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

Abstract: The invention describes improved environmentally friendly, non-toxic, CBM friendly, green fracturing compositions, methods of preparing fracturing compositions and methods of use. Importantly, the subject invention overcomes problems in the use of water-based mists as an effective fracturing composition particularly having regard to the ability of a mist to transport an effective volume of proppant into a formation. As a result, the subject technologies provide an effective economic solution to using high ratio gas fracturing compositions that can be produced in a continuous (i.e. non-batch) process without the attendant capital and operating costs of current pure gas fracturing equipment.

Abstract: Disclosed are spacer fluids comprising cement kiln dust (“CKD”) and methods of use in subterranean formations.

Abstract: The present invention relates to environmentally friendly compositions and methods for removing or suppressing metal ions in waters, flowback waters, and produced waters to make such waters suitable for subsequent use in oil-field applications and for delinking metal cross-linked gelling agents. One embodiment of the present invention provides a method of providing a competitive binder and allowing the competitive binder to interact with interfering metal ions in a flowback fluid to suppress or remove interfering metal ions.

Abstract: A fracking fluid hydration unit is provided that has a plurality of hydration tank sections wherein shear is added to the hydrated fluid flow via a recirculation hydrated fluid jetting system.

Abstract: Additives useful in attenuating the crosslinking time of sparingly soluble borate minerals and the use of those additives in oil well fracturing fluids and methods are described.

Abstract: A method for breaking the viscosity of an aqueous fluid gelled with a water soluble polymer or a VES is disclosed. The method includes providing an aqueous fluid. The method also includes adding to the aqueous fluid, in any order: a water soluble polymer in an amount sufficient to form a gelled aqueous fluid having a viscosity, a water soluble oxidizing agent configured to generate free radicals and a plurality of metallic particles to produce a mixture comprising dispersed metallic particles dispersed within the gelled aqueous fluid, the metallic particles configured to dissolve in the gelled aqueous fluid and provide a reducing agent to accelerate the generation of free radicals. The method further includes dissolving the metallic particles in the gelled aqueous fluid to provide a source of at least one transition metal ion in an amount effective accelerate the generation of free radicals and reduce the viscosity.

Abstract: Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include nitrogen generating compounds, which upon activation, react to generate heat and nitrogen gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, heat and nitrogen gas are generated. Upon the generation of nitrogen gas and heat within the formation, microfractures are produced within the formation and the hydrostatic pressure within the reservoir is reduced to less than the reservoir fluid pressure, such that the rate of production of hydrocarbons from the formation is increased.

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: Cement compositions comprising carboxylated inulin and methods of using the same to cement a workspace. In one embodiment, a method of cementing includes providing a cement composition comprising a carboxylated inulin, for example, in a subterranean formation. The method further includes allowing the cement composition to set. In some embodiments, the cement composition has a thickening time of from about 2 hours to about 11 hours. In other embodiments, the cement composition has a viscosity that is about constant for a period of time after the cement composition is placed.

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: A method of treating a subterranean formation comprises providing a treatment fluid comprising: an aqueous fluid; a gelling agent, and a multifunctional boronic crosslinker comprising two or more boronic functional groups; and introducing the viscosified fluid into a subterranean formation.

Abstract: A method comprises providing a treatment fluid having a first viscosity comprising an aqueous base fluid; a viscoelastic surfactant; and a stimuli-responsive water-soluble polymer; introducing the treatment fluid into a subterranean formation; and allowing the treatment fluid viscosity to change to a second viscosity in response to a stimulus.

Abstract: Disclosed is a method of rapidly hydrating a hydratable polymer, which method involves irradiating with radio frequency electromagnetic radiation, a mixture of at least the polymer and an aqueous hydrotreating medium to form a viscosified mixture of at least aqueous hydrotreating medium and hydrated polymer. Related methods of treating a subterranean formation and continuously hydrotreating a subterranean formation are also revealed.

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: Methods that comprise selecting proppant for use in a fracturing fluid based on one or more factors, wherein the one or more factors comprise an interaction between the proppant and the fracturing fluid. Methods that comprise designing a treatment fluid that comprises a gelled base fluid and a particulate based on one or more factors, wherein the one or more factors comprise an interaction between the particulate and the gelled base fluid.

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: Proppant material for hydraulic fracturing is provided. The particles of the proppant are formed by drip casting. A slurry of finely divided ceramic particles is flowed through nozzles and formed into droplets under the influence of vibration. Uniform sized, smooth surface, spherical green particles are formed. The green particles are dried and sintered to form the proppant. The proppant is used in the process of hydraulic fracturing of wells.

