functional fluids used in internal combustion engines, such as engine oils, and antioxidants containing a phenolic or benzoic group, where the antioxidant is present in the functional fluid composition at levels that would otherwise cause the composition to be unstable and/or hazy.

Abstract: The invention is directed to stable crosslinked water-soluble swellable polymers and methods for making same. More particularly, the invention relates to a composition comprising expandable polymeric particles having anionic sites and labile crosslinkers and stable crosslinkers, said particle mixed with a fluid and a cationic crosslinker that is capable of further crosslinking the particle on degradation of the labile crosslinker and exposure of the anionic sites so as to form a gel. A particularly important use is as an injection fluid in petroleum production, where the expandable polymeric particles are injected into target zone and when the heat and/or suitable pH of the target zone cause degradation of the labile crosslinker and the particle expands, the cationic crosslinker crosslinks the polymer to form a gel, thus diverting water to lower permeability regions and improving oil recovery.

Abstract: A fluid loss pill that includes a crosslinked polymer gel, a brine, and solid salt particles disposed in said gel is described. Further, a method for reducing fluid loss that includes pumping a selected amount of a fluid loss pill into a wellbore leading to an oil-, condensate-, or gas-producing formation, the fluid loss pill including a crosslinked polymer gel, a brine, and solid salt particles disposed in said gel is described.

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: A method of treating a medium for water fracturing is disclosed, the method comprises: introducing at least one biocide and at least one metabolic inhibitor in the medium, using the medium for water fracturing. In another aspect a method of controlling the post-fracture reservoir souring by the metabolic activities of sulfate reducing bacteria of a well is described: at least one biocide and at least one metabolic inhibitor are introduced in a medium made of water, the medium is used for fracturing the well, and the medium remains in the reservoir to kill and/or inhibit growth of sulfate reducing bacteria.

Abstract: The present invention is a cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas and a first additive. The liquefied industrial gas may be liquefied carbon dioxide, liquefied nitrogen, or a blend of the two. The liquefied industrial gas mixture should be substantially free of water. In this context, substantially free of water means less than 10% water by volume, or preferably less than 5% water by volume. In addition to the first additive, a proppant may be added to the fracturing fluid. In addition to the biocide and/or proppant additional additives may be added to the liquefied industrial gas as required. Non-limiting examples of such additives include ozone, a friction reducer, an acid, a gelling agent, a breaker, a scale inhibitor, a clay stabilizer, a corrosion inhibitor, an iron controller, an oxygen scavenger, a surfactant, a cross-linker, a non-emulsifier, a Ph Adjusting agent, or any combination thereof.

Abstract: An aqueous hydraulic fluid composition comprising a first lubricant comprising at least one phospholipid and a second lubricant comprising an alkoxylate salt. The aqueous hydraulic fluid composition contains less than about 20% by weight (preferably none or substantially none) of an oil selected from the group consisting of mineral oils, synthetic hydrocarbon oils, and mixtures thereof. The use of alkoxylate salts provides increased lubricity and also acts as an emulsion stabilizer for the composition.

Abstract: Consolidation fluids comprising: an aqueous base fluid comprising a hardening agent; an emulsified resin having an aqueous external phase and an organic internal phase; a silane coupling agent; and a surfactant. The consolidation fluid itself may be emulsified and further comprise an emulsifying agent. The consolidation fluid may also be foamed in some cases.

Abstract: A fluid may contain nanoparticles and a base fluid where the base fluid may be a non-aqueous fluid. The base fluid may be, but is not limited to a drilling fluid, a completion fluid, a production fluid, and/or a stimulation fluid. The fluid may have at least one property, such as but not limited to a dielectric constant ranging from about 5 to about 10,000, an electrical conductivity ranging from about 1×10?6 S/m to about 1 S/m, and combinations thereof. The non-aqueous fluid may be a brine-in-oil emulsion, or a water-in-oil emulsion, and combinations thereof. The addition of nanoparticles to the base fluid may modify the electrical properties of the fluid.

Abstract: New fluids are disclosed for use in servicing subterranean formations containing oil and gas. In particular, an improved chemical gelling additive for hydrocarbon based fracturing fluids is disclosed having reduce, negligible or no volatile phosphorus at temperatures below about 250° C.

Abstract: A method is disclosed to inhibit scale formation in aqueous systems whereby a threshold amount of a scale inhibiting agent, represented by an aminoacid alkylphosphonic acid, is added to the aqueous system. The aminoacid moiety can be represented by ?-species or by species having, at least, two or more carbon atoms between the carboxylic moiety and the amine group. These aminoacid based inhibitors exhibit unusually superior performance and system acceptability compared to leading state-of-the-art inhibitors.

Abstract: The present invention relates to a method of preventing or alleviating the problems associated with corrosion and to novel formulations for use in such a method.

