Abstract: An acid corrosion inhibitor includes an active corrosion intermediate including alkylated pyridine, an internal intensifier including formic acid, a filming additive including cinnamaldehyde, a surfactant including one or more of propylene glycol methyl ether and alcohol ethoxylate, and a solvent including ethylene glycol. A system includes a formulation, an acid system including HCl and MSA, and a metal surface contacting the formulation and/or the acid system. The formulation of the system includes an alkyl pyridine, formic acid, cinnamaldehyde, and one or of propylene glycol methyl ether and alcohol ethoxylate. A method for reducing corrosion of a pipe in contact with an acid system and disposed in a well bore includes applying the acid corrosion inhibitor. The acid system includes methanesulfonic acid.

Abstract: The present disclosure generally relates to compositions and uses of sulfidogenesis inhibitor compounds of Formulae 1 and 2 for preventing sulfidogenesis, i.e., the reduction reaction of a sulfur-containing compound by sulfur-utilizing prokaryotes that produce sulfide species such as hydrogen sulfide, during enhanced oil recovery processes. A method for inhibiting or decreasing microbial sulfide production by sulfur-utilizing prokaryotes includes addition of an effective amount of sulfidogenesis inhibitor compounds of Formulae 1 and 2 to the fluid that is injected into a sulfidogenic reservoir system during enhanced oil recovery. For example, the compounds can be used as sulfidogenesis inhibitors in a water injection system for use in a hydrocarbon extraction system or a hydrocarbon production system. Thus, these compositions can be effectively used as inhibitors of biogenic hydrogen sulfide generation in oilfield fluids.

Abstract: A method and system for removing wax deposits from a wellbore and other oil production and processing equipment using a wax removal surfactant having at least 1% alkyl polyglycoside (APG), at least 0.5% ethoxylated alcohol (AE) or alcohol ethoxysulfates (AES), and at least 1% saturated alcohol, and optionally comprising D-Limonene, wherein the wax removal surfactant solution forms a Winsor Type III or Type IV microemulsion with water and wax.

Abstract: Fluids including a parylene-coated chemical entity and methods of treating a subterranean formation with such fluids are disclosed. The methods may include introducing a treatment fluid into a subterranean formation, the treatment fluid containing a parylene-coated particle having a chemical entity encapsulated therein.

Abstract: An oil well being subjected to an acid stimulation may be treated with a corrosion inhibitor including an Ammonium Iodide Ion Source, a first carbonyl containing compound having a general formula: and a second carbonyl containing compound having the general formula: wherein R1 is an alkyl or aromatic group, R2 is a hydrogen, alkyl or aromatic group, and R3 is a hydrogen or an alkyl group having from 1 to 6 carbons; and wherein the oil well being treated has zone being treated at a temperature of from about 90 to about 500° F. This abstract 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.

Abstract: A composition for enhancing fluid viscosity including a mixture of at least one cationic or cationizable polymer and at least one anionic or anionizable (hydrolysable) polymer. The composition has a zeta potential at 25° C. in the range of 0.5 to 100 mV or ?0.5 to ?100 mV, typically 1 to 60 mV or ?1 to ?60 mV, or is a precursor convertible at a temperature of 100 to 250° C. to the composition having a zeta potential at 25° C. of 0.5 to 100 mV or ?0.5 to ?100 mV, typically 1 to 60 mV or ?1 to ?60 mV. Typically the compositions exhibit salt tolerance and interaction of both polymers at very high temperatures (>300° F.) such that the system exhibits an increase of viscosity at extreme temperatures. The compositions are useful for hydraulic fracturing, enhanced oil recovery, subterranean acidization, personal care as well as home and industrial cleaners.

Abstract: Curable adhesive compositions comprising a silane coupling agent; a polymer, the polymer having a reactive silicon end group; a catalyst operable to facilitate the curing of the polymer; and, a diluent and wherein the polymer comprises about 0.1% to about 30% by weight of the curable adhesive composition. The curable adhesive compositions may further comprise a dehydrating agent comprising a component selected from the group consisting of: vinyl trimethoxysilane, vinyl alkoxysilane, inorganic zeolites, and organic zeolites.

Abstract: A method of treating a very high salinity high temperature hydrocarbon containing formation is described. The method includes (a) providing a hydrocarbon recovery composition to at least a portion of a hydrocarbon containing formation having a brine salinity of above about 13 wt % and a temperature of above about 7° C., wherein the composition comprises a C15-18 internal olefin sulfonate; and (b) allowing the composition to interact with hydrocarbons in the hydrocarbon containing formation.

