Abstract: A method for affecting the viscosity of an aqueous fluid gelled with a VES includes providing an aqueous fluid and adding to the aqueous fluid, in any order: at least one VES comprising a non-ionic surfactant, cationic surfactant, amphoteric surfactant or zwitterionic surfactant, or a combination thereof, in an amount sufficient to form a gelled aqueous fluid comprising a plurality of elongated micelles, a glyceride oil comprising a fatty acid, and a plurality of metallic particles to produce a mixture comprising dispersed metallic particles. The method also includes dissolving at least a portion of the metallic particles in the aqueous fluid to provide a compound comprising a metallic base and forming in situ a soap reaction product of the fatty acid with the compound, wherein the soap reaction product is present in an amount effective to increase, decrease, or increase and then decrease a viscosity of the gelled aqueous fluid.

Abstract: Aqueous treating fluids may include a viscoelastic surfactant (VES) and an aqueous base fluid, e.g. a drilling fluid, whereby the VES may increase and/or maintain the viscosity of the aqueous treating fluid. Metal ions may be present within the aqueous treating fluid that break, reduce, and/or digest the VES within the aqueous treating fluid. An effective amount of complexation particles may be added to the aqueous treating fluid for complexing at least a portion of these metal ions and thereby disallowing the metal ions from breaking, reducing, and/or altering the VES within the aqueous treating fluid.

Abstract: Water-based drilling mud lubricants using a blend of fatty acid polyamine salts and fatty acid esters give synergistically better lubricity results than either component used separately. For example, the blends with different ratios of fatty acid diethylenetriamine salt and fatty acid methyl ester demonstrate much better lubricity in water-based drilling fluids than those where only fatty acid diethylenetriamine salt or fatty acid methyl ester are separately used. The amines in fatty acid amine salt might also include other polyamines, such as butanediamine pentamethylenediamine, spermidine, spermine, propylene diamine and propylene polyamines. The fatty acid esters might also include fatty acid ethyl ester, fatty acid glycerol ester and fatty acid trimethylolpropane ester. The carbon numbers of the fatty acids used to make the components in the lubricant blend may range from C4 to C28.

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: 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: 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: 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: 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: 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: The present disclosure relates to a biodegradable lubricant composition, notably intended to be incorporated as an oil phase with high lubricating power in a drilling fluid or mud. This composition may be in a drilling fluid or as a fluid for fracture of underground formations. These muds or fluids contained in the composition of the present disclosure are particularly suitable for very deep drillings, offshore in deep water and/or sidetracked drillings or with a long shift.

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 subterranean treatment fluid comprising a degradable gemini surfactant composition described by the following formula: A and A? are spacers that may be a hydrophobic group or a hydrophilic group. B is an ion and may contain a quaternary nitrogen, a sulfonate, or a phosphate. A, A?, B, B?, C, C, E and E? may be an alkyl, an aryl, a sugar, an ester, an ether, and any combination thereof. D and D? may be an aryl, a sugar, an ester, an ether, and any combination thereof. In some cases, A?, D?, and E? may be optional.

Abstract: Embodiments disclosed herein relate to gels for use in downhole applications containing the reaction product of at least one polymer, or polymer precursor, and at least one oxazoline crosslinking agent, wherein the at least one polymer, or polymer precursor, and the oxazoline crosslinking agent are normally combined in a solution, and methods including the use thereof.

Abstract: Water flood materials may contain an effective amount of a nano-sized particulate additive to inhibit or control the movement of fines within a subterranean formation during a water flood secondary recovery operation. The particulate additive may be an alkaline earth metal oxide, alkaline earth metal hydroxide, alkali metal oxide, alkali metal hydroxide, transition metal oxide, transition metal hydroxide, post-transition metal oxide, post-transition metal hydroxide, piezoelectric crystal, and/or pyroelectric crystal. The particle size of the magnesium oxide or other agent may be nanometer scale, which scale may provide unique particle charges that help control and stabilize the fines, e.g. clays.

