Abstract: A wellbore fluid comprises an aqueous carrier liquid, hydrophobic fibers suspended therein, hydrophobic particulate material also suspended in the carrier liquid, and a gas to wet the surfaces of the particles and fibers and bind them together as agglomerates. The wellbore fluid may be a slickwater fracturing fluid and may be used for fracturing a tight gas reservoir. Using a combination of hydrophobic particulate material, hydrophobic fibers and gas inhibits settling out of the particulate material from an aqueous liquid. Because the gas acts to wet the surfaces of both materials and agglomerates them, the particulate material is made to adhere to the fibers; the fibers form a network which hinders settling of the particulate material adhering to them, and the agglomerates contain gas and so have a bulk density which is less than the specific gravity of the solids contained in the agglomerates.

Abstract: A plurality of particles comprising an elastomer-modified crosslinked aromatic epoxy vinyl ester polymer, wherein a particle from the plurality of particles maintains at least 50 percent of its height under a pressure of 1.7×107 Pascals at a temperature of at least 150° C. is disclosed. Mixtures of the plurality of particles and other particles, fluids containing the plurality of particles, methods of making the plurality of particles, and methods of fracturing a subterranean geological formation are also disclosed.

Abstract: A plurality of particles comprising a crosslinked aromatic epoxy vinyl ester polymer, wherein a particle from the plurality of proppant particles swells not more than 20 percent by volume when submerged in toluene for 24 hours at 70° C. is disclosed. A plurality of particles comprising a crosslinked aromatic epoxy vinyl ester polymer, wherein a particle from the plurality of particles maintains at least 75 percent of its height under a pressure of 1.7×107 Pascals up to at least 135° C. is also disclosed. Mixtures of the plurality of particles and other particles, fluids containing the plurality of particles, methods of making the plurality of particles, and methods of fracturing a subterranean geological formation are also disclosed.

Abstract: Use of two different methods, either each by itself or in combination, to enhance the stiffness, strength, maximum possible use temperature, and environmental resistance of thermoset polymer particles is disclosed. One method is the application of post-polymerization process steps (and especially heat treatment) to advance the curing reaction and to thus obtain a more densely crosslinked polymer network. The other method is the incorporation of nanofillers, resulting in a heterogeneous “nanocomposite” morphology. Nanofiller incorporation and post-polymerization heat treatment can also be combined to obtain the benefits of both methods simultaneously. The present invention relates to the development of thermoset nanocomposite particles.

Abstract: The invention pertains to improved proppant particles comprising an aromatic polycondensation polymer having a glass transition temperature (Tg) of at least 120° C. when measured according to ASTM 3418 [polymer (P)] and a method of treating a subterranean formation using said proppant particles.

Abstract: Fluorinated polymers having first divalent units represented by formula, and a plurality of groups of formula —CH2—CH2—O—. Compositions containing the fluorinated polymer and solvent, and methods of treating hydrocarbon-bearing formations using these compositions are disclosed. A method of making a composition containing the fluorinated polymer is also disclosed.

Abstract: A method of servicing a wellbore comprising placing a composition comprising an emulsified resin composite into a fluid loss zone of the wellbore, wherein the emulsified resin composite comprises a nonaqueous external phase (NEP) and an aqueous internal phase (AIP), and allowing the composition to cure to form a composite material.

Abstract: Proppant materials, and methods for making proppant materials, are provided. In one embodiment, the proppant material comprises a substrate material, a polymeric material disposed on the substrate material and a surface wettability modifier disposed on the polymeric material. Methods of making and using the proppant materials are also disclosed.

Abstract: A proppant comprises a particle and a polycarbodiimide coating disposed on the particle. The polycarbodiimide coating comprises the reaction product of an isocyanate reacted in the presence of a phospholene oxide catalyst. A method of forming the proppant comprises the steps of providing the particle, providing the isocyanate, providing the phospholene oxide catalyst, reacting the isocyanate in the presence of the phospholene oxide catalyst to form the polycarbodiimide coating, and coating the particle with the polycarbodiimide coating.

