Abstract: This invention relates to compositions and methods of treating a subterranean formation penetrated by a well bore including providing a treatment composition comprising a rheological polymer, a partitioning agent, a charged polyelectrolyte, and a first liquid medium, forming a stabilized heterogeneous mixture comprising a dispersed rheological polymer-rich phase and a partitioning agent-rich phase, and injecting the treatment fluid into the well bore. The invention relates to methods and compositions for preparing a well treatment fluid, including mixing polyethylene glycol partitioning agent, a charged polyelectrolyte, a first aqueous medium, and one or more rheological polymers selected from the group consisting of guar, modified guar, cellulose, modified cellulose, heteropolysaccharide, heteropolysaccharide derivative, or polyacrylamide, to hydrate the one or more polymers and form a water-in-water emulsion, and mixing the water-in-water emulsion with a second aqueous medium to form a well treatment fluid.

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

Abstract: A treatment fluid for treating a subterranean formation is formed from an aqueous solution of a polysaccharide, a polyacrylamide, a crosslinking agent, which may be a Group 4 transition metal crosslinking agent, and less than 0.1% by weight of any clay component. In certain embodiments, the polyacrylamide may have an average molecular weight of from greater than 0.5 million to about 20 million and may be present in the fluid in an amount of from about 0.01% to 1% by weight of the fluid. 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. In certain embodiments, the treatment fluid may be introduced into a portion of the formation having a temperature of 120° C. or higher.

Abstract: The present invention relates to novel aqueous wellbore treatment fluids containing a gas component, a heteropolysaccharide, an electrolyte, and a surfactant, wherein the fluids may further include an organoamino compound. The fluids exhibit good rheological properties at elevated temperatures. Methods of using fluids containing at least an aqueous medium, a gas component, a heteropolysaccharide and a surfactant for hydraulically fracturing, well cleanup and gravel packing operations, are also disclosed.

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: A treatment fluid composition for treating a subterranean formation penetrated by a wellbore is formed from an aqueous fluid, a hydratable polymer and a water-soluble, non-symmetrical, inorganic peroxide breaking agent, which is capable of undergoing heterolytical cleavage. A method of treating a subterranean formation penetrated by a wellbore may also be performed by forming a treatment fluid from an aqueous hydrated polymer solution. This is combined with a water-soluble, non-symmetrical, heterolytically cleavable inorganic peroxide breaking agent. The treating fluid is introduced into the formation. An optional crosslinking agent capable of crosslinking the polymer may also be included.

Abstract: Processes for the rapid and efficient drying of boron-containing compounds, in particular boron-containing minerals and ores, are described, as well as the products which result from such processes. The process comprises the steps of providing a boron-containing material; introducing the boron-containing material into a pre-heated furnace; heating the boron-containing material in the furnace at a temperature between about 800° F. and 1000° F.; retaining the boron-containing material within the furnace for a time ranging from about 5 minutes to about 120 minutes; and removing the boron-containing material from the furnace and allowing it to cool to ambient temperature. Optionally, the process may also comprise one or more steps of grinding and/or sizing the boron-containing material to a specific particle size prior to the introduction of the material to a furnace.

Abstract: A well treatment fluid and method uses an organic peroxide. An activator embodiment can lower an effective concentration of the peroxide to break the fluid. A weight ratio of activator:organic peroxide can be at least about 1:20 in one well treatment fluid embodiment. A peroxyester breaker embodiment can be used in a well treatment fluid and method. A breaker delay agent embodiment can control the polymer break window in a well treatment fluid and method using an organic peroxide. A breaker package embodiment used in a well treatment fluid and method can include an organic peroxide and an amine breaker delay agent having the formula RR1NR2 wherein R, R1 and R2 are independently selected from hydrogen, alkyl, hydroxyalkyl, and combinations thereof.

