Abstract: One aspect of an emulsion includes an internal phase including acid, an external phase including supercritical carbon dioxide, and multiple nanoparticles to stabilize the internal phase and the external phase. The acid can include hydrochloric acid. The hydrochloric acid can include 15% hydrochloric acid. The nanoparticles can include hydrophobic nanoparticles. A concentration of nanoparticles in the emulsion can be at least 0.1% by weight. The emulsion can include a corrosion inhibitor. A concentration of the corrosion inhibitor can be in a range of between 0.25% and 0.6% by volume. A ratio of a concentration of the acid to a concentration of the supercritical carbon dioxide can be in a range between 30% and 70%.

Abstract: Methods for treating a shale formation may include injecting a pad fluid including a shale stabilizing agent into a shale formation to generate one or more fractures. The method may also include injecting a fracturing slurry including proppant particulates into the one or more generated fractures such that the proppant particulates form microfractures along shale fracture faces. At least a portion of the proppant particulates may be at least partially coated with at least one oxidizing agent.

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 (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 material (24), and removing the filler material (24) to form open channels (26) around the pillars (28). The filler material can be dissolvable particles, initially acting as a consolidator during placement of the proppant in the fracture, and later dissolving to leave flow channels between the proppant pillars. The well treatment fluid can include extrametrical materials to provide reinforcement and consolidation of the proppant and, additionally or alternatively, to inhibit settling of the proppant in the treatment fluid.

Abstract: The present invention relates to the well drilling field in petroleum industry, in particular to a nano-hybrid lubricant and method thereof, and oil-based drilling fluid. The lubricant comprises: graphite oxide and a biquaternary ammonium salt compound of which the cation part is represented by formula (1). The present invention also provides a method for preparation of the lubricant and an oil-based drilling fluid containing the lubricant. The lubricant provided in the present invention can be comprehended as a nano-hybrid material. Thus, oil-based drilling fluids that contain the lubricant provided in the present invention have lower lubrication coefficient and excellent lubricating property without or with little negative impact on rheological property of the oil fluid, and the lubricant provided in the present invention has excellent thermostability thus suitable for use in operation at a high temperature.

Abstract: An aqueous slurry composition for use in industries such as the petroleum and pipeline industries includes a particulate, an aqueous liquid and a chemical compound that renders the particulate surface extremely hydrophobic. The slurry is produced by rendering the surface of the particulate extremely hydrophobic during or before making the slurry.

Abstract: The present disclosure provides for shape memory proppants, methods for making shape memory proppants, and methods of using shape memory proppants, and the like. The strong expandable proppants of the present disclosure may be used in maintaining fracture openings.

Abstract: The invention relates to a method of generating an enhanced fracture network in a rock formation by the sequential stages of: i) injecting a non-slurry aqueous solution into a well extending into the formation at a rate and pressure which is close to the minimum hydraulic fracture initiation pressure and rate of the formation, until the maximum possible stimulated volume of the formation has been substantially attained to generate an outer zone of self-propping fractures; ii) injecting a first slurry of relatively fine grains of proppant to prop fractures generated in stage i within an intermediate zone located within and surrounded by the outer zone generated in stage i; and iii) injecting a second slurry comprising relatively coarse grains of to generate large fractures within an inner zone surrounded by and within the intermediate zone, in communication with the fractures generated in stages i and ii.

Abstract: A hydraulic fracturing and gravel packing proppant composite with protectant on the surface of the proppant and the composition matters of the protectant and proppant. The surface protectant reduces the generation of dust/fines from the proppant caused by abrasion and impingement during transportation and conveyance, particularly pneumatic transfer.

Abstract: Embodiments relate to preparation of expandable particulates and their use in fracturing operations. An embodiment provides a method for treating a subterranean formation comprising: introducing a treatment fluid comprising expandable particulates into the subterranean formation, wherein the expandable particulates each comprise a particulate substrate, a swellable material coating the particulate substrate, and an exterior coating comprising a resin; and depositing at least a portion of the expandable particulates in the subterranean formation.

Abstract: Dual-function nano-sized particles or nanoparticles may be effective at fixating or reducing fines migration and they may facilitate identification of a particular zone in a well having more than one zone. In some embodiments the dual-function nanoparticles are tagged with a detectable material that is distinguishable from the composition of the primary nanoparticle component. In these embodiments, the taggant material rather than the primary component of the nanoparticles may be used to enable identification of a particular zone. The nanoparticles (with or without taggant) may be added to a treatment fluid containing carrier particles such as proppant. The treatment fluid is pumped downhole to one of the zones; each zone receiving its own unique or uniquely-tagged nanoparticles. Should one of the zones fail, the composition of the nanoparticles (or its taggant) produced on the carrier particles may be correlated to the zone from which it was received, and hence produced.