Abstract: Of the many compositions and methods provided herein, an example method includes a method of treating a subterranean formation that comprises combining components comprising water and a density-matched suspension to prepare a treatment fluid, wherein the density-matched suspension comprises a suspending liquid and a solid particle suspended in the suspending liquid, and introducing the treatment fluid into a well bore. An example composition includes a suspension that comprises a suspending liquid comprising a hydrophobic liquid, wherein the hydrophobic liquid hydrolyzes when placed in contact with an aqueous fluid to form hydrophilic products, and a solid particle suspended in the suspending liquid, wherein the suspension is a density-matched suspension.

Abstract: A method of cleaning a wellbore prior to the production of oil or gas is disclosed, wherein the wellbore has been drilled with an invert emulsion drilling mud that forms an invert emulsion filter cake. The method may include the steps of circulating a breaker fluid into the wellbore, where the breaker fluid includes an aqueous fluid, and imino diacetic acid or salt thereof. Optionally an acid buffering agent, and a weighting age are also included. The breaker fluid is formulated such that after a predetermined period of time and the filter cake present in the wellbore or on the wellbore face is substantially degraded. Other methods may also include drilling the wellbore with a water-based drilling mud that forms a water-based filter cake, wherein the method may include the steps of circulating a breaker fluid into the wellbore, where the breaker fluid may include an aqueous fluid, and an iminodiacetic acid or a salt thereof.

Abstract: Spray dried emulsifier compositions are described, which have desirable emulsifying and wetting characteristics. Among other advantages, the solid particulate emulsifier compositions greatly reduce transportation costs and simplify the logistics and environmental concerns associated with shipping large volumes of solvent-containing liquids. The emulsifier comprises (1) a carboxylic acid terminated fatty amine condensate or (2) a modified tall oil or (3) a blend of (1) and (2) that is converted to its alkali or alkaline earth metal salt and spray dried.

Abstract: A pill for wellbore operations, that includes a base fluid; and at least two polymers that interact to form a gelatinous structure characterized as isolating and controllably transmitting hydrostatic pressure between a first wellbore fluid above the pill in a wellbore and a second wellbore fluid below the pill in the wellbore is disclosed.

Abstract: Biphenylmono- and polysulphonic acids and salts thereof, fluorenemono- and polysulphonic acids and salts thereof as well as p-terphenylmono- and polysulphonic acids and salts thereof may be used successfully as tracers for surveying, monitoring and/or measuring movements of aqueous fluids in aqueous and/or non-aqueous media. Said substances are especially suited for surveying or monitoring movements of fluids in oil wells or reservoirs as well as for fluid movements in hydrothermal reservoirs.

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 of servicing a wellbore in a subterranean formation comprising placing a wellbore servicing fluid comprising a coupling agent, a hardenable resin and a hardening agent into the wellbore wherein the coupling agent comprises a multihydroxy phenyl, a dihydroxy phenyl, a trihydroxy phenyl, ascorbic acid, a hydroxymethylnaphthol, an oxidation product thereof, a derivative thereof, or combinations thereof. A wellbore servicing fluid comprising a coupling agent, a hardenable resin, a hardening agent and a proppant wherein the coupling agent comprises a multihydroxy phenyl, a dihydroxy phenyl, a trihydroxy phenyl, ascorbic acid, a hydroxymethylphenol, a hydroxymethylnaphthol, an oxidation product thereof, a derivative thereof, or combinations thereof.

Abstract: A method of converting an inactive biocide into an active biocide comprises: contacting the inactive biocide with an activating agent, wherein the activating agent is capable of chemically reacting with the inactive biocide; and causing or allowing a chemical reaction to take place between the inactive biocide and the activating agent, wherein the chemical reaction produces the active biocide. The methods can also include deactivating the active biocide via a chemical reaction between the active biocide and a deactivating agent.

Abstract: New hydrocarbon based slurry compositions and drilling, fracturing, completion and production fluids including the hydrocarbon based slurry composition are disclosed, where the composition includes a hydrocarbon soluble polymer adapted to decrease particle settling rates of particulate materials present in the fluids and in the case of fluids that include hydratable materials to increase hydration properties of such materials.