Abstract: A method of treating a subterranean formation including with a bactericidal fluid is provided. The method comprises the steps of: (a) continuously mixing to obtain a stream of a treatment fluid: (i) a base fluid comprising water; (ii) an aqueous solution comprising a hypochlorite having a pH equal to or greater than 7; and (iii) a pH-adjusting agent selected to be capable of lowering the pH of water to less than 7; and (b) injecting the treatment fluid into a wellbore. The step of continuously mixing the base fluid, the aqueous solution of hypochlorite, and the pH-adjusting agent is preferably under conditions and in proportions sufficient to obtain a stream of a treatment fluid having a free chlorine concentration of at least 1 ppm by weight of the water in the treatment fluid and having a pH in the range of 4-7.

Abstract: The present invention relates to novel aqueous wellbore treatment fluids containing a gas component, a heteropolysaccharide, an electrolyte, and a surfactant, wherein the fluids may further include an organoamino compound. The fluids exhibit good rheological properties at elevated temperatures. Methods of use of fluids comprising at least an aqueous medium, a gas component, a heteropolysaccharide and a surfactant for hydraulically fracturing, well cleanup and gravel packing operations, are also disclosed.

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: 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: This invention involves a process for recovering oil from a subterranean reservoir where an injection fluid containing one or more primary surfactants of the structure below along with one or more co-surfactants, solvent and optionally a viscosifier and one or more alkalis injected into one or more injection wells and the oil is recovered from one or more producing wells. where: Ar=any aromatic moiety, M=H, Na, K, Ca, Mg, NH4, or an amine, m+n=10 to 28, R, R?, R?=separately and independently H, CH3, branched alkyl having 2-30 carbons, linear alkyl having 2-30 carbons, CH3(CH2)mCH(CH2)nSO3M, O(CH2CH2O)xH, O(CHCH3CH2O)xH, or O(CH2CH2O)aO(CHCH3CH2O)bH, x=1 to 30, y=1 to 30, a+b=1 to 30. The primary surfactant may be prepared in the acid form at one location and shipped as a neat product to be formulated into the final injection brine at or near the point of injection.

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

Abstract: A composition comprising a carboxylated, sulfonated polysaccharide and a wellbore servicing fluid. A wellbore servicing composition comprising a hydraulic cement and a carboxylated, sulfonated polysaccharide. A wellbore servicing composition comprising a polysaccharide having carboxylate and sulfonate groups.

Abstract: The invention discloses treatment and reuse of oilfield produced water. A method of inhibiting enzymes/bacteria in an aqueous medium for viscosification comprises contacting the aqueous medium with a denaturant and/or a bactericide and thereafter mixing a gelling agent in the aqueous medium. The viscosified fluid can be used as a well treating fluid for fracturing and other applications. A well treatment fluid comprises a metal denaturant and/or a bactericide and a gelling agent in an amount effective to viscosify the fluid. Also disclosed is oilfield produced water denatured with from 1 to 2000 ppm by weight of a zirconium compound.

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: Novel cross-linked gels comprised of alkoxyetheramides grafted to polysaccharides that have superior viscosity properties have been made. By controlling the chain length of the alkoxyetheramides and the hydrophobic nature of the gel, these materials are ideal for many uses such as in hydraulic fracturing of oil-bearing geological formations, in the paint and dye industries, as dispersants, in personal care products and for carriers in controlled drug delivery.

Abstract: A depolymerized-carboxyalkyl polysaccharide formed by de polymerizing a polysaccharide having from 0.5 to 3.0 degrees of substitution and reducing the molecular weight of said polysaccharide before or after said depolymerizing provides a biodegradable scale inhibitor useful to prevent deposition of scale comprising, for example, calcium, barium, sulfate and salts thereof. The depolymerized carboxyalkyl polysaccharide is particularly useful in off shore oil production squeeze treatments and in the treatment of scale formed in industrial water treatment.

Abstract: A cross-link delaying or retarding composition, a cross-linking system including the cross-link delaying or retarding composition, or a fracturing fluid including a cross-linking system and a cross-link delaying or retarding composition are disclosed along with methods for making and using the compositions.