Abstract: A method for forming particles having a ridge portion includes inducing flow of a slurry of particles and a reactant through one or more orifices, detaching an amount of the slurry from the slurry flow following exit from the one or more orifices, the detached amount forming a slurry body, forming the slurry body into a particle shape, contacting the particle shaped slurry body with a coagulation solution to form a stabilized particle having the ridge portion, and drying and/or sintering the particle having the ridge portion.

Abstract: A method of enhancing conductivity within a hydrocarbon-bearing reservoir by building proppant pillars in a spatial arrangement in fractures created or enlarged in the reservoir. Two fluids of differing viscosity and stability are simultaneously pumped into the reservoir. The fluids contain identical proppants which include a proppant which is neutrally buoyant in the fluid and a proppant which is not neutrally buoyant in the fluid. Vertically extending pillars are created within the formation when the fluids are destabilized and the heavier proppant is then released from the destabilized fluids. The area between the pillars may be held open by the presence of the neutrally buoyant proppant in the remaining fluid. Fluid produced from the hydrocarbon-bearing reservoir is then flowed at least partially through channels between the vertically extending pillars.

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: Hydrophobically modified amine-containing polymers (“HMAP”) may be useful in mitigating scale buildup in a subterranean formation. For example, a method may include preparing a treatment fluid that comprises a base fluid and a plurality of HMAP-coated particulates that comprise particulates at least partially coated with an HMAP, wherein the HMAP comprises a plurality of hydrophobic modifications on an amine-containing polymer; introducing the treatment fluid into a wellbore penetrating a subterranean formation; forming a particulate pack that comprises at least some of the HMAP-coated particulates; and inhibiting scale buildup on the HMAP-coated particulates.

Abstract: Energy recovery medium for insertion into a ground hole in a ground comprising a recoverable energy carrying medium, wherein the energy recovery medium comprises a base liquid, a carbohydrate-based thickener mixed in the base liquid, a salt dissolved in the base liquid and configured for increasing a density of the base liquid, and proppant particles dispersed within the mixture of the base liquid, the thickener and the salt.

Abstract: There is provided synthetic proppants, and in particular polysilocarb derived ceramic proppants. There is further provided hydraulic fracturing treatments utilizing these proppants, and methods of enhance hydrocarbon recovery.

Abstract: Fracturing slurries are prepared on the fly using a solids pump to feed the solid such as a gel into a liquid stream of normally water for pumping downhole with a large capacity triplex pump. The solids pump is preferably a Posimetric® style which delivers the solid into the fluid pipeline in a manner that keeps fluid from backing into the solids hopper above the solids pump. A separate fluid tank is connected to a fluid pump to pressurize a suction line to a boost pump before reaching the triplex pump and pumping into the subterranean formation. The solids pump can deliver between the fluid and boost pumps in which case the solids go through the triplex pump or alternatively the solids can be delivered into the higher pressure discharge line of the triplex pump.

Abstract: Synthetic ceramic proppants are described. Proppants having a monodispersity of 3-sigma distribution or lower are also described, including methods to make these proppants and methods of using these proppants.

Abstract: Proppant particles formed from slurry droplets and methods of use are disclosed herein. The proppant particles can include a sintered ceramic material and can have a size of about 80 mesh to about 10 mesh and an average largest pore size of less than about 20 microns. The methods of use can include injecting a hydraulic fluid into a subterranean formation at a rate and pressure sufficient to open a fracture therein and injecting a fluid containing a proppant particle into the fracture, the proppant particle including a sintered ceramic material, a size of about 80 mesh to about 10 mesh, and an average largest pore size of less than about 20 microns.

Abstract: The present disclosure describes a recovery process using injector and producer wells, each well having means for varying the axial resistance to fluid flow to provide a complementary first and second annular axial fluid flow resistance profile. The recovery mechanism includes a gravity drainage component and also includes a convective flow mechanism which operate concurrently.

Abstract: Methods for controlling fluid flow through one or more pathways in one or more rock formations penetrated by a borehole in a subterranean well, comprise injecting into or adjacent to the formation a treatment fluid comprising at least one polysaccharide polymer; at least one crosslinker; and fibers, or a mixture of fibers and particles. The fluids are pumped into the well through a tubular body that comprises at least one flow restriction. Shearing of the treatment fluid as it passes through the flow restriction causes the viscosity to decrease, allowing the fibers to form masses that migrate to formation-rock openings such as pores, cracks, fissures and vugs. As a result, the fibrous masses are useful for curing lost circulation, providing fluid-loss control and as diverting agents.

Abstract: The invention provides for modified proppants, comprising a proppant particle and a hydrogel coating, wherein the hydrogel coating localizes on the surface of the proppant particle to produce the modified proppant, methods of manufacturing such proppants and methods of use.

