Abstract: The invention discloses a method of controlling fluid loss from a subterranean formation of a well bore. In a first aspect, the method is done by providing a treatment fluid made of an aqueous fluid and a hydrophobic polymer; and introducing the treatment fluid into the wellbore. In a second aspect, the method is done by providing a treatment fluid made of water and a water soluble polymer; providing in the treatment fluid a fluid loss additive having a hydrophobic polymer; using the treatment fluid in a well bore of a subterranean formation; allowing the treatment fluid to establish a permeable filter cake with the water soluble polymer in at least a portion of the well bore; and allowing hydrophobic polymer to enter into the filter cake to reduce permeability of the filter cake.

Abstract: An aqueous fluid having a viscosity greater than the viscosity of water is contacted with a water soluble material for a time and at a temperature sufficient to reduce the viscosity of the aqueous fluid to a value which is less than about 10 percent of the initial viscosity of the aqueous fluid. The water soluble material is an alkali metal peroxide or a combination of an alkali metal peroxide and a transition metal-containing compound.

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.

Abstract: The invention discloses a well treatment composition for use in a subterranean formation comprising: a carrier fluid; and a viscoelastic surfactant being present in a concentration of less than about 1.5% by weight. Optionally, the fluid comprises a crosslinked polymer in a thickening amount in the carrier fluid. The invention also discloses a method to increase the viscosity of a fluid, the method comprising: providing a fluid comprising a thickening amount of a crosslinked polymer; adding a viscoelastic surfactant at a given concentration to the fluid; taking the fluid to a given temperature; defining a viscosity profile of the fluid depending of the concentration and the temperature; comparing said viscosity profile to a viscosity profile of the crosslinked polymer fluid alone; and defining an optimum concentration of the viscoelastic surfactant for each temperature.

Abstract: Embodiments of this invention relate to a composition and a method for tailoring the rheology of a fluid for use in the oil field services industry including forming a fluid comprising a tetrakis(hydroxyalkyl) phosphonium salt and a polymer, and exposing the fluid to a temperature of about 20° C. to about 200° C., wherein a viscosity is observed that is at least about 5 percent different than if no salt were present. Embodiments of this invention also relate to a composition and a method for tailoring the rheology of a fluid for use in the oil field services industry including forming a fluid comprising a tetrakis(hydroxyalkyl) phosphonium salt and diutan and/or guar and/or guar derivatives and/or a combination thereof, and exposing the fluid to a temperature of about 20° C. to about 163° C., wherein a viscosity is observed that is at least about 5 percent lower than if no salt were present.

Abstract: Treatment fluids are provided that include a treatment fluid comprising a base fluid and a gelling agent that comprises clarified diutan. In some embodiments, the treatment fluid is a subterranean treatment fluid. In some embodiments, the treatment fluid is a subterranean treatment fluid comprising a base fluid, a gelling agent that comprises clarified diutan, and at least a plurality of particulates. Additional treatment fluids are also provided.

Abstract: A well stimulation fluid includes water, a polymer, and a biocide consisting of 3,5-dimethyl-1,3,5-thiadiazinane-2-thione in an amount effective to inhibit bacterial growth.

Abstract: Additives that may be useful in preventing fluid loss in certain subterranean formations and associated methods of use are provided. In one embodiment, the methods of the present invention comprise: providing a low molecular weight crosslinkable polymer and a crosslinking agent capable of crosslinking the low molecular weight crosslinkable polymer; and introducing the low molecular weight crosslinkable polymer and the crosslinking agent into at least a portion of a subterranean formation.

Abstract: A well treatment composition is formed from an aqueous crosslinkable hydrated polymer solution. Combined with the polymer solution is a solid boric acid or borate crosslinking agent and a solid metal oxide or metal hydroxide pH buffering agent that has limited solubility (less than 100 kg/m3 at 20° C.) within the polymer solution that provides the solution with a pH of from about 8 to about 11. The composition may be introduced into a subterranean formation through a wellbore that penetrates the formation. The composition may provide at least one of shortened shear recovery time and an increase in the thermal stability of the aqueous polymer solution.

Abstract: A method of treating a subterranean formation, comprising: at least partially coating particulates with a first layer of a first curable resin and allowing the first curable resin to substantially cure; and then, at least partially coating the particulates with a second layer of a second curable resin; and allowing the second layer of the second curable resin to substantially cure; and then, slurrying the coated particulates into a treatment fluid and placing the slurry into a subterranean formation. Improved particulates suitable for use in subterranean formations, comprising low-quality particulates that have been at least partially coated with a first layer of a first curable resin and then at least partially coated with a second layer of a second curable resin and wherein the first layer of the first curable resin is allowed to substantially cure before the application of the second layer of the second curable resin.

