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: The method disclosed herein includes the introduction of proppant-free stage and a proppant laden stage into the wellbore and/or subterranean formation. The method increases the effective fracture width and enhances fracture conductivity within the formation. Either the proppant-free stage or the proppant laden stage contains a breaker. The other stage contains a viscosifying polymer or viscoelastic surfactant to which the breaker has affinity. The proppant-free stage may be introduced prior to introduction of the proppant laden stage into the wellbore and/or formation. Alternatively, the proppant laden stage may be introduced into the wellbore and/or formation prior to introduction of the proppant-free stage.

Abstract: A fracturing fluid, gravel pack fluid and/or frac pack fluid containing particles such as proppants, gravel and/.or sand, may contain an effective amount of a nano-sized particulate additive to fixate or reduce fines migration, where the particulate additive is an alkaline earth metal oxide, alkaline earth metal hydroxide, alkali metal oxides, alkali metal hydroxides transition metal oxides, transition metal hydroxides, post-transition metal oxides, post-transition metal hydroxides piezoelectric crystals and pyroelectric crystals. The nano-sized particulate additive is optionally bound to the particles with a coating agent such as an oil, alcohol, glycol, glycol ethers, ketones, terpenes, etc. The particle size of the magnesium oxide or other agent may be nanometer scale but may be a larger scale than nanometer but still relatively small, which scale may provide unique particle charges that help fixate the formation fines.

Abstract: Coal friendly, non-toxic, green fracturing compositions, methods of preparing fracturing compositions and methods of use in various fracturing applications are described. The compositions are characterized as non-toxic compositions enabling effective use of the fracturing compositions in coal bed methane (CBM) formations and particularly shallow CBM formations. The compositions include a liquid component (water-based component) and a gas component in proportions that can support a proppant under turbulent conditions and that promote the formation of a mist.

Abstract: Of the many methods provided herein, one method comprises: providing at least one fracture in a subterranean formation that comprises tight gas, a shale, a clay, and/or a coal bed; providing a plasticity modification fluid that comprises an aqueous fluid and an alkaline embrittlement modification agent; placing the plasticity modification fluid into the fracture in the subterranean formation; and embrittling at least one fracture face of the fracture to form an embrittled fracture face.

Abstract: Subterranean formations, such as tight gas formations, may be subjected to hydraulic fracturing by introducing into the formation a fracturing fluid of an aqueous fluid, a hydratable polymer, a crosslinking agent and proppant. The fracturing fluid is prepared in a blender and then pumped from the blender into the wellbore which penetrates the formation. The fluid enters the reservoir through an entrance site.

Abstract: A composition for wellbore consolidation comprises fibers having a core formed from a material that is electrically and/or magnetically susceptible, and a polymeric coating. When the composition is placed in a wellbore in a zone to be consolidated and an electric current or magnetic field is applied, the fibers bond together by melting or setting of the polymeric coating.

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: 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: 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 process for fracturing a subterraneous formation in the production of an oil well is described. The process steps include injecting an initial charge of a mixture, the mixture being formed from at least a water-insoluble adsorbent and at least one well treatment agent, into a well bore formed in the subterraneous formation so as to form a downhole matrix within the formation; injecting a solution comprised of an additional amount of the well treatment agent into the formation after the initial charge of the at least one well treatment agent has been substantially depleted; and then pressurizing the well bore for a time and under conditions sufficient to reactivate the downhole matrix in the formation, so that the treatment agent activity of the matrix is increased relative to the treatment agent activity of the matrix just prior to injecting the solution.

Abstract: A method for the controlled delivery of a fracturing fluid to a well bore comprises formulating an aqueous base fluid such that it meets or exhibits desired physical and chemical characteristics for an optimal fracturing fluid. The formulation of the aqueous base fluid max involve commingling one or more sources of waste water with a source of fresh water followed by controlled injection of one or more additives. This process is substantially completed prior to delivering the aqueous base fluid to the well site. This allows the delivery of an optimal volume of the aqueous base fluid with homogeneously blended additives to the well bore.

