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: The present invention relates to bridging agents for use in subterranean formations, to well drill-in and servicing fluids comprising such bridging agents, and to methods of using such bridging agents and well drill-in and servicing fluids in subterranean drilling operations. An example of a well drill-in and servicing fluid of the present invention comprises a viscosified fluid, a fluid loss control additive, and a bridging agent comprising a degradable material.

Abstract: A method of fracturing a subterranean formation comprising at least in part shale formation, comprises providing a carrier fluid; providing a particulate blend including a first amount of particulates having a first average particle size between about 100 and 2000 microns and a second amount of particulates having a second average particle size between about three and twenty times smaller than the first average particle size, such that a packed volume fraction of the particulate blend exceeds 0.75; combining the carrier fluid and the particulate blend into a fracturing slurry; fracturing the formation with the fracturing slurry to create at least a fracture; and removing the second amount of particulates from the fracture.

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: 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: Disclosed herein are an acid emulsion fluid for use in sealing target portions of a hydrocarbon producing formation penetrated by a wellbore and the method of use thereof for fluid loss control.

Abstract: A method for replacing glycol-based mutual solvents in an oil field application comprising: obtaining an alternative solvent and solvent blends and replacing all or a portion a glycol-based mutual solvent, which forms a component of an oil field formulation, with the alternative solvent or solvent blends, wherein the oil field formulation can be utilized in an oil field application.

Abstract: Emulsified acids have been used to increase production rates of oil and gas in carbonate reservoirs through acid fracturing and matrix acidizing operations. An emulsifier is used to emulsify the aqueous acid with an oil, usually diesel. Very small particles, such as colloidal clay particles and/or nanoparticles increase the stability of the emulsified acids over an elevated temperature range.

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

Abstract: The 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: Of the many methods provided herein, one method of reducing the viscosity of a viscosified treatment fluid includes: providing a clean-up composition comprising a carboxylic acid; providing a chlorite-based breaker system; providing a viscosified treatment fluid; placing the viscosified treatment fluid in a subterranean formation via a well bore penetrating the subterranean formation; contacting the viscosified treatment fluid with the clean-up composition; contacting the viscosified treatment fluid with the chlorite-based breaker; and allowing the viscosity of the viscosified treatment fluid to reduce. Also provided herein are methods that include a method of reducing polymeric residue from a subterranean formation that includes: placing a clean-up composition and a chlorite-based breaker system in a subterranean formation in contact with an amount of polymeric residue; and allowing the amount of polymeric residue present in the formation to be reduced.

Abstract: Disclosed is a filter cake removal composition, and method of use thereof, for use in a wellbore for controlled removal of a filter cake present in a target production zone. The filter cake removal composition includes hydrochloric acid and an organic acid. The filter cake removal composition, when a mixture of the hydrochloric acid and the organic acid is applied to the filter cake in the target production zone, is operable to dissolve the filter cake in the target production zone over an extended reaction time. The mixture includes the hydrochloric acid present in an amount of between about 0.1% and 5% by weight and the organic acid present in an amount of between about 0.1% and 10% by weight.

Abstract: The present invention describes the synthesis and use of cleavable di-functional anionic surfactants for enhanced oil recovery applications and/or the use of sacrificial surfactants.

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: Described is an additive composition made up of at least one dibasic ester, at least one non-ionic surfactant, at least one terpene or terpene derivative and optionally, at least one polyalkylene glycol and/or water. The composition is useful as an additive for well treatment fluids used for cleaning or stimulation of oil or gas wells.

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: The present invention relates to compositions and methods for enhancing fracture conductivity. One embodiment of the present invention provides a method of providing a fracturing fluid and a flowable propping composition having a hardenable external phase and an internal phase where the internal phase is immiscible with the external phase; introducing the fracturing fluid into a subterranean formation; introducing the flowable propping composition into a fracture in the subterranean formation; allowing the hardenable external phase to form a hardened external phase in the fracture in the subterranean formation; and allowing the presence of the internal phase to be reduced from the hardened external phase thereby leaving a void volume in the hardened external phase.