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: The invention relates to an improved enhanced recovery method using polymers, wherein these polymers are preserved from mechanical degradation by adding an additive comprising sacrificial compounds. The sacrificial compounds are preferentially degraded instead of the active polymers, thus allowing optimized recovery of the oil in the petroleum reservoir. The sacrificial compounds can be polymers of same nature as the active polymers, but of higher molecular weight, or polymers of different nature having more fragile bonds. The sacrificial compound(s) is/are selected according to a lesser resistance to mechanical degradation, in comparison with the active polymers of the solution allowing enhanced recovery.

Abstract: The present invention is directed to novel additives packages, to fluid compositions including the additives, to methods of using the fluid compositions and the additives package, to methods of recovering hydrocarbons, and to petroleum products made from hydrocarbons derived from these methods. The novel additives packages may be used in a fluid composition for fracturing a subterranean. The additives package of the present invention include one or more gelling agents; one or more cross-linking agent; and one or more high temperature stabilizers; wherein the additives package further comprises one or more ingredients selected from the group consisting of a clay stabilizer, a metallic base, a cross-link retarded and a gel breaker, and any combination thereof; and wherein the additives package optionally includes a diluent.

Abstract: Methods are provided comprising providing a sealant composition comprising an aqueous fluid, a diutan composition, at least one gel system, and a leak off prevention material; introducing the sealant composition into a well bore penetrating the subterranean formation; and allowing the sealant composition to form a seal.

Abstract: The invention provides a process for the production of a granule of a coated oxidizing compound which granule has good delayed release properties, said process comprising a) providing cores of an oxidizing compound produced by fluidized bed spray granulation, b) spraying on the oxidizing compound cores an aqueous solution of metal sili-cate in a fluidized bed, said aqueous solution comprising at least 15% by weight metal silicate, and c) drying to form a metal silicate coating layer on the oxidizing compound core, provided that the amount of metal silicate coating layer is at least 8%, preferably at least 10% by weight based on the total weight of the granule. The invention also provides such granule and well treatment fluids including such granule, and processes for use.

Abstract: A fluid slug consolidation is maintained in a fluid system for use in downhole applications. The fluid system has an interfacing fluid of a different character adjacent to the fluid slug. The method is carried out by admixing a particulate material with at least one of the fluid slug and adjacent interfacing fluid in an amount wherein discrete interfacing fluid margins are formed between the slug and the adjacent interfacing fluid under laminar flow conditions. The fluid system is introduced into a well bore of a well formed in a subterranean formation. In certain applications at least a portion of the particulate material is provided with adhesive properties to facilitate aggregation of the particulate material within the at least one of the fluid slug and adjacent interfacing fluid.

Abstract: Spacer compositions and products may include a biopolymer component, a plant fiber component, and a weighting agent component, and in further non-limiting embodiments may include xanthan gum, a blend of plant fibers, and a weighting agent component. These spacer compositions and spacer products may be utilized in well fluid operations, including well cementing operations and well completion operations.

Abstract: A method of controlling or arresting the rate of depolymerization of a polymer composition during a biocide treatment, and use of such methods in oilfield and industrial applications. Also disclosed are methods of preparing a visco-stable application fluid containing a biocide in an amount effective to reduce bacteria count, as well as additive compositions capable of reducing bacteria count in application fluids while maintaining viscosity in such fluids. Also disclosed are methods of preparing biocide-containing application fluids with improved friction reducing properties, as well as related compositions.

Abstract: A well treatment composition comprises: an aqueous liquid; a fluid loss additive, wherein the fluid loss additive comprises a high molecular weight, water-swellable polymer; and an amphiphilic dispersant, wherein the well treatment composition has an activity of at least 10%. A method of cementing in a subterranean formation comprises: introducing a cement composition into the subterranean formation, the cement composition comprising: (i) cement; (ii) water; and (iii) the well treatment composition; and allowing the cement composition to set.

Abstract: Of the many compositions and methods provided herein, one example composition includes a treatment fluid comprising: an aqueous fluid; and a tar stabilizing polymer comprising at least one polymer selected from the group consisting of a styrene polymer, an acrylate polymer, a styrene-acrylate polymer, and any combination thereof.