Abstract: Methods of forming one or more fractures in a subterranean formation penetrated by a well bore. The methods generally include providing a treating fluid that comprises water and one or more sulfonated gelling agent polymers, wherein the one or more sulfonated gelling agent polymers comprise a sulfonated synthetic polymer selected from the group consisting of sulfonated polyvinyl alcohol, sulfonated polyacrylate, sulfonated polyacrylamide/acrylic acid copolymers, and any combination thereof; and introducing the treating fluid into the subterranean formation. The treating fluid may be placed at a pressure sufficient to create or extend fractures within the subterranean formation.

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 retarder, and a gel breaker, and any combination thereof; and wherein the additives package optionally includes a diluent.

Abstract: A method of heterogeneous proppant placement in a subterranean fracture is disclosed. The method comprises injecting well treatment fluid including proppant and a channelant through a wellbore into the fracture, heterogeneously placing the proppant in the fracture in a plurality of proppant clusters or islands spaced apart by the channelant, and removing the channelant filler material to form open channels around the pillars for fluid flow from the formation through the fracture toward the wellbore. The proppant and channelant can be segregated within the well treatment fluid, or segregated during placement in the fracture. The channelant can be dissolvable particles, initially acting as a filler material during placement of the proppant, and later dissolving to leave the flow channels between the proppant pillars. The well treatment fluid can include fibers to provide reinforcement and consolidation of the proppant and/or to inhibit settling of the proppant in the treatment fluid.

Abstract: Apparatus and methods comprising a plurality of particles which are magnetically attracted to one another in response to exposure to an magnetic field, and which maintain attraction to one another after removal of the magnetic field, the attraction being disabled when the particles are demagnetized, whereby the particles operate to alter the rheological properties of a fluid in which the particles are mixed when the attraction is enabled or disabled is disclosed.

Abstract: Spherical porous and non-porous cellulose particulates for use in sand control as well as stimulation procedures, may be prepared by first dissolving cellulosic materials (such as fibrous cellulose, wood pulp linters, cotton balls and/or paper), in the substantial absence of water or a nitrogen-containing base, in an ionic liquid. The solution is then combined with a cellulose-insoluble liquid to render the spherical particulates. The surface of the cellulosic particulates may be treated with a coating or penetrating layer.

Abstract: A fluid separation method for performing fluid analysis of an unfiltered fluid. The fluid separation method includes providing a structure with a fluid analyzer and a power supply. Using a substrate for receiving a fluid flow stream of a multiphase mixture through a fluid sample inlet, wherein the substrate interconnects with the structure. Providing a membrane disposed across the fluid sample inlet for separating a fluid of interest from the multiphase mixture, wherein the fluid flow stream of the multiphase mixture has a shear rate that prevents a fouling of the membrane. Finally, the fluid separation method includes the substrate having fabricated channels, such that the fabricated channels are arranged substantially tangent to the fluid stream downstream of the porous membrane.

Abstract: A process for concentrating and diluting a treatment substance to provide a diluted treatment for introduction to a wellbore is disclosed. In one embodiment, the process includes measuring a treatment fluid flow rate. The process also includes blending the treatment fluid with a treatment substance to produce a concentrated treatment fluid. The process further includes measuring a flow rate of the concentrated treatment fluid. Moreover, the process includes determining a difference between the treatment fluid flow rate and the flow rate of the concentrated treatment fluid. In addition, the process includes comparing the difference to a target difference. The process additionally includes adjusting the difference to be within a desired range of the target difference and diluting the concentrated treatment fluid to provide the diluted treatment fluid.

Abstract: Disclosed herein are methods of making free flowing coated particles and low temperature including a step of curing the coating with UV light or electron beam. Each particle has a precured coating disposed upon a substrate. Methods of using the particles are also disclosed.

Abstract: The migration of coal fines within a bed is reduced, inhibited or constrained by contacting the fines with nanoparticles, such as magnesium oxide crystals having an average particle size of about 30 nm. These nanoparticles may coat a proppant during the fracturing of a subterranean formation to produce methane from a coal bed therein. The nanoparticles may also treat a proppant pack in a fractured coal bed. The nanoparticles cause the coal fines to thus bind to or associate with the proppants. Thus, most of the coal fines entering fractures away from the near-wellbore region will be restrained or controlled near their origin or source and the production of methane at a desired level will be maintained much longer than a similar situation than where the nanoparticles are not used.