Abstract: The invention relates to a class of novel surfactants that have utility in the recovery and/or extraction of oil.

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: 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: 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: A gas generating system for use in stimulation or in deliquification/dewatering includes a foam generating agent, a foam enhancing agent and a gas generating additive. The foam generating agent is absorbed or adsorbed on a first plurality of substrates and the foam boosting agent is absorbed or adsorbed on a second plurality of substrates. The gas generating additive preferably includes an acidic component contained within a releasing mechanism container and a carbonate or bicarbonate contained within a releasing mechanism container. The use of encapsulated substrate permits the staged and targeted delivery of treatment chemicals in fractures extending from the wellbore or in the wellbore itself.

Abstract: An acid treatment composition is provided including an alkyl sarcosinate as corrosion inhibitor and an optional corrosion inhibitor intensifier in an acidic solution. Methods for treating wells with these acid treatment compositions are also provided that help control corrosion of the alloy surfaces used in the wells during the acid treatment.

Abstract: A base fluid may contain nanoparticles where the base fluid may include a non-aqueous fluid, an aqueous fluid, and combinations thereof. The fluid may have a resistivity range of from about 0.02 ohm-m to about 1,000,000 ohm-m. The non-aqueous fluid may be a brine-in-oil emulsion, or a water-in-oil emulsion; and the aqueous fluid may be an oil-in-water emulsion, or an oil-in-brine emulsion; and combinations thereof. The addition of nanoparticles to the base fluid may improve or increase the electrical conductivity and other electrical properties of the fluid. The fluid may be a drilling fluid, a completion fluid, a production fluid, and/or a stimulation fluid.

Abstract: Methods and compositions for the treatment of subterranean formations, and more specifically, treatment fluids containing pumicite and methods of using these treatment fluids in subterranean formations, are provided. An example of a method is a method of displacing a fluid in a well bore. Another example of a method is a method of separating fluids in a well bore in a subterranean formation. An example of a composition is a spacer fluid comprising pumicite and a base fluid.

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: Soluble silicates are commonly used to block and strengthen permeable zones in subterranean formations. These applications include conformance for oil field, grouting for the construction industry and water shut-off for mining. It was discovered that set times and set properties could be improved by using novel, high ratio alkali silicates. Ratio being defined as the mol ratio of SiO2:Me2O, where Me is an alkali metal and is most commonly sodium or potassium (i.e. Na2O and K2O).

Abstract: A method for cleaning oil wells to increase the flow of oil thereof by use of a unique cleaning emulsion comprising of water, hydrocarbon solvent, terpene hydrocarbon material, demulsifier, detergent, and optionally an acid. This one step method provides for the simultaneously cleaning/removal of asphaltene and/or paraffin and scale at a wide range of temperatures. This method can be used alone or with the assistance of a wash tool which is a combination pressure and surge wash tool having a nipple assembly, or a hydro self-rotating nozzle wash tool.

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 water-based wellbore treatment fluid contains: one or more viscoelastic-gelling carboxylic acids and/or alkali metal salts thereof; and one or more solubilizing alkylolamines. The carboxylic acids and/or alkali metal salts and the alkylolamines are present in the fluid in respective amounts such that, at 25° C., the alkylolamines solubilize a sufficient portion of the carboxylic acids and/or alkali metal salts to render the fluid viscoelastic. A remaining portion of the carboxylic acids and/or alkali metal salts forms a suspension of solid particulates in the fluid.

Abstract: Methods of making a degradable ball composition comprising a carboxylic acid, a fatty alcohol, a fatty acid salt, a fatty ester, or a combination thereof comprising the steps of: forming a thermoplastic mass, and allowing the thermoplastic mass to cool as to form a degradable ball that is introduced in subterranean treatments by a carrier fluid.