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: 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: Fluids viscosified with viscoelastic surfactants (VESs) may have their viscosities affected (increased or reduced, e.g. gels broken) by the indirect or direct action of a composition that contains at least one fatty acid that has been affected, modified or reacted with an alkali metal base, an alkali earth metal base, ammonium base, and/or organic base compound, optionally with an alkali metal halide salt, an alkali earth metal halide salt, and/or an ammonium halide salt. The composition containing the resulting saponification product is believed to either act as a co-surfactant with the VES itself to increase viscosity and/or possibly by disaggregating or otherwise affecting the micellar structure of the VES-gelled fluid. In a specific, non-limiting instance, a brine fluid gelled with an amine oxide surfactant may have its viscosity broken with a composition containing naturally-occurring fatty acids in canola oil or corn oil affected with CaOH, MgOH, NaOH and the like.

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: A method of servicing a wellbore comprising placing a composition comprising a surfactant, brine, an oleaginous fluid, and optionally a co-surfactant in an annular space of the wellbore, wherein the composition forms a microemulsion under low shear conditions.

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: 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: 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 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.

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: The present invention provides hydrocarbon-based fracturing fluid compositions comprising a hydrocarbon fluid, proppant, and a small amount of water, and methods of using same. The small amount of water, preferably present at a concentration ranging from about 0.1% to about 5%, causes water bridging between the proppant particulates, causing the proppant particles to agglomerate. The compositions are useful in mitigating proppant flowback in hydraulic fracturing operations and are useful in isolating one or more zones in vertical as well as horizontal wells having multiple pay zones.

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: Methods and compositions that include a method comprising: providing a treatment fluid comprising at least a plurality of degradable diverting agents that comprise at least one degradable material selected from the group consisting of a fatty alcohol, a fatty acid salt, a fatty ester, a proteinous material, and a combination thereof; and introducing the treatment fluid into a subterranean formation during a subterranean operation via a well bore.

Abstract: A sand slurry composition and a method for making sand slurries are disclosed. The sand slurry composition is comprised of sand, an aqueous liquid and a chemical compound that renders the surface sand of hydrophobic. The method is comprised of rendering sand surface hydrophobic during or before making the slurry. This method and composition can find many applications in different industries, especially in various oil field applications.

Abstract: Fluids viscosified with viscoelastic surfactants (VESs) may have their viscosities reduced (gels broken) by the direct or indirect action of a synergistic internal breaker composition that contains at least one first internal breaker that may be a mineral oil and a second breaker that may be an unsaturated fatty acid. The internal breakers may initially be dispersed oil droplets in an internal, discontinuous phase of the fluid. This combination of different types of internal breakers break the VES-gelled aqueous fluid faster than if one of the breaker types is used alone in an equivalent total amount.

Abstract: Using a complex emulsion for treating a subterranean formation, such as to dissolve minerals therein (e.g. carbonates, scales, and/or filter cake) to improve permeability, substantially improves post treatment fluid clean-up for improved hydrocarbon production. The complex emulsion is made by mixing an acid aqueous phase with an oil external microemulsion to give an initial product, where the acid aqueous phase is an external phase and the microemulsion is an internal phase. Then the initial product is mixed with a second oil (e.g. xylene, diesel, toluene, kerosene, other aromatics, refined hydrocarbons and the like) containing an emulsifier to make a complex emulsion.

Abstract: In hydrocarbon recovery applications, viscoelastic surfactant (VES) gelled fluids may be preheated to a temperature that will increase viscosity of the VES gelled fluid. The preheated VES gelled fluid retains at least a portion of its preheated viscosity when cooled such as by introduction into a low temperature condition. In an embodiment, the VES gelled fluid may be a drilling fluid, completion fluid, or fracturing fluid, and the low temperature condition may be an offshore operation, an operation in a locality having a cold climate, and/or a shallow oil, gas, or both land-based operation where the formation temperature is 120° F. or less. The surfactant in the VES gelled fluid may be one or more of an amine, amine salt, quaternary ammonium salt, betaine, amidoamine oxide, amine oxide, and combinations thereof.