Abstract: A method of making phenol and alkylphenol ethoxylates non-estrogenic by inserting 1 mole of propylene oxide onto the phenolic group before proceeding with the addition of ethylene oxide or mixtures of ethylene and propylene oxide. The final phenolic products can be further reacted to form sulfates, sulfonates, phosphate esters, condensed alkylphenol alkoxylates and other derivatives of alkylphenol or phenol. Non-estrogenic phenol and alkylphenol alkoxylates and their derivatives have been found to be excellent salt tolerant, high temperature stable surfactants for oil recovery from subterranean reservoirs. These products are also useful in forming emulsions of heavy crude for transportation through pipelines.

Abstract: A non-aqueous, non-flammable Group IVB metal alkoxide crosslinker composition includes a non-aqueous, non-flammable Group IVB metal alkoxide, wherein the metal is chemically bonded to a glycol containing 4 or more carbons, to an alkoxy group containing 6 or more carbons, or a mixture of both. A fracturing fluid employed in the hydraulic fracturing of subterranean formations is formulated through mixture of the non-aqueous, non-flammable Group IVB metal alkoxide crosslinker composition with a polymer solution.

Abstract: A viscoelastic composition containing an effective amount of at least one cationic carbohydrate ether having one or more cationic fragments and one or more carbohydrate fragments connected through one or more linker fragments for controlling the viscoelasticity of the composition, wherein at least some carbohydrate fragments are connected to the linker fragments through ether bonds. The viscoelastic composition of the present technology may be used to alter fluid rheology and impart both viscous and elastic properties to the treated fluids. Applications of the viscoelastic composition of the present technology include, but are not limited to, oil field fluids such as, for example, well bore treatment fluids.

Abstract: A method of treating a subterranean formation includes pumping into a cased, perforated wellbore that intersects the formation an invert emulsion kill fluid, the invert emulsion kill fluid comprising: an oleaginous continuous phase; a non-oleaginous discontinuous phase; an emulsifier; at least one degradable material; and at least one bridging material; contacting the formation with the kill fluid; and allowing the degradable material to at least partially degrade.

Abstract: A method and a composition for stimulating oil production from wells which have ceased production by pumping in a mixture of gluconic, oxalic and citric acids, isopropanol, ethylene glycol and sodium citrate between pre-flush and over-flush intervals, which composition and method does not include the use of hydrochloric acid or hydrofluoric acid.

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

Abstract: Methods are provided that include a method comprising providing a viscosified treatment fluid comprising a base fluid and a gelling agent that comprises a clarified xanthan; and placing the viscosified treatment fluid into at least a portion of a subterranean formation. In some embodiments, the method comprises placing the viscosified treatment fluid into at least a portion of a subterranean formation at a pressure sufficient to create or enhance at least one fracture in the subterranean formation. In some embodiments, the viscosified treatment fluid may also comprise a plurality of particulates. In some embodiments, the viscosified treatment fluids may be placed into at least a portion of a pipeline. Additional methods are also provided.

Abstract: A downhole wellbore filtercake breaker is disclosed comprising one or more breaker chemicals (or activators thereof) capable of being activated with radiation to form one or more breaker reaction products which in turn are capable of reacting with the filtercake to chemically break down the filtercake. There is also disclosed a conventional reservoir drilling fluid modified to include an inactive, delayed, or sequestered breaker chemical or an activator thereof, wherein the breaker chemical (or activator) may be activated directly or indirectly by radiation, such as, microwave, visible, uV, soft x-ray, or other electromagnetic radiation. Also disclosed are methods for creating these filtercakes, and then breaking them via deploying a source of radiation that can be energized proximate to the filtercake. The breaker may be regenerated downhole by reaction with the filtercake breakdown products, and subjected again to a source of radiation to continue the breakdown of filtercake.

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: Spherical and rod-shaped proppants and anti-flowback agents made from sillimanite minerals possess high strength and high conductivity. The sillimanite minerals may be selected from the group consisting of kyanite, sillimanite, and andalusite and may be used alone or in combination with other materials, such as bauxite, kaolin, meta-kaolin, pure or technical grade alumina (about 98%-99.9% alumina by weight), alumina-containing slag, zirconia, silica, iron, alkali elements (such as calcium, magnesium, and sodium), and virtually any other mineral containing alumina. The starting material may optionally be milled to achieve better compacity and crush resistance in the final proppant or anti-flowback agent. A fracturing fluid may comprise the rods or spheres alone, or in combination with each other or other proppants or anti-flowback agents of different shapes.