Abstract: Fluids including a parylene-coated chemical entity and methods of treating a subterranean formation with such fluids are disclosed. The methods may include introducing a treatment fluid into a subterranean formation, the treatment fluid containing a parylene-coated particle having a chemical entity encapsulated therein.

Abstract: A relatively low density, high strength round proppant material having (i) a round core made of a sintered mixture of fly ash and clay or, in some instances, fly ash, clay, and bauxite; and (ii) an outer shell made of sintered bauxite, and a method of making the same.

Abstract: The invention provides a method and apparatus for use in a wellbore gravel pack operation. The method comprises providing an apparatus in a downhole annulus. The apparatus comprises a mandrel and a swellable element formed from a material selected to increase in volume when exposed to a downhole stimulus. The method comprises placing a gravel pack below the apparatus via the downhole annulus in which the apparatus is located, and placing a gravel pack above the apparatus. Subsequent to placing the gravel packs, the swellable element is increased in volume to create an annular barrier in the wellbore. The invention allows isolation of multiple intervals of a well in a single gravel pack operation using swellable elastomers, and does not rely on the use of shunt tube alternate path systems.

Abstract: A well treatment composite which allows for the slow release of one or more well treatment agents into a subterranean formation and/or a wellbore penetrating the formation has a nano-sized calcined porous substrate (adsorbent) of high surface area onto which is applied the well treatment agent. The composites are suitable for use in such well treatment operations as hydraulic fracturing and sand control.

Abstract: A method and system for increasing fracture conductivity. A treatment slurry stage has a continuous first solid particulate concentration and a discontinuous anchorant concentration between anchorant-rich substages and anchorant-lean substages within the treatment slurry stage.

Abstract: Proppants for hydraulic fracturing of oil and gas wells are coated with a polyurea-type coating. In a preferred embodiment, the polyurea-type coating is formed by contacting a polymeric isocyanate with an amount of water and a blowing catalyst at a rate and quantity sufficient to generate a reactive amine in situ on the outer surface of the proppant which thereby reacts with unconverted polymeric isocyanate to form a thin polyurea-type surface coating that is substantially solid and lacks foam or substantial porosity. Alternatively, the polyurea-type can be produced by selecting reactive amine compounds and isocyanates to develop the coated proppant. The coated proppants retain the discrete, free-flowing character of the original core solids but with the beneficial effects of the polyurea-type coating of the present invention.

Abstract: Methods of treating a wellbore in a subterranean formation including providing an aqueous treatment fluid comprising a liquid resin agent, wherein the liquid resin agent comprises the reaction product of a multifunctional electrophilic compound and at least one nucleophilic compound selected from the group consisting of a dimer acid; a dimer amine; any derivative thereof; and any combination thereof, and wherein the multifunctional electrophilic compound comprises least two electrophilic reactive groups; introducing the aqueous treatment fluid into the wellbore in the subterranean formation; and, curing the liquid resin agent.

Abstract: An aggregate processing assembly is provided. The processing assembly includes a separator assembly having a central member extending from a first end to a second end, the central member supporting at least one helical flight provided between the first and second ends, the helical flight having a width provided between a proximal end and a distal end. An assembly housing is provided around a portion of the separator assembly, the assembly housing includes a collection portion for receiving processed feed stock which exits the separator assembly radially away from the central member outward past the distal end, and the collection portion includes a first outlet. A second outlet is coupled to the separator assembly for receiving processed feed stock which exits the separator assembly at the second end of the at least one helical flight. A proppant, an aggregate, a system for processing feed stock to produce a proppant or aggregate, and a method of producing a proppant or aggregate is also provided.

Abstract: Systems and methods for treating a fluid with a body are disclosed. Various aspects involve treating a fluid with a porous body. In select embodiments, a body comprises ash particles, and the ash particles used to form the body may be selected based on their providing one or more desired properties for a given treatment. Various bodies provide for the reaction and/or removal of a substance in a fluid, often using a porous body comprised of ash particles. Computer-operable methods for matching a source material to an application are disclosed. Certain aspects feature a porous body comprised of ash particles, the ash particles have a particle size distribution and interparticle connectivity that creates a plurality of pores having a pore size distribution and pore connectivity, and the pore size distribution and pore connectivity are such that a first fluid may substantially penetrate the pores.

Abstract: A sintered, generally spherical ceramic body, having an alumina content of from about 52 to about 55 weight percent distributed substantially homogeneously throughout the body, a silica content from about 32 to about 38 weight percent distributed substantially homogeneously throughout the body, an apparent specific gravity of about 2.61 to about 2.65, and a bulk density of about 1.45 to about 1.56 grams per cubic centimeter.