Abstract: Fluids viscosified with viscoelastic surfactants (VESs) may have their viscosities affected (increased or reduced) by the indirect or direct action of a composition that contains at least one fatty acid that has been affected, modified or reacted with an alkali metal halide salt, an alkaline earth metal halide salt, and/or an ammonium salt and a water soluble base. The composition containing the resulting saponification product is believed to either act as a co-surfactant with the VES itself to increase viscosity and/or possibly by disaggregating or otherwise affecting the micellar structure of the VES-gelled fluid. In a non-limiting instance, a brine fluid gelled with an amine oxide surfactant has its viscosity broken with a composition containing naturally-occurring fatty acids in canola oil reacted with a water soluble base such as NaOH, KOH, NH4OH, and the like with an alkali halide salt such as CaCl2, MgCl2, NaCl, NH4Cl and the like.

Abstract: This invention relates to compositions and methods for treating subterranean formations, in particular, oilfield stimulation compositions and methods using water-in-water polymer emulsions to uniformly dissolve a rheologically active polymer, such as a thickener or friction reducer, in the treatment fluid. The emulsions have a low viscosity and are easily pumped for mixing into a treatment fluid, where upon dilution with an aqueous medium, the polymer is easily hydrated without forming fish-eyes. The partitioning agent in the water-in-water emulsion does not generally affect the rheology of the treatment fluid. The invention also relates to further processing of the emulsion by wet grinding, high shear mixing and/or heating to enhance the hydration rate in the preparation of the well treatment fluid.

Abstract: In one embodiment, the present invention provides a drilling fluid composition that comprises a surfactant-free emulsion comprising an oleaginous fluid, a fluid that is at least partially immiscible with the oleaginous fluid, and a non-surfactant polymeric emulsifier. In another embodiment, the present invention provides a method of treating a subterranean formation comprising providing a treatment fluid that comprises a surfactant-free emulsion, the surfactant-free emulsion comprising an oleaginous fluid, a fluid that is at least partially immiscible with the oleaginous fluid, and a non-surfactant polymeric emulsifier; and treating the subterranean formation.

Abstract: A non-toxic, environmentally friendly, green flowback aid is disclosed that reduces water blockage when injected into a fractured reservoir. The composition includes an water soluble ester of a low molecular weight alcohol and a low molecular weight organic acid, an oil soluble ester of a low molecular weight alcohol and a high molecular weight fatty acid, one or more water soluble or dispersible nonionic surfactant(s) derived from vegetable or animal sources, one or more anionic or amphoteric surfactant(s) derived from animal or vegetable based sources, and, water. Compositions for low temperature applications are also disclosed that can remain fluid down to ?41 ° F.

Abstract: An aqueous fluid system that contains an aqueous dicarboxylic acid solution, a viscoelastic surfactant as a gelling agent to increase the viscosity of the fluid, and an internal breaker such as mineral oil and/or fish oil to controllably break the viscosity of the fluid provides a self-diverting acid treatment of subterranean formations. The internal breaker may be at least one mineral oil, a polyalphaolefin oil, a saturated fatty acid, and/or is an unsaturated fatty acid. The VES gelling agent does not yield viscosity until the organic acid starts to spend. Full viscosity yield of the VES gelling agent typically occurs at about 6.0 pH. The internal breaker allows the VES gelling agent to fully viscosify the spent organic acid at 6.0 pH and higher, but as the spent-acid VES gelled fluid reaching reservoir temperature, controllable break of the VES fluid viscosity over time can be achieved.