Abstract: A cross-linking composition which comprises (a) an aqueous liquid, (b) a cross-linkable organic polymer, and (c) a solution comprising a zirconium cross-linking agent which comprises a zirconium complex having a molar ratio of 1:2 to 1:4 of zirconium to triethanolamine and a molar ratio of 1:0.1 to 1:1 of zirconium to N,N,N?,N?-tetrakis-(2-hydroxypropyl)-ethylene diamine. The composition can be used in oil field applications for hydraulic fracturing and plugging of permeable zones and leaks in subterranean formations.

Abstract: The invention concerns an aqueous viscoelastic fracturing fluid for use in the recovery of hydrocarbons. According to the invention, the fluid comprises a viscoelastic surfactant and a hydrophobically-modified polymer wherein the concentration of the hydrophobically-modified polymer is comprised between its overlap concentration c* and its entanglement concentration ce.

Abstract: Long-chained polymer compounds are useful to viscosify aqueous brine fluids so that they can function as drilling fluids, completion/workover fluids, fracturing fluids, agricultural products, cleaning compounds, etc. These polymers may be hydrated with a microemulsion or lactescent emulsion prior to being added to the target fluid. The rate and completeness of hydration by this method are controlled and improved. In one non-limiting embodiment the microemulsion includes a polar hydrocarbon component, a nonpolar hydrocarbon oil, a small amount of water, a surfactant and optionally a co-surfactant.

Abstract: A method of enhancing hydration of a hydratable material is described, including providing an aqueous composition including a hydratable material, and supplying energy to the aqueous composition using a cavitation device.

Abstract: A well treating composition containing a polysaccharide-based water-superabsorbent material has particularly applicability as a thermal insulating, fracturing or acid stimulation fluid. The water-superabsorbent material is capable of absorbing, at a minimum, its own weight. Particularly effective are biodegradable materials containing guar gum and carrageenan. The composition may further contain a crosslinking agent, brine and/or a viscosifying polymer or a gelling agent. As an oil-based fluid, the crosslinking agent is absorbed onto the water-superabsorbent material and serves to effectively delay crosslinking.

Abstract: A composition includes water having a salinity of at least 1 ppt, at least one hydrophilic polymer containing primary (—NH2) and/or secondary (—NHR) amine groups and at least one saccharide containing a reducible function. A method of changing the permeability of a subterranean formation includes the step of injecting into a subterranean formation a composition comprising water, at least one hydrophilic polymer containing at least two groups which are independently the same or different a primary amine group or a secondary amine group and at least one saccharide containing a reducible function.

Abstract: A clear, stable, salt-free solution of a 1:1 molar complex of zirconium and N,N,N?,N?-tetrakis-(2-hydroxypropyl)ethylene diamine. The solution can be used in a cross-linking composition comprising a cross-linkable organic polymer for oil field applications such as fluid fracturing and plugging permeable zones in subterranean formations.

Abstract: A process for preparing a stable zirconium triethanolamine cross-linking agent comprises contacting a solution of a zirconium triethanolamine complex with water at a temperature of 50° C. to 90° C. at a mole ratio of triethanolamine:zirconium in the range of 3.5:5.5 and at a mole ratio of water:zirconium in the range of 20:1 to 1:1. The stable zirconium triethanolamine complex can be used in a cross-linking composition. Further disclosed are methods to use the composition in oil field applications for hydraulic fracturing and plugging of permeable zones and leaks in subterranean formations.

Abstract: An aqueous composition for treating hydrocarbon wells comprises an aqueous medium, a scale inhibitor, and a guar.

Abstract: A composition for treating wellbore formations is provided consisting of a hydratable polysaccharide, an anionic surfactant, and an aqueous solvent where the hydratable polysaccharide is soluble in the aqueous solvent. The concentration of the anionic surfactant is sufficient to scavenge greater than about 50%, and preferably greater than 90% of the cations contained in the aqueous solvent. The hydratable polysaccharide is preferably anionic and may be a guar, guar derivative, galactomannan, cellulose, or cellulose derivative. The composition may also be a slurry used for preparing aqueous well treatment fluid. A method is also provided for utilizing the composition for fracturing a formation by pumping the fluid into the formation.