Abstract: Methods comprising preparing an aqueous mixture of an anionic polymer, a charge screening surfactant, and a borate crosslinker, wherein the mixture has a conductivity less than 10 mS/cm, injecting the mixture down a wellbore, and gelling the mixture. An embodiment of the aqueous mixture can also include tetramethylammonium chloride as a clay stabilizer and a metal crosslinker such as a complex of zirconium and an amino acid ligand system. An embodiment can effectively provide borate crosslinking of an anionic polymer in a low-ionic-strength fluid system, without sacrificing ultimate gel strength or thermal persistence of the metal crosslinked polymer.

Abstract: Many methods are provided herein including, in one embodiment, a method comprising: providing a fluid that comprises an acid, crosslinked oxidized xanthan, and optionally, a base fluid; placing the fluid in a well bore penetrating a subterranean formation; and allowing the fluid to acidize at least a portion of the formation or damage contained therein. In another embodiment, herein provided is a fluid for subterranean uses comprising an acid and crosslinked, oxidized xanthan.

Abstract: A process is disclosed for treating an underground formation, which process comprises: (a) introducing into the underground formation a micellar dispersion comprising water, one or more organic acid precursors, one or more surfactants and, optionally, one or more salts, co-surfactants and/or organic liquids that are not organic acid precursors; and (b) allowing (i) the micellar dispersion to solubilise hydrocarbons, emulsions or water blocks present in the underground formation, and (ii) at least a portion of the organic acid precursor to hydrolyse in-situ to produce sufficient organic acid to substantively dissolve acid soluble material present in or adjacent to filter cakes or other damage in the underground formation.

Abstract: Spherical and rod-shaped proppants and anti-flowback agents made from sillimanite minerals possess high strength and high conductivity. The sillimanite minerals may be selected from the group consisting of kyanite, sillimanite, and andalusite and may be used alone or in combination with other materials, such as bauxite, kaolin, meta-kaolin, pure or technical grade alumina (about 98%-99.9% alumina by weight), alumina-containing slag, zirconia, silica, iron, alkali elements (such as calcium, magnesium, and sodium), and virtually any other mineral containing alumina. The starting material may optionally be milled to achieve better compacity and crush resistance in the final proppant or anti-flowback agent. A fracturing fluid may comprise the rods or spheres alone, or in combination with each other or other proppants or anti-flowback agents of different shapes.

Abstract: A water-based drilling fluid containing Mn3O4 has been found to be effective in providing petroleum reservoirs with the ability to flow naturally and achieve a return permeability of 90% or greater without the need for acidizing treatments.

Abstract: Acidic treatment fluids used in industrial and/or subterranean operations, and more particularly, acidic treatment fluids comprising clarified xanthan gelling agents, and methods of use in industrial and/or subterranean operations, are provided. In one embodiment, the methods comprise: providing an acidic treatment fluid that comprises an aqueous base fluid, an acid, and a gelling agent that comprises clarified xanthan; and introducing the acidic treatment fluid into a portion of a subterranean formation.

Abstract: Acidic treatment fluids used in industrial and/or subterranean operations, and more particularly, acidic treatment fluids comprising clarified xanthan gelling agents, and methods of use in industrial and/or subterranean operations, are provided. In one embodiment, the acidic treatment fluids comprise an aqueous base fluid, an acid, and a gelling agent comprising clarified xanthan.

Abstract: A low viscosity wellbore polymer fluid gelling system comprising an aqueous medium and a water-in-water emulsion comprising a plurality of polymers or oligomers, including at least one removable polymer or oligomer, and at least one gelling polymer or oligomer, wherein said fluid has a low viscosity when injected, and the gelling polymer forms a gel downhole which has a storage modulus of at least about 60 Pa after the removable polymer is removed from the fluid. A method of isolating at least one zone of a subterranean formation penetrated by a wellbore includes the steps of preparing a water-in-water emulsion comprising a plurality of polymers or oligomers including at least one removable polymer or oligomer, and at least one gellable polymer or oligomer; and combining the water-in-water emulsion with an aqueous medium to prepare a low viscosity polymer fluid.

Abstract: Compositions and methods are given for delayed breaking of viscoelastic surfactant gels inside formation pores, particularly for use in hydraulic fracturing. Breaking inside formation pores is accomplished without mechanical intervention or use of a second fluid. Acidic internal breakers such as sulfuric acid and nitric acid are used. The break may be accelerated, for example with a free radical propagating species, or retarded, for example with an oxygen scavenger.