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: A method is given for heterogeneous proppant placement in fracturing by in situ aggregation of fine mesh proppant particulates or other materials such as fibers in a subterranean fracture. A polymer is injected into a subterranean formation and is subsequently subjected to a chemical reaction, for example hydrolysis, under downhole conditions, which leads to formation of either a cationic or an anionic polyelectrolyte. Alternatively, the polyelectrolyte is synthesized downhole by, for example, a Hofmann degradation or a Mannich reaction. The polyelectrolyte acts as a flocculant and provides aggregation of solid particulates such as sand, mica, silica flour, ceramics and the like, which leads to formation of proppant micropillars deep in the fracture. Methods of aggregation of fibers to enhance bridging, and other applications of controlled flocculation are also given.

Abstract: In a method of hydraulically fracturing a hydrocarbon-bearing subterranean formation, a proppant stage is introduced into the fracture which contains a gaseous fluid and an ultra lightweight proppant suspended in a viscosified aqueous fluid. The gaseous fluid of the proppant stage contains at least about 90 volume percent of the combination of gaseous fluid and aqueous fluid. A pad fluid may first be introduced into the formation, the pad fluid containing a gaseous fluid and, optionally, an aqueous fluid. The gaseous fluid of the pad fluid mixture typically contains at least 70 volume percent of the mixture.

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 is given for fracturing a formation, in particular far-field in a tight formation, in which at least a portion of the proppant is crushable in situ at some point during pumping, during fracture closure, or at higher Fluid flow stresses experienced later during fracture closure. The closure stress or hydrostatic stress is estimated, then a proppant is selected that is at least partially crushable at that closure stress, and then the fracturing treatment is performed with at least a portion of the total proppant being the selected crushable proppant.

Abstract: Fiber aggregate comprising organic polymeric fibers, wherein the organic polymeric fibers have an average length in a range from 2 to 20 millimeters, an average diameter up to 100 micrometer, and comprise at least 75 percent by solid volume of the fiber aggregate, wherein the fiber aggregate has an unrestrained bulk density of at least 0.05 g/cm3, and wherein at least 85% by volume of the fiber aggregate disassociates to provide dispersed fibers. The fiber aggregates are useful, for example, for flowback control in wellbores and reservoirs.

Abstract: Compositions and methods for determining the source of treatment fluids being produced from a production formation having multiple zones by introducing a treatment composition having a tracking material into a zone in the subterranean formation, and detecting the tracking material in treatment composition that flows back from the subterranean formation.

Abstract: Methods for treating a subterranean formation can comprise introducing a treatment fluid comprising dicarboxymethyl glutamic acid (GLDA) or a salt thereof into a subterranean formation comprising a carbonate mineral, and at least partially dissolving the carbonate mineral in the subterranean formation using the GLDA. Treatment fluids containing GLDA or a salt thereof may be used to increase the permeability of a subterranean formation.

Abstract: Methods for treating a subterranean formation can comprise introducing a treatment fluid comprising dicarboxymethyl glutamic acid (GLDA) or a salt thereof into a subterranean formation, the treatment fluid having a pH equal to or greater than about 2. Fluids suitable for treating a subterranean formation can comprise water, GLDA or a salt thereof, and a surfactant.

Abstract: In one aspect, this invention provides a method for the in-situ production of natural gas, light crude oil, or sequences or mixtures thereof, comprising the steps of: (a) suspending a catalytic polymer bead in a fracturing medium, wherein said catalytic polymer bead is nearly neutrally buoyant in said fracturing medium; (b) introducing said suspension into a formation at sufficiently high rates and pressures that the formation fails and fractures to accept said suspension; and (c) collecting the natural gas, light crude oil, or sequences or mixtures thereof, generated by the subterranean formation. In another aspect, this invention provides compositions of matter for said catalytic polymer beads. In yet another aspect, this invention provides processing methods for producing said catalytic polymer beads.

Abstract: A method for fracture stimulation of a subterranean formation includes providing a thermoset polymer nanocomposite particle precursor composition comprising a polymer precursor mixture, dispersed within a liquid medium, containing at least one of an initiator; at least one of a monomer, an oligomer or combinations thereof, said monomer and oligomer having three or more reactive functionalities capable of creating crosslinks between polymer chains; at least one of an impact modifier; and nanofiller particles substantially dispersed within the liquid medium; subjecting the nanocomposite particle precursor composition to suspension polymerizing conditions; subjecting the resulting nanocomposite particles to heat treatment; forming a slurry comprising a fluid and a proppant that includes the heat-treated nanocomposite particles; injecting the slurry into a wellbore; and emplacing the proppant within a fracture network in the formation.