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: A composition includes water having a salinity of at least 1 ppt, at least one hydrophilic polymer containing primary (—NH2) and/or secondary (—NHR) amine groups and at least one saccharide containing a reducible function. A method of changing the permeability of a subterranean formation includes the step of injecting into a subterranean formation a composition comprising water, at least one hydrophilic polymer containing at least two groups which are independently the same or different a primary amine group or a secondary amine group and at least one saccharide containing a reducible function.

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: A composition useful for making gelled fluids by crosslinking hydratable polymers is an aqueous solution of zirconium complexed with carbonate and bicarbonate as the only multidentate ligands complexed with zirconium. The composition also provides pH modifying capability and the crosslinking is delayed, so that the single composition replaces several liquid additives previously necessary for generation of fluids used, for example, in hydraulic fracturing.

Abstract: One embodiment of the present invention provides methods of treating a subterranean formation with a viscosified treatment fluid comprising combining water, a carbonyl-containing first compound, and an amine-containing second compound; wherein the carbonyl-containing first compound comprises at least one carbonyl moiety and is either a gelling agent or a derivatizing agent, and wherein the amine-containing second compound comprises at least one amine moiety and is a gelling agent when the carbonyl-containing first compound is a derivatizing agent and is a derivatizing agent when the carbonyl-containing first compound is a gelling agent; allowing at least one carbonyl moiety from the first compound and at least one amine moiety from the second compound to form a derivatizing linkage and create a derivatized gelling agent; and, placing the viscosified treatment fluid into a portion of a subterranean formation.

Abstract: A polyelectrolyte complex for the controlled release of an oil and gas field chemical selected from the group consisting of (a) a gel-forming or cross-linking agent, (b) a scale inhibitor, (c) a corrosion inhibitor, (d) an inhibitor of asphaltene or wax deposition, (e) a hydrogen sulfide scavenger, (f) a hydrate inhibitor, (g) a breaking agent, and a surfactant.

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

Abstract: A well service fluid comprising one or more anionic viscoelastic surfactants and one or more polymers is described. The fluids can contain an aqueous or non-aqueous fluid and/or a buffer for adjusting the pH of the fracturing fluid. The well service fluid can be used as a fracturing fluid in order to control water production from a well, while simultaneously increasing the oil production from the well.

Abstract: Methods using foamed fluids to perform subterranean formation treatments, the fluid containing methanol having a decreased concentration of gelling agent, while retaining excellent rheological properties in the foamed state, and processes for preparing foamed fluid for use in treating subterranean formations.

Abstract: A thermal insulating packer fluid contains water and/or brine, a crosslinkable viscosifying polymer, a crosslinking agent and an optional set retarder. The composition is capable of inhibiting unwanted heat loss from production tubing or uncontrolled heat transfer to outer annuli. The viscosity of the composition is such as to reduce the convection flow velocity within the annulus.

Abstract: A method of introducing an oil field or gas field production chemical into a hydrocarbon-bearing porous subterranean formation penetrated by a wellbore comprising: injecting a gelling composition comprising an aqueous liquid, an oil field or gas field production chemical, and a gellable polymer through the wellbore into the porous subterranean formation wherein the gellable polymer forms a gel within the pores of the subterranean formation thereby encapsulating the production chemical in the gel; and controllably releasing the production chemical from the gel into a formation fluid.

Abstract: A self-hydrating, self-crosslinking dry composition is used to prepare a hydrated, crosslinked fracturing fluid upon addition of water, the composition comprising (A) guar powder or a guar derivative powder; (B) crosslinker selected from the group consisting of boric acid, borax, borate ore, boron ore, antimony compounds, aluminum compounds, zirconium compounds, and titanium compounds; and (C) slow dissolving alkaline buffer, wherein the crosslinker (B) is non-encapsulated.