Abstract: The invention relates to a method to repair a leak in a geological structure or a construction comprising a geological material, comprising administering a liquid nutrient composition, comprising an energy source for anaerobic bacteria and a multivalent metal ion upstream of the leak allowing micro-organisms present in the structure or construction to ferment the energy source and to grow, thereby increasing biomass in and/or around the leak releasing mineral particles upstream of the leak allowing the mineral particles to migrate to the leak; and allowing the mineral particles to settle in the biomass.

Abstract: The amount of crystallized salt in an oil and/or gas well may be minimized or reduced by use of a fructan, such as inulin, or a derivative as a salt block inhibitor. A preferred salt inhibitor is the salt of carboxyalkyl inulin such as a sodium salt of carboxymethyl inulin. The salt block inhibitor may be adsorbed onto a water-insoluble adsorbent.

Abstract: A variety of methods and compositions are disclosed, including, in one embodiment, a method that comprises: introducing a treatment fluid into a subterranean formation, wherein the treatment fluid comprises water and a concentrated polymer composition comprising a complexing agent and a friction reducing polymer. Also disclosed is a method that comprises combining at least water and a concentrated polymer composition to form a treatment fluid, wherein the concentrated polymer composition comprises a complexing agent and a friction reducing polymer; and introducing the treatment fluid into a subterranean formation. Also disclosed is a concentrated polymer composition comprising: a friction reducing polymer in an amount of about 15% to about 60% by weight of the composition; and a complexing agent.

Abstract: A water-based drilling fluid containing Mn3O4 has been found to be effective in providing petroleum reservoirs with the ability to flow naturally and achieve a return permeability of 90% or greater without the need for acidizing treatments.

Abstract: Method and agent for reducing water production from oil and gas wells. The agent comprises polymer, cross-linked particles which are stable in water-free solvents. The particles are manufactured in an oil-in-oil emulsion and are cross-linked with at least one water-stable cross-liner and at least one water-labile cross-linker. The water-labile cross-linker is chosen so that when it is opened or broken in a reaction with water a hydrophilic seat is formed which increases the particle's ability to swell in water. The particles furthermore comprise a controlled amount of an immobilized chemical compound which by means of said reaction between water and reactive groups in the polymer skeleton, become able to form chemical bonds to another particle, to another reactive seat in the same particle or to another compounds thereby increasing the agent's stability in the formation.

Abstract: A method of treating a hydrocarbon containing formation is described. The method may include providing a hydrocarbon recovery composition to the hydrocarbon containing formation. Hydrocarbons in the hydrocarbon containing formation may interact with the hydrocarbon recovery composition. The hydrocarbon recovery composition may include an aliphatic anionic surfactant and an aliphatic nonionic additive. In some embodiments, an aliphatic anionic surfactant may be branched. In other embodiments, an aliphatic nonionic additive may be branched.

Abstract: A method is provided for producing a guar gum powder, the method comprising the steps of: (a) flaking undehusked guar splits; and (b) grinding the flaked, undehusked guar splits to obtain guar gum powder. According to another aspect of the invention, a method is provided for treating a subterranean formation penetrated by a wellbore, the method comprises the steps of: (a) forming a treatment fluid, wherein the treatment fluid comprises: (i) an aqueous fluid; and (ii) a guar gum powder comprising at least 70% by weight gum material and at least 15% by weight husk material; and (b) introducing the treatment fluid into the subterranean formation through the wellbore, According to yet another aspect of the invention, the product of the method for producing a guar gum powder is used in the method for treating a subterranean formation.

Abstract: Methods comprising: providing a treatment fluid comprising: an aqueous base fluid and a gelling agent that comprises a nonnatural galactomannan; and placing the treatment fluid into the subterranean formation. Treatment fluids suitable for use in a subterranean treatment operation comprising an aqueous base fluid and a gelling agent that comprises a nonnatural galactomannan.

Abstract: A lost circulation material and method for treatment employing the material is provided that has particular utility in offshore applications because the material may be used with saltwater or brine, as well as with fresh water, and is biodegradable. The material comprises a biodegradable superabsorbent polysaccharide polymer that is preferably uncrosslinked and non-ionic and that is capable of absorbing multiple times its weight in sea water.

Abstract: A process to prepare a solution of zirconium-hydroxyalkylated diamine-lactic acid complex is disclosed and use of the solution in oil field applications such as hydraulic fracturing and plugging of permeable zones. The process comprises contacting an alcohol solution of a zirconium complex with an hydroxyalkylated diamine, then with lactic acid to produce a solution of zirconium-hydroxyalkylated diamine-lactic acid complex. The solution is particularly suitable for use in a cross-linking composition in hydraulic fracturing and plugging of permeable zones of subterranean formations at pH of 10 or greater and at temperatures of 275° F. (135° C.) and higher in the formation.