Abstract: This invention relates to compositions and methods of removing an organic deposit including introducing a fluid, wherein the fluid comprises at least two non-polar organic solvents and at least two polar organic solvents; allowing the fluid to dissolve at least a portion of the organic deposit; and removing at least a portion of the fluid. This invention relates to compositions and methods of removing an organic deposit including introducing a fluid, wherein the fluid comprises at least two non-polar organic solvents and at least two polar organic solvents, wherein the non-polar organic solvents comprise aromatic naphtha, terpenes, kerosene, and combination thereof, and wherein the polar solvents comprise heavy aromatic naphtha, cyclohexanone, N-2-methyl pyrrolidone, N-ethyl-2-pyrrolidone, and combination thereof, allowing the fluid to dissolve at least a portion of the organic deposit, and removing at least a portion of the fluid.

Abstract: The present invention includes compositions and methods for using an anionic surfactant composition for treating a hydrocarbon-bearing formation or a reservoir, of formula (I): wherein R1 and R2 are identical or different and may independently be alkyl, alkenyl, alkynyl, alkylene, aryl, propylene oxide, ethylene oxide or hydrogen groups in a straight or branched chain with 16 or more carbon atoms, X1 and X2 are identical or different and are selected from the group consisting of phosphate, sulfate, carboxylate, sulfonate or other suitable anionic groups, S is a spacer group selected from short or long arkyl, alkenyl, alkynyl, alkylene, stilbene, polyethers, and other suitable aliphatic or aromatic groups comprising 2 to 12 carbon atoms.

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 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: A method of cleaning a wellbore prior to the production of oil or gas, wherein the wellbore has been drilled with an invert emulsion drilling mud that forms an invert emulsion filter cake is disclosed. The method may include circulating a breaker fluid into the wellbore, where the breaker fluid includes a non-oleaginous internal phase and an oleaginous external phase, where the non-oleaginous phase includes a water soluble polar organic solvent, a hydrolysable ester of a carboxylic acid, and a weighting agent, and the oleaginous external phase includes an oleaginous fluid and an emulsifier, and where the hydrolysable ester is selected so that upon hydrolysis an organic acid is released and the invert emulsion of the filter cake breaks.

Abstract: A method of cleaning a wellbore prior to the production of oil or gas is disclosed, wherein the wellbore has been drilled with an invert emulsion drilling mud that forms an invert emulsion filter cake. The method may include the steps of circulating a breaker fluid into the wellbore, where the breaker fluid includes an aqueous fluid, a water soluble polar organic solvent, a hydrolysable ester of a carboxylic acid, and a weighting age, and where the hydrolysable ester is selected so that upon hydrolysis an organic acid is released and the invert emulsion of the filter cake breaks.

Abstract: A non-aqueous wellbore servicing fluid comprising a fluid loss additive wherein the fluid loss additive comprises the reaction product of (i) a functional polymer and (ii) an oligomerized fatty acid. A method of conducting an oil-field operation comprising placing a non-aqueous wellbore servicing fluid downhole wherein the non-aqueous wellbore servicing fluid comprises a fluid loss additive comprising the reaction product of (i) a functional polymer and (ii) an oligomerized fatty acid.

Abstract: Processes for producing alkyl esters useful as base fluids in oil-based mud compositions. The alkyl esters are produced from raw material waste oil that include vegetable oil. The raw material waste oil can be obtained from the food industry, such as from food chains. The raw material waste oil is purified by removing impurities from it. The raw material waste oil is then esterified with an alcohol in the presence of a catalyst. The resulting alkyl ester products are then separated from triglycerides. The alkyl ester products are then washed and dried.

Abstract: Emulsions for use in a well including: (a) a water-insoluble resinous material; (b) water; and (c) an emulsifier, wherein the emulsifier comprises a non-ionic, a cationic, or a zwitterionic emulsifier; wherein the continuous phase of the emulsion comprises the water; wherein a dispersed phase of the emulsion comprises the resinous material; wherein the dispersed phase is in the form of droplets having a size distribution range such that at least 50% of the droplets have a size of 0.5 micrometers-500 micrometers; wherein the resinous material of the droplets is in a concentration of at least 5% by weight of the water; and wherein the composition of the droplets has a viscosity of less than 2,000 Poise measured at 20° F. Methods include the steps of: (a) forming an emulsion described above; and (b) introducing the emulsion into a portion of a subterranean formation.

Abstract: A grouting composition for use in insulating a portion of a tubular located inside an enclosed conduit comprises: (A) an oil-swellable binding material comprising a organophilic clay; and (B) a hydrocarbon liquid, wherein the hydrocarbon liquid is the continuous phase of the grouting composition; and (C) an insulating material comprising a hollow microsphere, wherein after the grouting composition has set, the grouting composition has a thermal conductivity of less than 0.3 BTU/hr·ft·° F.