Abstract: A method for minimizing the amount of metal crosslinked viscosifier necessary for treating a wellbore with proppant or gravel is given. The method includes using fibers to aid in transporting, suspending and placing proppant or gravel in viscous carrier fluids otherwise having insufficient viscosity to prevent particulate settling. Fibers are given that have properties optimized for proppant transport but degrade after the treatment into degradation products that do not precipitate in the presence of ions in the water such as calcium and magnesium. Crosslinked polymer carrier fluids are identified that are not damaged by contaminants present in the fibers or by degradation products released by premature degradation of the fibers.

Abstract: Method of fracturing, hydrocarbon deposits comprising using as source of water an aquifer containing water stable and clear in the aquifer but which may include undesirable soluble chemical compounds that are not in solution when subjected to reduced pressures at surface conditions such as hydrogen sulfide, utilizing aquifer source water in a fracturing process to pump water under pressure at above the water's bubble point pressure to prevent undesirable constituents thereof from separating, maintaining said pressure at a minimum at all times during fracturing, drilling a source and disposal well to/from the aquifer, providing a pump capable of maintaining the minimum pressure, establishing a closed loop, to keep the aquifer water circulating at all times and the undesirable constituents remaining in solution and the water remaining clear thereby avoiding the necessity of treating the water from the aquifer prior to using it in a fracturing processes.

Abstract: The method disclosed herein includes the introduction of proppant-free stage and a proppant laden stage into the wellbore and/or subterranean formation. The method increases the effective fracture width and enhances fracture conductivity within the formation. Either the proppant-free stage or the proppant laden stage contains a breaker. The other stage contains a viscosifying polymer or viscoelastic surfactant to which the breaker has affinity. The proppant-free stage may be introduced prior to introduction of the proppant laden stage into the wellbore and/or formation. Alternatively, the proppant laden stage may be introduced into the wellbore and/or formation prior to introduction of the proppant-free stage.

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

Abstract: A fluid system for hydraulic fracturing operations which comprises a low residue fluid that facilitates the clean up of the wellbore following the treatment is disclosed. The system includes a surfactant compound that forms micelles above a critical concentration. Under certain conditions the addition of an associative thickener compound yields a network based on hydrophobic interactions. The resulting viscous fluid can transport proppants, be applied neat or as a foamed or energized system, or used in an acidizing treatment. The fluid system may further include a breaker additive.

Abstract: Methods of forming gravel packs while reducing fluid loss to the surrounding subterranean formation. The methods involve suspending gravel that has been coated with a tackifying agent and degradable fines into a low viscosity carrier fluid and then placing that suspension into a subterranean formation so as to form a gravel pack wherein, as the gravel pack is placed, the degradable fines to de-adhere from the gravel and to fill at least a portion of the pore spaces within the gravel pack so as to reducing fluid loss through the gravel pack.

Abstract: A method for the controlled delivery of a fracturing fluid to a well bore comprises formulating an aqueous base fluid such that it meets or exhibits desired physical and chemical characteristics for an optimal fracturing fluid. The formulation of the aqueous base fluid max involve commingling one or more sources of waste water with a source of fresh water followed by controlled injection of one or more additives. This process is substantially completed prior to delivering the aqueous base fluid to the well site. This allows the delivery of an optimal volume of the aqueous base fluid with homogeneously blended additives to the well bore.

Abstract: A solid zirconium cross-linking agent is prepared comprising zirconium and hydroxyalkylated ethylene diamine ligand. Use of the cross-linking agent in compositions for oil field applications such as hydraulic fracturing and plugging of permeable zones is also disclosed.

Abstract: A solid zirconium cross-linking agent and use in a cross-linking composition in oil field applications such as hydraulic fracturing and plugging of permeable zones. The zirconium cross-linking agent is prepared by a process comprising contacting a zirconium complex with an alkanolamine and water at particular mole ratios of alkanolamine and water to zirconium.