Abstract: The invention provides a method for producing guar gum, the method comprising the steps of: (a) sizing husk from guar seed into larger pieces and smaller pieces, (b) washing the larger pieces, (c) soaking the larger pieces, and (d) flaking the larger pieces to obtain guar gum. The invention also provides a method for processing undehusked guar splits, the method comprising the steps of: (a) dehusking undehusked guar splits to obtain dehusked guar splits and husk, and (b) sizing the husk into larger pieces and smaller pieces.

Abstract: Additives for use in treatment operations, and more particularly, additives that include chlorinated carbohydrates, are provided. An example of an additive is a well fluid additive for use in a subterranean formation that includes a chlorinated carbohydrate. Another example of an additive is a well fluid additive for use in a subterranean formation that includes a chlorinated carbohydrate and a tartaric acid.

Abstract: Treatment fluids are provided that comprise a gelling agent that comprises scleroglucan and/or diutan.

Abstract: Aqueous wellbore treatment fluids having improved thermal stability are provided. The wellbore treatment fluids comprise at least one polysaccharide and an effective amount of at least one polyacrylamide to maintain its stability at a temperature greater than about 250° F. A formate compound is not required to achieve high-temperature stability in the fluid. Thus, the fluid is less expensive than conventional polymer-containing aqueous wellbore treatment fluids. The aqueous fluid may serve as, for example, a drilling fluid in the wellbore and thus may be circulated through the wellbore without being concerned that it could become unstable due to exposure to relatively high downhole temperatures.

Abstract: Methods of improving the thermal stability of an aqueous wellbore treatment fluid are provided. The wellbore treatment fluid comprises at least one polysaccharide and an effective amount of at least one polyacrylamide to maintain its stability at a temperature greater than about 250° F. A formate compound is not required to achieve high-temperature stability in the fluid. Thus, the fluid is less expensive than conventional polymer-containing aqueous wellbore treatment fluids. The aqueous fluid may serve as, for example, a drilling fluid in the wellbore. It may be circulated through the wellbore without being concerned that it could become unstable due to exposure to relatively high downhole temperatures.

Abstract: A method of treating a subterranean formation penetrated by a wellbore is carried out by providing a treatment fluid comprising a hydratable polymer, a divalent metal salt in an amount of at least about 0.25 mol/L and an aluminum crosslinking agent. The fluid is provided with a pH of from about 5 or higher. The treatment fluid may be caused to contact the formation by introducing the fluid into the wellbore. The fluid may optionally contain a polyol.

Abstract: N,N-Dialkylpolyhydroxyalkylamines may be made by the reductive alkylation of an N-alkylpolyhydroxyalkylamine with an aldehyde or ketone, or with an equivalent compound, in the presence of a transition metal catalyst and hydrogen. The reaction is performed in a reaction solvent that contains at least 30 wt % of an organic solvent. The use of a sufficiently high proportion of an appropriate organic solvent in the reaction mixture reduces the amount of water present in the reaction mixture, and provides rapid reaction rates and high yields of the desired product. The N,N-dialkylpolyhydroxyalkylamines may be used in a wide variety of applications.

Abstract: For conformance treatment to plug an opening in subterranean hydrocarbon bearing formation, a conformance additive including water soluble crosslinkable polymer, a crosslinking agent, a filter aid that is preferably diatomaceous earth, and optionally a reinforcing material. The method of forming a conformance fluid includes contacting the additive with water or an aqueous solution, with a method of conforming the formation further including the step of injecting the fluid into the formation to plug the opening.

Abstract: The present application relates to granules of powdery mineral particles produced by spray granulation of a liquid slurry comprising powdery minerals particles having particle size below 10 m, at least one water-reducing agent and/or at least one binder agent and/or at least one dispersing agent. The application further relates to a method for producing such granules.

Abstract: Methods comprising preparing an aqueous mixture of an anionic polymer, a charge screening surfactant, and a borate crosslinker, wherein the mixture has a conductivity less than 10 mS/cm, injecting the mixture down a wellbore, and gelling the mixture. An embodiment of the aqueous mixture can also include tetramethylammonium chloride as a clay stabilizer and a metal crosslinker such as a complex of zirconium and an amino acid ligand system. An embodiment can effectively provide borate crosslinking of an anionic polymer in a low-ionic-strength fluid system, without sacrificing ultimate gel strength or thermal persistence of the metal crosslinked polymer.