Abstract: Reduction of the water permeability within a subterranean formation, particularly within a proppant pack or a gravel pack, can be achieved through the use of a relative permeability modifier (RPM) coated on a particulate material. Methods for reducing the water permeability include providing RPM-coated particulates that contain a RPM coating on the particulates, and placing a treatment fluid containing a base fluid and the RPM-coated particulates in at least a portion of a subterranean formation. The treatment fluid can also contain a companion polymer that serves to further reduce the water permeability compared to that achievable when using the RPM alone.

Abstract: A method of placing proppant into a fracture formed in a subterranean formation from a wellbore is disclosed. The method comprises injecting through the wellbore a first treatment fluid to initiate the fracture in the subterranean formation; injecting through the wellbore a second treatment fluid comprising a particulate blend slurry made of proppant; the particulate blend comprising at least a first amount of particulates having a first average particle size between about 100 and 5000 ?m and at least a second amount of particulates having a second average particle size between about three and twenty times smaller than the first average particle size; and forming with the particulate blend slurry a plurality of proppant-rich clusters spaced apart by proppant-free regions forming open channels.

Abstract: Disintegrative particles are designed to be blended with and pumped with typical proppant materials, e.g. sand, ceramics, bauxite, etc, into the fractures of a subterranean formation. With time and/or change in wellbore or environmental condition, these particles will either disintegrate partially or completely, in non-limiting examples, by contact with downhole fracturing fluid, formation water, or a stimulation fluid such as an acid or brine. Once disintegrated, the proppant pack within the fractures will lead to greater open space enabling higher conductivity and flow rates. The disintegrative particles may be made by compacting and/or sintering metal powder particles, for instance magnesium or other reactive metal or their alloys. Alternatively, particles coated with compacted and/or sintered nanometer-sized or micrometer sized coatings could also be designed where the coatings disintegrate faster or slower than the core in a changed downhole environment.

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: 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: During a hydraulic fracturing treatment operation, one of three operational parameters may be modified in a successive stage by adjustment of another operational parameter to attain a fracture of length DPST. The operational parameters include the proppant size, viscosity of the transport fluid and injection rate of the transport fluid.

Abstract: Coacervate gels having excellent shear viscosities and other properties are made with anionic or cationic polymers, a smaller amount of a surfactant having a charge opposite that of the polymer, and a hydrophobic alcohol and an effective amount of a phosphorus-containing compound sufficient to increase the viscosity of coacervate gels up to 3 times as compared to the gels in the absence of the phosphorus-containing compound. The Zeta Potential of the gel is maintained at an absolute value of at least 20. Optional gel promoting additives include betaines and amine oxides. A preferred gel comprises poly diallyl dimethyl ammonium chloride, a lesser amount of sodium lauryl sulfonate, and lauryl alcohol. The gels are particularly useful in well drilling fluids and well fracturing fluids.

Abstract: This invention provides a process for coating particulate solids with a curable novolac resin without employing heat as a step of the process, comprising placing an epoxy resin which is curing on the particulate followed by placing a novolac resin capable of being heat cured on the epoxy resin before curing of the epoxy resin is complete.

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 making resin-coated proppants comprising applying epoxy and phenol resins with a curing agent onto the surface of proppants. The epoxy and phenol resins with the curing agent are applied onto the surface of the mix of proppants. The mix of proppants is obtained by blending heavy proppants with bulk density of 1.4 g/cm3 and more, with lightweight proppants with bulk density of less than 1.4 g/cm3. The application of the epoxy and phenol resins is performed at temperatures from 5 to 35. degrees Celsius.

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: Viscoelastic compositions are disclosed herein containing an effective amount of one or more random or structurally defined polycationic quaternary ammonium compounds for controlling the viscoelasticity of the composition. In one aspect, the present technology provides polycationic quaternary ammonium compounds that comprise bis-quaternary compound. The bis-quaternary compounds of the present technology can be symmetric or dissymmetric. In another aspect, the present technology provides viscoelastic well bore treatment fluids comprising water, and at least one polycationic quaternary ammonium compound that comprises a bis-quaternary compound. In another aspect, the present technology provides polycationic carboxylates. Preferred viscoelastic compositions of the present technology maintain viscoelasticity at a temperature greater than about 80° C., preferably greater than about 100° C. or 110° C.