Abstract: A method of and an apparatus for treating a near zone and/or a far zone of a well is disclosed. The method comprises the following steps. (1) A tube that is permeable to a material is placed inside a wellbore, forming an annulus inside the wellbore. (2) A setting section surrounded by a sleeve is placed inside the tube. The sleeve is expandable and impermeable to the material. (3) The sleeve is inflated so that the sleeve is in contact with the tube, ensuring that the first zone of the tube is impermeable to the material, but leaving a second zone permeable to the material. (4) A treatment fluid is pumped to the zones that passes through the second zone still permeable to the material. (5) The near zone in the annulus and/or the far zone in the surrounding formation is treated with the treatment fluid.

Abstract: Methods for treating a formation penetrated by a wellbore which improves fluid loss control during treatment. In some aspects, the treatments include preparing an aqueous fluid including one or more water inert polymers and an optional viscosifier, injecting the aqueous fluid into the wellbore at a pressure equal to or greater than the formation's fracture initiation pressure, and thereafter injecting into the wellbore a proppant laden fluid at a pressure equal to or greater than the formation's fracture initiation pressure. The water inert polymer may be a polymer such as an emulsion polymer or a latex polymer. Some methods of the invention use a fluid which may have a normalized leak off coefficient (Cw/sqrt(K)) equal to or less than about 0.0022, 0.0014, or 0.0010. A conventional fluid loss additive may or may not be used in conjunction with the treatment fluid and/or the proppant laden fluid. The water inert polymer may or may not substantially enter formation pores.

Abstract: Proppants used to prop open subterranean formation fractions. Proppant formulations using one or more proppants. Methods to prop open subterranean formation fractions and other uses for the proppants, as well as methods of making the proppants.

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 solubilize hydrocarbons, emulsions or water blocks present in the underground formation, and (ii) at least a portion of the organic acid precursor to hydrolyze 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: The present invention relates to aqueous oilfield treatment fluids containing a gas component and fibers, wherein the fluids may further include a viscosifying agent and/or proppant. The fluids have good proppant suspension and transport properties as well as excellent gas phase stability. Use of fluids comprising an aqueous medium, a gas component, viscosifying agent, and fibers for hydraulically fracturing a subterranean formation, cleanup operations, and gravel packing a wellbore, are also disclosed.

Abstract: A process is provided for reducing the pressure for injecting a solution of water-soluble polymer from a given injection pump into various oil wells in a given field as a function of the fracturation pressure for each well according to which, between the injection pump and each well, a main volumetric pump is placed, whose rate is controlled using a brake.

Abstract: A method of improving natural gas release from a well via an enhanced hydraulic fracturing operation. The method includes capturing or retrieving the flow back from the well following the fracturing operation. The flow back or other source water is introduced to an electrocoagulation (“EC”) treatment process. EC treatment separates the water from other fracturing fluid components in the flow back and also removes bacteria and other contaminants. Thereafter, the EC-treated fluid is recycled for subsequent fracturing operations. The process may also be used to treat all source water, including fresh water delivered to the well before it is used as a fracturing fluid.

Abstract: The present invention relates to a proppant for the hydraulic fracturing of oil or gas wells, which consists of a mixture of from 10 to 95% by weight of a spherical proppant and from 5 to 90% by weight of an angular material, the percentages being based on the total weight of the mixture. The proppant obtained according to the present invention is useful for eliminating or decreasing the “flow-back” phenomenon in operations in oil or gas wells.

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: The present invention relates to methods and compositions for carrier fluids comprising water-absorbent fibers. One embodiment of the present invention provides a method of treating a portion of a subterranean formation, comprising providing a slurry wherein the slurry comprises a servicing fluid, particulates, and a degradable, water-absorbent material wherein the degradable, water-absorbent material acts to help keep the particulates from settling out of the slurry; and, introducing the slurry into the portion of the subterranean formation. Another embodiment of the present invention provides a slurry suitable for use in subterranean operations comprising a servicing fluid, particulates, and a degradable, water-absorbent material wherein the degradable, water-absorbent material acts to help keep the particulates from settling out of the slurry.