Abstract: A well treatment fluid and method of use includes water, at least one hydratable polymer, an optional crosslinking agent, and a delayed release percarbonate formulation effective to reduce initial viscosity of the fluid after a period of time. Also disclosed are processes for fracturing a subterranean formation.

Abstract: The present invention relates to methods and compositions for treating a water- and hydrocarbon-producing subterranean formation with a relative permeability modifier, and more specifically, to improved treatment fluids, methods for preparing treatment fluids, and methods for use thereof in a subterranean formation. Methods of the present invention comprise providing a treatment fluid comprising a relative permeability modifier, at least one surfactant, and an aqueous phase base fluid; and placing the treatment fluid in a subterranean formation. The relative permeability modifier comprises a hydrophobically modified hydrophilic polymer. The at least one surfactant is operable to maintain the relative permeability modifier in a dissolved state in the treatment fluid above a pH of about 8.

Abstract: Additives and treatment fluids with improved shale inhibition, and associated methods of use in subterranean operations, are provided. The additives and treatment fluids used generally comprise a shale-inhibiting component and one or more silicates.

Abstract: The use of a solvent for bitumen extraction, either from mined oil sands or in situ. The solvent includes (a) a polar component, the polar component being a compound comprising a non-terminal carbonyl group; and (b) a non-polar component, the non-polar component being a substantially aliphatic substantially non-halogenated alkane. The solvent has a Hansen hydrogen bonding parameter of 0.3 to 1.7 and/or a volume ratio of (a):(b) in the range of 10:90 to 50:50.

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: Guard bed compositions for protecting metal surfaces in a wellbore from corrosion may comprise a variety of constituent components. Exemplary guard bed compositions may include: one or more surfactants selected from the group comprising amine surfactants; one or more co-surfactants selected from the group comprising C3 to C15 alcohols; and one or more non-surfactant amines. Other exemplary guard bed compositions may comprise: a hydrocarbon fluid and an overbased detergent. Still other exemplary guard bed compositions may comprise: a hydrocarbon fluid; one or more surfactants; one or more co-surfactants; and one or more non-surfactant amines. The one or more surfactants may be selected from the group comprising alkyl alkoxylated surfactants. Still further, exemplary guard bed compositions may comprise: a hydrocarbon fluid and one or more associating surface active polymers selected from the group comprising amphiphilic polymers.

Abstract: According to one aspect of the inventions, emulsion compositions are provided. Emulsions according to this aspect include: (a) a water-insoluble resinous material; (b) water; and (c) an emulsifier, wherein the emulsifier comprises a non-ionic, a cationic, or a zwitterionic emulsifier; wherein the continuous phase of the emulsion comprises the water; wherein a dispersed phase of the emulsion comprises the resinous material; wherein the dispersed phase is in the form of droplets having a size distribution range such that at least 50% of the droplets have a size of 0.5 micrometers-500 micrometers; wherein the resinous material of the droplets is in a concentration of at least 5% by weight of the water; and wherein the composition of the droplets has a viscosity of less than 2,000 Poise measured at 20° F. According to another aspect of the inventions, methods are provided for treating a portion of a subterranean formation.

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: A method and apparatus for treating a subterranean formation traversed by a wellbore including forming an emulsion comprising oil, acid, and particulate, wherein the forming the emulsion is prepared on the fly, and introducing the emulsion into a wellbore.

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 making a styryl phenol alkoxylate sulfate surfactant by alkoxylation of a styryl phenol using propylene oxide (PO) and/or ethylene oxide (EO) followed by a sulfation reaction. The styrylphenol alkoxylate sulfate surfactant of the present invention is made by a facile and inexpensive method. The large hydrophobe surfactants of the present invention find uses in EOR applications where it is used for solubilization and mobilization of oil optionally containing asphaltene, and for environmental cleanup. Further, the unsulfated version of the large hydrophobe styrylphenol alkoxylate surfactant of the present invention can be used as an ultra-high molecular weight non-ionic surfactant.

Abstract: Gelled liquid hydrocarbons and methods for gelling hydrocarbons and treating subterranean wellbores employ a phosphorus compound of the formula: wherein, X is a straight chained alkyl or alkoxy group having 5 to 18 carbon atoms in combination with a polyvalent metal source.

Abstract: One or more compositions and methods for inhibiting the formation of hydrate agglomerates in a fluid that contain a specified generic formula are disclosed. The fluid can be contained in an oil or gas pipeline or refinery.

Abstract: One or more compositions and methods for inhibiting the formation of hydrate agglomerates in an aqueous medium that contain a specified generic formula are disclosed. The aqueous medium can be contained in an oil or gas pipeline or refinery.