Abstract: The current application discloses fluids and methods for treating a subterranean formation penetrated by a wellbore, such as hydraulic fracturing. In one aspect, there is provided an oilfield fluid comprising chitosan at an amount sufficient to inhibit the growth of bacterial in the oilfield fluid. In another aspect, there is provided a method of preserving an oilfield fluid containing adding chitosan at a concentration that is sufficient to inhibit the growth of bacteria in the oilfield fluid. In a further aspect, there is provided a method of treating a subterranean formation penetrated by a wellbore, comprising preparing a treatment fluid, adding chitosan at a concentration sufficient to inhibit the growth of bacteria in the treatment fluid, introducing the mixture to the subterranean formation, and treating the subterranean formation with the mixture.

Abstract: The current application discloses fluids and methods for treating a subterranean formation penetrated by a wellbore. In one aspect, there is provided a fluid comprising chitosan and titanate, where the fluid has an increased viscosity compared with a solution containing chitosan without titanate. In another aspect, there is provided a method of using such fluid to treat a subterranean formation penetrated by a wellbore. The method may comprise mixing chitosan and titanate in a carrying medium, forming a gel comprising chitosan and titanate, introducing the gel into a subterranean formation, and treating the subterranean formation with the gel.

Abstract: Fracturing fluid compositions and methods of fracturing subterranean formations using polyboronic compounds as crosslinking agents are provided. The compositions and methods of the present invention allow for lower polymer loadings because achieving higher fracturing fluid viscosities can be achieved using less polymer than in traditional crosslinked systems.

Abstract: Methods are provided that include, but are not limited to, methods of treating guar splits comprising: exposing guar splits to a treatment chemical to create treated guar splits, wherein the treatment chemical comprises at least one treatment chemical selected from the group consisting of: an aqueous salt solution; a caustic solution, and a derivatizing agent; and grinding the treated guar splits to create ground, treated guar splits.

Abstract: The current application discloses a method of treating a portion of a subterranean formation comprises providing a treatment fluid comprising a carrier fluid, a non-hydrolyzed polyacrylamide or a nonhydrolyzed non ionic copolymer of acrylamide, and a delaying agent; and treating the subterranean formation.

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: A method of treating a portion of a subterranean formation comprises providing a treatment fluid comprising a carrier fluid, a viscosifying agent, a breaker, and a breaker aid wherein the breaker aid slowly releases a catalyst, wherein the viscosifying agent and the breaker in the carrier fluid have an initial viscosity and the catalyst and the breaker cooperate to decrease the viscosity of the treatment fluid below half of the initial viscosity after at least 30 minutes; and treating the subterranean formation.

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

Abstract: Wellbore-cleaning compositions comprising microemulsions are useful during cementing operations. The microemulsion solvent may be selected from the group comprising methyl esters and ethoxylated alcohols. The microemulsion surfactants comprise a water-wetting surfactant, a cleaning surfactant, an emulsifying surfactant, a non-ionic surfactant and a non-ionic co-surfactant. The wellbore-cleaning compositions may be pumped alone, ahead of a conventional spacer fluid or scavenger slurry and behind a conventional spacer fluid or scavenger slurry. In addition, the wellbore-cleaning composition may be incorporated into a carrier fluid such as (but not limited to) a conventional spacer fluid or scavenger slurry. The resulting fluid mixture may be pumped as a spacer fluid.

Abstract: Crosslinkable-polymer compositions that comprise a chitosan-based compound and a phenol source, and associated methods, are provided. Various methods of use are also provided. In one embodiment, the methods comprise providing a crosslinkable-polymer composition comprising an aqueous fluid, a chitosan-based compound, a chitosan-reacting polymer, and a phenol source; introducing the crosslinkable-polymer composition into the portion of the subterranean formation; and allowing the crosslinkable-polymer composition to form a crosslinked gel in the portion of the subterranean formation.

Abstract: Methods of inhibiting corrosion of a metal surface in a well or pipeline are provided. The methods include the steps of: (a) forming a fluid of: (i) an aqueous acid solution; and (ii) inulin; and (b) introducing the fluid into the well or pipeline. The methods have wide application in various kinds of operations involved in the production or transportation of oil and gas, such as acid stimulation or remedial treatment in a pipeline.

Abstract: Methods are provided that include, but are not limited to, methods of treating guar splits comprising: exposing guar splits to a treatment chemical to create treated guar splits, wherein the treatment chemical comprises at least one treatment chemical selected from the group consisting of: an aqueous salt solution; a caustic solution, and a derivatizing agent; and grinding the treated guar splits to create ground, treated guar splits.