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

Abstract: A proppant consists of a core part and shell of a material different from the material of the core part. The shell comprises a soft material attached rigidly to the core part in such a way that the total surface area of the points where the shell and the core part are joined is less than the surface area of the core part.

Abstract: A method includes identifying application parameter(s) including a subterranean formation temperature, determining a breaker particle size in response to the application parameter(s), providing a treatment fluid including a carrier fluid and a granular breaker sized according to the breaker particle size, and treating the subterranean formation with the treatment fluid. The granular breaker is a metallic peroxide which may be an alkaline peroxide and/or zinc peroxide. The application parameter(s) may further include a flowback wait time, a composition of the metallic peroxide, a gel loading of the carrier fluid, and a permeability of the subterranean formation. The breaker particle size may include a breaker large particle size that is not greater than 25% larger than a breaker small particle size. At least 90% of the breaker particles may be sized between the breaker small particle size and the breaker large particle size.

Abstract: Subterranean treatment fluids that exhibit enhanced particulate transport or suspension capabilities, and associated methods of use in certain subterranean treatments are provided. In one embodiment, the methods comprise: providing a linear gelled fluid that comprises an aqueous base fluid, a plurality of particulates, and a linear particulate transport enhancing additive, the linear gelled fluid having a certain yield stress, crossover frequency, and/or particulate settling time; introducing the linear gelled fluid into the subterranean formation; and using the linear gelled fluid to create or enhance at least one fracture in at least a portion of the subterranean formation.

Abstract: A technique includes running a string into a well bore and inhibiting formation face failure. The well bore extends at least partially through a non-producing layer and a hydrocarbon formation layer. The inhibiting of the formation face failure includes communicating a proppant into the well bore via the string until a well bore pressure exceeds a first formation stress of the non-producing layer, which causes a fracture to form in the non-producing layer, and communicating the proppant into the fracture to create a barrier layer.

Abstract: A method for breaking a fracturing fluid includes identifying application parameter(s) including a subterranean formation temperature, and determining an acid precursor concentration in response to the application parameter(s). The method further includes providing a treatment fluid including a carrier fluid, a metallic peroxide breaker, and an amount of an acid precursor according to the acid precursor concentration, and treating the subterranean formation with the treatment fluid. The application parameter(s) may further include a flowback wait time, a composition of the metallic peroxide breaker, a gel loading of the carrier fluid, and/or a permeability of the subterranean formation. The metallic peroxide breaker may include an alkaline peroxide and/or a zinc peroxide. The acid precursor may include polylactic acid and/or polyglycolic acid.

Abstract: Elimination of sand entrainment and a significant increase in hydrodynamic permeability of the sand pack in an area near the wellbore are achieved through the use of a sand and/or proppant, and proppant material mixture at the final stage of the fracture filling process, where individual particles of the proppant material have at least one shape of plates, lattices, hollow bars, inside-hollow tubes with a closed impermeable cavity or cavities, toroidal particles, elongated particles in the form of ovals, pellets or plates, cylinders with a closed impermeable cavity or cavities, or blocks with a comb multi-channel structure with throughout channels of the ellipse or polygon cross-section.

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 method of treating a subterranean formation penetrated by a wellbore is carried out by forming a treatment fluid comprising an aqueous carrier fluid and a solid-form polyimide homopolymer or copolymer capable of hydrolyzing to form polycarboxylates and/or polycarboxylic acids. The treatment fluid is introduced into the formation through the wellbore. In another method, a treatment fluid comprising an aqueous carrier fluid, a solid-form polysuccinimide homopolymer or copolymer and at least one of a viscosifying agent, proppant and an acid capable of dissolving materials of the formation is formed. This is introduced into the formation through the wellbore. A method of treating a sandstone-containing formation penetrated by a wellbore may also be carried out by forming a treatment fluid comprising an aqueous solution containing a hydrogen fluoride source, ammonium hydroxide and at least one of a polyimide and a polycarboxylate, which is introduced into the formation through the wellbore.