Abstract: Disclosed is a method for introducing additives into formation fluid from an oil and gas well in or moving through equipment and systems located downstream from the oil and gas well. The method is practiced using pellets having a density sufficient to suspend the pellet at an interface of two phases of fluid within the Downstream Equipment. The pellets are prepared from a pellet matrix, such as an ethoxylated wax, and, optionally, a weighting agent as well as an additive. By varying the amount of weighting agent, the density of the pellet can be varied to suspend it at a desired point for a time sufficient to deliver the additive to the desired point within the Downstream Equipment. The method of the invention may also be used with Refinery Equipment such as a fuel distribution system or a waste water treatment system.

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 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: A process for making a coated substrate that includes treating a proppant with a coating agent, wherein the coating agent comprises at least one of monomeric alpha-hydroxycarboxylic acids, alpha-hydroxycarboxylic acid polymers, and combinations thereof, reacting the treated proppant to form a polymer coated proppant, and recovering the polymer coated proppant is disclosed.

Abstract: A method of servicing a wellbore comprising placing a composition comprising a surfactant, brine, an oleaginous fluid, and optionally a co-surfactant in an annular space of the wellbore, wherein the composition forms a microemulsion under low shear conditions.

Abstract: A method comprising contacting a zwitterionic surfactant, co-surfactant, and water to form a microemulsifier, and contacting the microemulsifier with an oleaginous fluid under low shear conditions to form a microemulsion. A method comprising introducing a first wellbore servicing fluid comprising at least one oleaginous fluid into a wellbore, wherein the first wellbore servicing fluid forms oil-wet solids and/or oil-wet surfaces in the wellbore, and contacting the oil-wet solids and/or oil-wet surfaces in the wellbore with a second wellbore servicing fluid comprising a zwitterionic surfactant, a co-surfactant, and a brine to form a microemulsion.

Abstract: A substantially liquid gellant formed as one or more reaction products of a metal carboxylate or metal carboxylate amine salt, one or more organic acids, an ester which drives the reaction so that the reaction products are asymmetrical in structure, and a rheology modifier which preferentially interacts between the reaction products for prevent solidifying of the gellant reaction products until such time as the gellant is mixed with the fracturing fluid containing an activator after which the reaction products preferentially interact with the activator to gel the fracturing fluid. The resulting gellant is capable of gelling a hydrocarbon base fluid in less than about 30 seconds.

Abstract: The invention relates to a concentrate for the effective, environmentally friendly treatment of oil-polluted stretches of ground and the cleaning of oil-contaminated surfaces, said concentrate containing an emulsifier, a vegetable oil and ethanol. The emulsifier is preferably a non-ionic surfactant with an HLB value between 7 and 8. The vegetable oil is preferably selected so that it is liquid at temperatures above 5 DEG C. Oils containing unsaturated fatty acids, in particular germ oils are especially suitable. For its application as a treatment for stretches of ground, the inventive concentrate is diluted with water to form a cleaning solution and is applied to the oil-contaminated surface that is to be treated. The oil is emulsified in the inventive cleaning solution and is detached from the particles of the ground. The oil degrades in a significantly easier manner in the emulsified state. To clean oil-contaminated surfaces, the cleaning solution is sprayed onto the latter.

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: Wellbore treatment kits are provide that include a polymeric solution for placement in a wellbore that penetrates a subterranean formation and an activator for causing a polymer to precipitate out of the polymeric solution when it contacts the polymeric solution, wherein the resulting precipitate is capable of at least partially blocking a flow of a wellbore servicing fluid into the subterranean formation. The wellbore servicing fluid may be, for example, a drilling fluid, a cement composition, a workover fluid, or combinations thereof. The polymeric solution may comprise, for example, a poly vinyl pyrrolidone aqueous solution, and the activator may comprise, for example, a formate brine. When desirable, the precipitate may be easily and quickly removed from the subterranean formation by dissolving it in fresh water.

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: Among many things, in some embodiments, improved viscoelastic surfactant gels that comprise non-aqueous tackifying agents, and their associated methods of use, are provided. In one embodiment, the methods comprise: providing a treatment fluid that comprises an aqueous base fluid, a non-aqueous tackifying agent, and a viscoelastic surfactant; and introducing the treatment fluid into a subterranean formation.