Abstract: A slurry and method are disclosed for low damage gravel packing. The slurry comprises a solids mixture comprising a plurality of volume-averaged particle size distribution (PSD) modes such that a packed volume fraction (PVF) exceeds 0.75; a carrier fluid in an amount to provide a solids volume fraction (SVF) less than the PVF of the solids mixture; and a stability additive to inhibit settling of the solids mixture. The method comprises circulating the slurry into a wellbore to deposit the slurry downhole; terminating the slurry circulation for a period of time, wherein the stability additive inhibits settling of the solids mixture; and thereafter circulating the deposited slurry in contact with a surface of a screen. Stability additives disclosed include colloidal particles, hydratable polymer particles, and particles having an aspect ratio above 6.

Abstract: An improved proppant and method of use are shown for use in wellbore operations in which a well is hydraulically fractured with a suitable fluid to create fractures in a surrounding subterranean formation where the proppant is used to hold the fracture open and provide a conduit for the production of fluids or gases. The improved proppant has associated therewith a chemically active adjunct material designed to react with the fracturing fluid, with the surrounding subterranean formation or with a fluid produced from the subterranean formation. The chemically active adjunct material may be an ion exchange resin which reacts with any multivalent ions released into solution by reaction of the fracturing fluid with the surrounding formation or with any multivalent ions dissolved in formation fluids, in order that these fluids being produced from the well will not contain these ions, requiring more exotic treatment procedures on the well surface.

Abstract: The disclosed invention relates to a process of using molten salt ion exchange to treat particles such as spherically shaped soda-lime-silica glass particles. The treated particles may be used as proppants in hydrofractured oil and natural gas wells.

Abstract: Non-spherical particulates are useful in the stimulation of subterranean formations. A proppant pack composed of the non-spherical particulates exhibits greater porosity than a corresponding proppant pack composed of spherical particulates. Non-spherical particulates which are hollow and non-porous may further be at least partially filled with a chemical treatment agent including water-soluble or oil-soluble chemical treatment agents.

Abstract: Methods of making particulates for use in a subterranean application comprising: providing particulates of a settable composition comprising a cementitious material, a filler material, and an activator of the cementitious material; and pre-curing the particulates until the particulates reach a crush strength of about 50 psi or greater; and curing the pre-cured particulates at a temperature in the range of about 230° F. to about 600° F., so that at least a portion of the particulates comprise a newly formed crystalline phase.

Abstract: The invention discloses a storable composition for oilfield application including a slurry of a carrier fluid and a particulate blend made of proppant; the particulate blend comprising at least a first amount of particulates having a first average particle size between about 100 and 5000 ?m and at least a second amount of particulates having a second average particle size between about three and twenty times smaller than the first average particle size; such that a packed volume fraction of the particulate blend exceeds 0.74 and the particulate blend volume is sufficient to substantially avoid settling of the particulate in the carrier fluid.

Abstract: A consolidation agent for molded articles and geological formations from porous or particulate materials, containing a hydrolysate or precondensate of (a) at least one organosilane of the general formula (I) RnSiX4-n??(I) in which the radicals R are identical or different and are not hydrolytically removable groups, the radicals X are identical or different and are hydrolytically removable groups or hydroxyl groups, and n is 1, 2 or 3, and optionally (b) at least one hydrolyzable silane of the general formula (II) SiX4??(II) in which the radicals X have the meaning defined above.

Abstract: Solid material required at a subterranean location is supplied from the surface suspended in a carrier liquid and agglomerated below ground by means of a binding liquid. To achieve agglomeration, the binding liquid and the particulate solid are similar to each other but opposite to the carrier liquid in hydrophilic/hydrophobic character. The solid and the binding liquid may both be hydrophobic while the carrier liquid is hydrophilic, or vice versa. The solid may be hydrophobically surface modified to render it hydrophobic. The binding liquid may be provided as a precursor which converts to the binding liquid below ground to trigger agglomeration after arrival at the subterranean location. The agglomerates may function as proppant heterogeneously placed in a fracture of a reservoir, or may serve to block an unwanted path of flow. The binding liquid may polymerise after agglomeration so as to stabilise and strengthen the agglomerates.