Abstract: Techniques for preconditioning an oilfield reservoir including heavy oil and/or bitumen prior to production of a petroleum product are described. A preconditioning agent can be injected into a mobile water film included in the oilfield reservoir. The preconditioning agent preconditions the reservoir prior to production of the petroleum product.

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.

Abstract: The invention relates to a class of novel surfactants that have utility in the recovery and/or extraction of oil.

Abstract: Methods for using a microemulsion system are 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 instant invention pertains to a composition which may be useful for enhancing oil recovery. The composition typically comprises the reaction mixture of at least (a) two or more compounds capable of generating at least about 20 kcal to about 150 kcal per mole when contacted; (b) one or more suitable surfactants or one or more suitable polymers or a mixture thereof; and (c) oil. The invention also pertains to a method for enhancing oil recovery wherein a suitable system is injected through a wellbore into a reservoir to enhance mobility of oil.

Abstract: Disclosed herein is a well treatment fluid comprising an aqueous solution comprising greater than or equal to about 1 wt % boron, at least 5 wt % of a co-solvent, and greater than or equal to about 5 wt % sodium hydroxide, potassium hydroxide, or a combination thereof, wherein the co-solvent comprises glycerol, ethylene glycol, propylene glycol, or a combination thereof. Methods of using the well treatment fluid are also disclosed.

Abstract: Surfactant based viscoelastic fluids for enhancing the productivity of a hydrocarbon-bearing formations have particular applicability in acid fracturing of subterranean formations surrounding oil and gas wells. The viscoelastic fluid contains an organic acid, an inorganic monovalent salt and a quaternary ammonium aromatic salt and water. The fluid may further be foamed or energized.

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: The present invention describes the use of EDTA and/or alkali treated hard brine at high pH for making ASP formulations for EOR applications.

Abstract: Viscoelastic surfactant (VES) gelled aqueous fluids containing water, a VES, an internal breaker, a VES stabilizer, a fluid loss control agent and a viscosity enhancer are useful as treating fluids and particularly as fracturing fluids for subterranean formations. These VES-based fluids have faster and more complete clean-up than polymer-based fracturing fluids. The use of an internal breaker permits ready removal of the unique VES micelle based pseudo-filter cake with several advantages including reducing the typical VES loading and total fluid volume since more VES fluid stays within the fracture, generating a more optimum fracture geometry for enhanced reservoir productivity, and treating reservoirs with permeability above the present VES limit of approximately 400 md to at least 2000 md.

Abstract: This invention relates to the use of degradable fibers, and more particularly, to self-degrading fibers and their associated methods of use and manufacture. In one embodiment, the present invention provides a self degrading fiber comprising: an outer shell, and a core liquid.

Abstract: Systems and methods for processing glycerol into one or more useful products are provided. The method can include decreasing a pH of a mixture comprising glycerol and fatty acids to produce an emulsion comprising a glycerol-rich portion and a fatty acids-rich portion. At least a portion of the glycerol-rich portion can be reacted with at least one of an oxidant and a catalyst at conditions sufficient to produce a reacted product comprising glyceric acid, oxalic acid, glycolic acid, formic acid, or any combination thereof.

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.

Abstract: Of the many methods provided herein, an example is a method including: providing a treatment fluid that comprises: an aqueous base fluid; a hydrofluoric acid source selected from the group consisting of hydrofluoric acid, a hydrofluoric acid generating compound, and a combination thereof; and a biodegradable chelating agent comprising one of the following selected from the group consisting of: glutamic acid diacetic acid, a glutamic acid diacetic acid salt, a derivative thereof, and a combination thereof; and introducing the treatment fluid into at least a portion of a subterranean formation.

Abstract: In one embodiment, the present invention provides a fluid comprising: an aqueous base fluid; and a gelling agent that comprises a polymerizable polycarboxylic acid and that is at least partially crosslinked by a crosslinking reaction comprising a crosslinking agent.

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.