Abstract: A method is provided for enhancing the shear stability of a high-viscosity fluid-water flow system, such as a core annular flow system. The method employs a family of demulsifier additives for maintaining separation of the fluids in biphasic flow. The additive family is sodium salts of polynuclear aromatic sulfonic acids. In one aspect, the high-viscosity fluid is heavy oil. A method of transporting heavy oil through a tubular body is also provided. The method includes pumping the heavy oil through the tubular body within an annular flow of water, and subjecting the water in the tubular body to a salt of a polynuclear, aromatic sulfonic acid additive so as to improve shear stability of the heavy oil and water.

Abstract: A water-based polymer drilling fluid, containing effective quantities of surfactants having HLB numbers equal to or greater than approximately 7, emulsifies oil and bitumen contained in oil sand cuttings, resulting in the oil and bitumen being dispersed into the mud as an emulsion. This eliminates or significantly reduces the ability of the oil, bitumen, and cuttings to clog the well or stick to drill string components when drilling a well through oil-bearing sands, particularly sands containing highly viscous oil or bitumen. The emulsification process separates the sand particles from the oil and bitumen, such that the sand particles can be removed when the mud is run through a conventional shale shaker or other suitable apparatus.

Abstract: Methods of using relative permeability modifiers for the diversion of aqueous fluids during subterranean operations are provided. An embodiment of the present invention provides a method of diverting fluids in a subterranean formation that may comprise providing a treatment fluid comprising an aqueous fluid and a relative permeability modifier that comprises water-soluble polymer with hydrophobic or hydrophilic modification; introducing the treatment fluid into a well bore that penetrates the subterranean formation; and 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 or another aqueous treatment fluid to another portion of the subterranean.

Abstract: Spray dried emulsifier compositions are described, which have desirable emulsifying and wetting characteristics. Among other advantages, the solid particulate emulsifier compositions greatly reduce transportation costs and simplify the logistics and environmental concerns associated with shipping large volumes of solvent-containing liquids. The emulsifier comprises (1) a carboxylic acid terminated fatty amine condensate or (2) a modified tall oil or (3) a blend of (1) and (2) that is converted to its alkali or alkaline earth metal salt and spray dried.

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: A method for sealing a subterranean zone is disclosed. The method includes the steps of preparing a wellbore fluid, placing the wellbore fluid into at least a portion of an annular space between the sidewalls of a wellbore and the exterior of a casing string disposed in the wellbore, and allowing the wellbore fluid to solidify therein, wherein the wellbore fluid includes an oleaginous fluid as the continuous phase of the wellbore fluid, a non-oleaginous fluid as the discontinuous phase of the wellbore fluid, and about 5 to about 50 pounds per barrel of a thermally activated hydrocarbon gellant.

Abstract: A method of heterogeneous proppant placement in a subterranean fracture is disclosed. The method comprises injecting well treatment fluid including proppant and a channelant through a wellbore into the fracture, heterogeneously placing the proppant in the fracture in a plurality of proppant clusters or islands spaced apart by the channelant, and removing the channelant filler material to form open channels around the pillars for fluid flow from the formation through the fracture toward the wellbore. The proppant and channelant can be segregated within the well treatment fluid, or segregated during placement in the fracture. The channelant can be dissolvable particles, initially acting as a filler material during placement of the proppant, and later dissolving to leave the flow channels between the proppant pillars. The well treatment fluid can include fibers to provide reinforcement and consolidation of the proppant and/or to inhibit settling of the proppant in the treatment fluid.

Abstract: A wellbore fluid that includes an oleaginous continuous phase; a non-oleaginous phase; and a polymeric additive formed by mixing at least one lipophilic monomer and at least one crosslinking agent, wherein the at least one lipophilic monomer is at least one of an epoxide-functionalized derivative of at least one selected from soybean oil, linseed oil, rapeseed oil, cashew nut shell oil; perilla oil, tung oil, oiticia oil, safflower oil, poppy oil, hemp oil, cottonseed oil, sunflower oil, high-oleic triglycerides, triglycerides of euphorbia plants, peanut oil, olive oil, olive kernel oil, almond oil, kapok oil, hazelnut oil, apricot kernel oil, beechnut oil, lupine oil, maize oil, sesame oil, grapeseed oil, lallemantia oil, castor oil, herring oil, sardine oil, menhaden oil, whale oil, tall oil, and synthetic aliphatic or aromatic ethers, and the at least one crosslinking agent includes at least one selected from amines, alcohols, phenols, thiols, carbanions, carboxylates, and mixtures thereof is disclosed.

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.