Abstract: A well treatment method includes drawing a solvent to a first pump, drawing a wetting liquid to a second pump, pumping the wetting liquid through a polymer mixer using the second pump, combining polymer with the wetting liquid to produce a slurry containing undissolved polymer, and combining the slurry with the solvent upstream from the first pump. Another well treatment method includes increasing dissolution time of the polymer by providing a buffering agent in the wetting liquid before combining the wetting liquid and the polymer. A well treatment system includes a polymer mixing subsystem with a mix loop having a mix loop inlet line from a first pump feed line and a mix loop outlet line back to the first pump feed line, the mix loop outlet line containing a polymer mixer.

Abstract: Proppant material for hydraulic fracturing is provided. The particles of the proppant are formed by drip casting. A slurry of finely divided ceramic particles is flowed through nozzles and formed into droplets under the influence of vibration. Uniform sized, smooth surface, spherical green particles are formed. The green particles are dried and sintered to form the proppant. The proppant is used in the process of hydraulic fracturing of wells.

Abstract: A method for improving hydraulic fracturing creates coated proppants containing one or more chemical constituents bonded to a substrate and introduced into the fracturing fluid itself. The substrate that eventually acts as a proppant may be sand, ceramic, resin coated sand, and other materials. Typically, the materials that are coated as powders adhered to the substrate may include friction reducers, biosides, oxygen scavengers, clay stabilizers, scale inhibitors, gelling agents, or the like. By adhering solid materials to a substrate 12 by a binder 14, a single, solid, granular material may be maintained onsite, requiring reduced footprint, reduced mixing and may introduce almost instantaneously into a fracturing flow stream all the necessary chemical constituents, which will eventually become mixed. The result is reduced time, energy, manpower, equipment, and space at the sight, while reducing the environmental impact of transportation, spills, hydrocarbon use, and the like.

Abstract: The present invention relates to compositions and use of fluidized polymer suspensions containing allyloxy linkage and its functional derivatives, and water soluble polymers for use in oil field applications as fluid additives for drilling and cementing processes.

Abstract: The concentrate solution for the crosslinking of polymers comprises water, polyol, a viscosifying agent, a first borate ion in solution, and a crosslinking agent able to release a second borate ion, wherein the second borate ion is not in solution.

Abstract: A method of servicing a wellbore comprising introducing to the wellbore a wellbore servicing fluid comprising an additive composition comprising a polysaccharide having carboxylate and sulfonate groups. A method of servicing a wellbore comprising preparing at the well site an additive composition comprising a polysaccharide having carboxylate and sulfonate groups, introducing the additive composition into a wellbore servicing fluid, and placing the wellbore servicing fluid into a subterranean formation. A method of preparing a wellbore servicing fluid comprising contacting a polysaccharide composition with an oxidizing agent to form an oxidized polysaccharide, and contacting the oxidized polysaccharide with a sulfonating agent to form a carboxylated sulfonated polysaccharide, and contacting the carboxylated sulfonated polysaccharide with a wellbore servicing fluid.

Abstract: The invention relates to a salt resistant water absorbing compound including a polymeric phase that includes polyacrylamide and at least one of di or poly saccharide, wherein the polyacrylamide is cross-linked in the presence of at least one of di or poly saccharide by a cross-linking agent including multivalent cations, complexes thereof, organic cross-linking agents, or any combination thereof.

Abstract: A cross-linking composition comprising (a) an aqueous liquid; (b) a pH buffer; (c) a cross-linkable organic polymer; and (d) a solution of a zirconium cross-linking agent comprising the product of contacting a zirconium complex with an alkanolamine and ethylene glycol wherein the mole ratio of alkanolamine to zirconium is 2:1 to 4:1 and the mole ratio of ethylene glycol to zirconium is 1:1 to 10:1. Optionally, water, hydroxyalkylated ethylenediamine, or both are added to the zirconium complex. The cross-linking composition of this invention is useful in oil field applications, for example, for hydraulically fracturing a subterranean formation and for plugging permeable zones or leaks in a subterranean formation.

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: Compositions having shear-gelling and shear-thickening properties are based on an amphiphilic polymer combined with hydrophilic particles and polyethyleneoxide. The hydrophilic particles preferably consist of a hydrous sodium lithium magnesium silicate. The amphiphilic polymer may be a synthetic polymer, a hydrophobically modified biopolymer, or both. The compositions may be employed in enhanced oil recovery operations.