Abstract: Lightweight polyamide particulates may be used in treatment of subterranean formations, including hydraulic fracturing and sand control methods, such as gravel packing. The polyamide particulates typically have an apparent specific gravity (ASG) between from about 1.05 to about 2.0 and are stable at temperatures up to 500° C. The polyamide particulates may be used in combination with a filler which further serves to increase the strength and temperature stability of the resulting composite. Fracture conductivity may be increased by the placement of the low density polyamide particulates as a partial monolayer.

Abstract: Treatments and compounds useful in subterranean formations are discussed, with particular attention to those utilizing ceramic coated particulates. Certain embodiments pertain to particulates and particulate packs with ceramic coatings of subatomic thickness. Of these, certain methods may utilize ceramic coatings on particulates in a subterranean formation, certain methods may utilize ceramic coatings on particulate packs in a subatomic formation, and certain compounds may provide the features of both ceramic coatings and particulates.

Abstract: Prior to a hydraulic fracturing treatment, the requisite apparent viscosity of a transport fluid, ?fluid, containing a proppant for a desired propped fracture length of a fracture, DPST, may be estimated in accordance with Equation (I): ?fluid=(1/A)×qi×(1/DPST)B×(CTRANS)×(?SGPS)×(d2prop)??(I) wherein: A is the multiplier and B is the exponent from the Power Law equation of velocity of the transport slurry vs. distance for the fracture geometry; qi is the injection rate per foot of injection height, bpm/ft; CTRANS is the transport coefficient; ?SGPS is SGprop?SGfluid, SGprop being the specific gravity of the proppant and SGfluid being the specific gravity of the transport fluid; and dprop is the median proppant diameter, in mm.

Abstract: A system and method are disclosed for low damage gravel packing. The system comprises a well bore; a gravel packing slurry comprising a carrier fluid and a solids mixture, wherein the solids mixture comprises a plurality of volume-averaged particle size distribution (PSD) modes such that a packed volume fraction (PVF) exceeds 0.75, wherein the solids mixture comprises at least a proppant PSD mode and a fines PSD mode; a pump to circulate the slurry in the wellbore and form a proppant pack; and a dispersant source effective to facilitate fines flowback from the pack. The method comprises circulating the slurry through a wellbore to form a proppant pack; contacting fines in the pack with a dispersant; and passing fluid through the pack to remove fines from the pack.

Abstract: A method of heterogeneous proppant placement in a subterranean fracture is disclosed. The method comprises injecting well treatment fluid including proppant (16) and proppant-spacing filler material called a channelant (18) through a wellbore (10) into the fracture (20), heterogeneously placing the proppant in the fracture in a plurality of proppant clusters or islands (22) spaced apart by the channelant (24), and removing the channelant filler material (24) to form open channels (26) around the pillars (28) for fluid flow from the formation (14) through the fracture (20) toward the wellbore (10). 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 in the fracture, and later dissolving to leave the flow channels between the proppant pillars.

Abstract: A substance and method for treating a subterranean formation using hydraulic fracturing. A non-metallic, substantially deformable, proppant particle is “elastically flexible” or “plastically compressible” and adapted for use at concentrations which will substantially create a partial monolayer.

Abstract: The invention provides economically effective methods for hydraulic fracturing a subterranean formation that ensure improvement of the hydraulic fracturcconductivity because of forming strong proppant clusters uniformly placed in the fracture throughout its length. One of these methods comprises: a first stage that involves injection into a borehole of fracturing fluid containing thickeners to create a fracture in the formation; and a second stage that involves periodic introduction of proppant into the injected fracturing fluid to supply the proppant into a created fracture, to form proppant clusters within the fracture to prevent fracture closure and channels for flowing formation fluids between the clusters, wherein the second stage or its sub-stages involve additional introduction of either a reinforcing or consolidation material or both, thus increasing the strength of the proppant clusters formed into the fracture fluid.

Abstract: A composite proppant having an increased buoyancy comprising a proppant substrate such as a porous ceramic or a silica sand coated with a material of a lesser actual density than the apparent density of the proppant substrate to increase the buoyancy of the composite proppant.

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: Among the methods described herein are methods using low-specific gravity particulates wherein the particulates comprise silica and an aluminum oxide in an amount of about 0.1% to about 25% by weight and having at least one void, a specific gravity of less than about 2.2, a particle sized of 8 U.S. Mesh or smaller, and a substantially spherical shape.