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: Liquid hydrocarbons are gelled by the introduction of a phosphate ester and a crosslinking agent for use in oil recovery. Generally a proppant, delayed gel breaker and other modifiers are added to the gelled hydrocarbon to improve the oil recovery process. The phosphate ester used in this method and composition for oil recovery has low volatility and good stability during hydrocarbon distillation resulting in improved distillation efficiency in a refinery.

Abstract: A method of secondary oil recovery is disclosed wherein from 0.1 to 100 000 ppm of a medium soluble aminoalkylene phosphonic acid amine salt are used wherein both the aminoalkylene phosphonic acid moiety and the amine moiety are selected from a specifically defined class of compounds. The substantially medium soluble aminoalkylene amine phosphonates exhibit a significantly improved compatibility with the recovery medium and thus can propagate fairly freely into the medium and consequently cover a largely extended rock surface before being subject to precipitation in the form of a medium insoluble scale inhibitor. The amine compound is represented by combinations of structurally different compounds.

Abstract: Phosphate brines are disclosed having reduced corrosive ratings. The phosphate brines include an additive system that reduces the corrosiveness of the phosphate brines compared to the phosphate brines in the absence of the additive system.

Abstract: Non-settable spacer fluids for use in subterranean operations comprising: a base liquid; vitrified shale; a chelating agent; a clay weighting agent; and a viscosifying agent. The chelating agent includes one or more of nitrilotriacetic acid, ethylene diamine tetracetic acid (EDTA), ethylene glycol tetraacetic acid (EGTA), tartaric acid, a polycarboxylic acid, a lignosulphonate, hydroxyethylidene diphoshponic acid (HEDP), diethylene triamine penta (methylene phosphonic) acid (DETMP), amino-tri-methylene phosphonic acid (ATMP), ethylene diamine tetra (methylene phosphonic) acid (EDTMP), or salts thereof. The clay weighting agent is present in the range of about 0.01% to about 85% by weight of the spacer fluid. The viscosifying agent is present in the range of about 1% to about 10% by weight of the spacer fluid.

Abstract: A packer or annular fluid includes a hydrocarbon fluid; and a gelling agent; wherein the packer fluid is a yield power law fluid. A method for preparing a packer fluid includes preparing a mixture of a hydrocarbon fluid, and a gelling agent; heating the mixture to a selected temperature; and shearing the mixture. A method for emplacing a packer fluid into an annulus includes preparing the packer fluid that includes a hydrocarbon fluid and a gelling agent, wherein the packer fluid is a yield power law fluid; and pumping the packer fluid into the annulus.

Abstract: The invention provides an environmentally friendly composition including a friction reducer, a biocide, a scale inhibitor, and optionally a clay stabilizer.

Abstract: Fluids for use in hydrocarbon recovery operations include water and at least one organo-anionic surfactant. The fluids may be used in methods for conducting hydrocarbon recovery operations, such as drilling operations, completion operations, production operations, injection operations. The fluid may be adapted to remediate a NAF filter cake. Exemplary organo-anionic surfactants may include one or more of monoethanol ammonium alkyl aromatic sulfonic acid, monoethanol ammonium alkyl carboxylic acid, and mixtures thereof.

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: The present invention relates to a method for inhibiting scale and corrosion in aqueous systems, for example, under high temperature and pressure conditions such as temperatures up to 250° C. and/or pressures up to 10000 psi (i.e., about 68.9 MPa). The method involves providing polymer compositions comprising 1% to 100% by weight of a phosphorus-containing amide monomer to such aqueous systems, which arise, for example, in connection with oilfield operations and some water treatment applications.

Abstract: New fluids are disclosed for use in servicing subterranean formations containing oil and gas. In particular, an improved chemical gelling additive for hydrocarbon based fracturing fluids is disclosed having reduce, negligible or no volatile phosphorus at temperatures below about 250° C.

Abstract: The invention provides formulations for facilitating the removal of oil from a surface using a chisel composition, wherein the chisel composition includes a polymer having one or more binding points with a high affinity for the surface, and one or more hydrophilic segments that form a hydrophilic coating on the surface, rendering the surface water-wet and thereby facilitating the removal of oil from the surface. The invention also provides for methods of use of such formulations.

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: Phosphate esters useful for gelling hydrocarbons in combination with a metal source are disclosed along with methods of preparation of the phosphate esters. Fouling in oil refinery towers has been attributed due to distillation of impurities present in phosphate esters used to gel hydrocarbons for oil well fracturing. The improved method of preparation of the phosphate ester results in a product that substantially reduces or eliminates volatile phosphorus, which is phosphorus impurities that distill up to 250° C., and increases the high temperature viscosity of the hydrocarbon gels formed using the phosphate esters.