Abstract: Suspensions are provided of water-soluble materials in non-aqueous carrier fluids using suspension agents that include organophilic clays. Methods of forming such suspensions are provided. Methods are also provided for using such suspensions to prepare aqueous solutions, in particular thickened aqueous solutions, in particular for use in oilfield treatments.

Abstract: The present invention relates to improved methods and compositions for reducing the viscosity of subterranean servicing fluids where the servicing fluid has been cross-linked to increase its viscosity and that crosslinking can be reversed using a delayed release acid produced to reduce the fluid's pH.

Abstract: Methods for treating subterranean formations and aqueous treating fluid compositions are provided. The aqueous treating fluid compositions comprise water, a water soluble hydrophobically modified gelling agent polymer produced by grafting a low concentration of hydrophobic monomers thereon, and a low concentration of an ionic surfactant the hydrophobic chain portion of which is associated with the hydrophobic monomers grafted onto the gelling agent polymer resulting in gelling agent polymer molecules having increased radiuses of gyration.

Abstract: A liquid gel concentrate for forming a high viscosity treating fluid is provided which can be premixed and stored before being used. The concentrate is comprised of an aqueous formate solution, at least one hydratable polymer which yields viscosity upon hydration and optionally an inhibitor having the property of reversibly reacting with the hydratable polymer in a manner whereby the rate of hydration of the polymer is retarded. Upon the selective reversal of the hydration inhibiting reaction the polymer is hydrated and high viscosity yielded thereby. The concentrate can be diluted with water to hydrate the hydratable polymer and form a large volume of high viscosity treating fluid.

Abstract: Disclosed are drilling fluids suitable for use in connection with oil well drilling. The drilling fluids of the invention include in one embodiment a liquid base, an alkyl glucoside, such as methyl glucoside, and a borehole stability promoter that includes a maltodextrin, a carboxyalkyl starch, a hemicellulose-containing material, or a mixture of the foregoing. In another embodiment, the drilling fluid includes a liquid base and molasses solids, preferably in combination with an alkyl glucoside and more preferably in further combination with one of the aforementioned borehole stability promoters. The drilling fluids of the invention surprisingly have a reduced tendency to swell shale as compared with known drilling fluids. Also disclosed are a drilling apparatus and process. The drilling apparatus includes a drill string, which may be conventional, that is fluidically coupled to a source of drilling fluid, the source of drilling fluid including the drilling fluid of the invention.

Abstract: Improved methods for treating and for fracturing subterranean formations and the fluid compositions are provided. The viscosity of a treating fluid containing gelling agents is broken, even at temperatures of about 250° F. and lower, utilizing an oxidizing breaker and a reducing sugar to activate the breaker.

Abstract: It has been discovered that certain fracturing fluid compositions can be used to fracture a subterranean formation and be permitted to stay within the formation for a relatively extended period of time, for example 28 days or more, before being flowed back or produced. At least two embodiments are envisioned, a bacteria-containing formulation and an anti-bacterial formulation. Both systems would be expected to prevent the potential of the fluid to oil wet the formulation (water block condition) by keeping the formation water wet through the use of water wetting surfactants or solvents. Additionally, both formulations would control reservoir crude souring (H2S generation by in situ sulfate-reducing bacteria), reservoir plugging (via slime biopolymers generated by in situ microbes, inorganic scale deposition like calcium carbonate or barium sulfate, and clay fines migration).

Abstract: The subject of the present invention is the use of particular polysaccharides as admixtures for mineral materials, especially as admixtures for mineral binders. These polysaccharides have, characteristically: a weight-average molecular weight Mw of at least 500 g/mol and at most 9000 g/mol, especially between 700 and 7000 g/mol; and a degree of branching DB of at least 10%, especially between 10 and 40%. The invention also relates to the combined use, in mineral materials, including especially mineral binders, of these particular polysaccharides on the one hand and of certain other admixtures on the other hand, for example admixtures, of saccharidic or nonsaccharidic type, having a plasticizing, superplasticizing or other functionality.