Abstract: Many methods are presented herein including a method comprising: providing a metal surface; and contacting the metal surface with a treatment fluid comprising an aqueous base fluid, an acid, a corrosion inhibitor, and a corrosion inhibitor intensifier composition comprising a corrosion inhibitor compound that corresponds to a formula: PR1R2R3, wherein R1, R2, and R3 are chosen from the group consisting of C1-C20 alkyl, cycloalkyl, oxyalkyl, and aryl groups, and R1, R2, and R3 may or may not be equal. Corrosion inhibitor intensifier compositions also are provided.

Abstract: The use of a surfactant mixture comprising at least one surfactant having a hydrocarbon radical composed of from 12 to 30 carbon atoms and at least one cosurfactant having a branched hydrocarbon radical composed of from 6 to 11 carbon atoms for tertiary mineral oil extraction.

Abstract: Phosphate esters useful for gelling hydrocarbons in combination with a metal source are disclosed along with methods of preparation of the phosphate esters. Fouling in oil refinery towers has been attributed due to distillation of impurities present in phosphate esters used to gel hydrocarbons for oil well fracturing. The improved method of preparation of the phosphate ester results in a product that substantially reduces or eliminates volatile phosphorus, which is phosphorus impurities that distill up to 250° C., and increases the high temperature viscosity of the hydrocarbon gels formed using the phosphate esters.

Abstract: A gelling agent for a hydrocarbon fracturing fluid is disclosed, comprising the general formula of: in which X is an OR1, NR1R2, or SR1 group, R1 is an organic group having 2-24 carbon atoms, and R2 is an organic group or a hydrogen. Y is an NR3R4 or SR3 group, R3 is an organic group having 2-24 carbon atoms, and R4 is an organic group or a hydrogen. A method of making a gelling agent for a hydrocarbon fracturing fluid is also disclosed. Phosphorus oxyhalide is reacted with a chemical reagent to produce substantially only diester phosphorus oxyhalide, the chemical reagent comprising at least one of an organic alcohol having 2-24 carbon atoms, an organic amine with an organic group having 2-24 carbon atoms, and an organic sulfide having 2-24 carbon atoms. The diester phosphorus oxyhalide is then hydrolyzed to produce diester phosphoric acid.

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 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 is disclosed to inhibit scale formation in aqueous systems whereby a threshold amount of a scale inhibiting agent, represented by an aminoacid alkylphosphonic acid, is added to the aqueous system. The aminoacid moiety can be represented by ?-species or by species having, at least, two or more carbon atoms between the carboxylic moiety and the amine group. These aminoacid based inhibitors exhibit unusually superior performance and system acceptability compared to leading state-of-the-art inhibitors.

Abstract: Phosphate esters useful for gelling hydrocarbons in combination with a metal source are disclosed along with methods of preparation of the phosphate esters. Fouling in oil refinery towers has been attributed due to distillation of impurities present in phosphate esters used to gel hydrocarbons for oil well fracturing. The improved method of preparation of the phosphate ester results in a product that substantially reduces or eliminates volatile phosphorus, which is phosphorus impurities that distill up to 250° C., and increases the high temperature viscosity of the hydrocarbon gels formed using the phosphate esters.

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: A method of servicing a wellbore comprising providing a composition comprising a mutual solvent precursor, an acid precursor, and an aqueous fluid, and contacting the composition with oil wet solids in the wellbore. A method of servicing a wellbore comprising introducing an oil-based fluid into a wellbore, wherein the oil-based fluid forms oil wet solids in the wellbore, contacting the oil wet solids in the wellbore with a composition comprising a mutual solvent precursor; an acid precursor and an aqueous fluid, and allowing the oil wet solids to become water wet. A method of servicing a well bore comprising contacting a composition comprising a formate ester with oil wet solids in the well bore under conditions wherein the formate ester hydrolyzes to release formic acid, wherein the formic acid catalyzes the hydrolysis of additional formate ester, and wherein all or a portion of the formate ester converts at least a portion of the oil-wet solids to water-wet solids.

Abstract: A method of servicing a wellbore comprising preparing a composition comprising a calcium aluminate cement, water, a polyphosphate, a pozzolan, and a set retarding agent, wherein the set retarding agent comprises an alkali halide and a basic phosphate salt, placing the composition in the wellbore and allowing the composition to set. A composition comprising a calcium aluminate cement in an amount of from about 30 wt. % to about 60 wt. % and a set retarding agent in an amount of from about 0.1 wt. % to about 15 wt. % based upon the total weight of the composition, wherein the set retarding agent comprises an alkali halide and a basic phosphate salt in a ratio of from about 3:1 to about 1:3.

Abstract: A treatment fluid for treating a subterranean formation penetrated by a wellbore is formed from an aqueous medium, a diutan heteropolysaccharide having a tetrasaccharide repeating unit in the polymer backbone and a peroxide breaker. A method of treating a subterranean formation penetrated by a wellbore may be carried out by introducing the treatment fluid into the formation through the wellbore. Breaking aids or catalysts may also be used with the treatment fluid.

Abstract: A composition 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.