Abstract: A method of treating a subterranean formation comprising generating a fracture in the subterranean formation, introducing a predetermined amount of proppant into a treatment fluid, and subsequently introducing a plugging agent into the treatment fluid before the entire predetermined amount of proppant reaches the fracture, minimizing overdisplacement of the proppant from the fracture.

Abstract: A pellet made from a mixture of natural occurring clays comprising porcelain clay, earthenware clay, and kaolin clay. In some embodiment, the pellet has an alumina content between about 5.5% and about 35%, an apparent specific gravity from about 2.10 to about 2.55 g/cc, and a bulk density of from about 1.30 to about 1.50 g/cc. The pellet is useful in hydraulic fracturing of oil and gas wells, and has greater conductivity than sand at pressures up to 8,000 psi as measured by Stim-Lab after 50 hours and 275° F. on Ohio Sandstone, in the presence of deoxygenated aqueous 2% solution of KCI.

Abstract: Methods and systems that may be employed to dynamically test the effect of fluids (e.g., well treatment chemicals such as well stimulation treatment chemicals, enhanced oil recovery “EOR” chemicals, etc.) on hydrocarbon recovery from crushed reservoir formation materials under conditions of applied stress. The disclosed methods and systems may be used in one embodiment to dynamically test types of low permeability formations (e.g., such as shale, limestone, quarried rock, etc.).

Abstract: Well treatment agents containing a particulate substrate are coated with a polyelectrolyte bilayer to provide a well treatment composite for use in well treatment operations. Each layer of the polyelectrolyte bilayer is composed of oppositely charged polyionic material. The well treatment composite may further contain a succession of polyelectrolyte bilayers, each polyelectrolyte bilayer containing layers of oppositely charged polyionic materials.

Abstract: The present invention provides modified proppants, and methods for their manufacture. In embodiments, the modified proppant comprises a proppant particle and a hydrogel coating, wherein the hydrogel coating is applied to a surface of the proppant particle and localizes on the surface to produce the modified proppant. In embodiments, formulations are disclosed comprising the modified particles, and methods are disclosed for using the formulations.

Abstract: A proppant having low surface friction is described, which is useful in hydrocarbon recovery. Methods of making low surface friction proppants are further described, as well as uses thereof.

Abstract: A controlled-release fertilizer composition is provided that is substantially coated with an impermeable layer. The fertilizer composition may further include one or more hollow sections to allow for root penetration and efficient delivery of nutrients.

Abstract: Methods of fracturing a subterranean formation comprising introducing a fracturing fluid into the subterranean formation at a pressure sufficient to create or enhance at least one fracture therein. And providing proppant aggregates themselves comprising proppant particles coated with a binding fluid and having foamed particulates adhered thereto that are suspended in gelled treatment fluid and placed into at least a portion of the fracture so as to form a proppant pack therein.

Abstract: The present invention is a cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas and a viscosity increasing additive. The liquefied industrial gas may be liquefied carbon dioxide, liquefied nitrogen, or a blend of the two. The liquefied industrial gas mixture should be substantially free of water. In this context, substantially free of water means less than 10% water by volume, or preferably less than 5% water by volume. In addition to the viscosity increasing additive, a proppant may be added to the fracturing fluid. In addition to the viscosity increasing additive and/or proppant additional additives may be added to the liquefied industrial gas as required.

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: An oil-gas well structure and a segmental flow-control method for a flow-control filter string (5) used in the oil-gas well. The segmental flow-control method for the flow-control filter string (5) comprises the following steps: 1) establishing a channel (2-1); 2) running the flow-control filter string (5); 3) filling with the anti-channeling flow pack-off particles (7); 4) sealing; 5) disconnecting a run-in string connected to the flow-control filter string (5). The segment flow control of the flow-control filter string (5) is achieved by using a pack-off effect of the anti-channeling flow pack-off particles (7).

Abstract: An apparatus for the supply of inert gas at a well site, the apparatus comprising one or more pressure vessels containing liquefied inert gas, a heat exchanger, one or more units of fracturing equipment connected to a manifold, a submersible pump in each of the one or more pressure vessels, each submersible pump being connected to supply liquefied inert gas to a supply line that passes through the heat exchanger and the supply line being connected to supply inert gas vaporized by the heat exchanger to the manifold.

Abstract: A method can include introducing a particulate diverting agent into a first fracture within an underground reservoir formation. The particulate diverting agent can at least partially hydraulically isolate the first fracture. The particulate diverting agent can also be a temporary material which substantially degrades over an extended time. The underground reservoir formation can be stimulated with a stimulation fluid sufficient to expand a second fracture within the underground reservoir formation. The particulate diverting agent can then be allowed to substantially degrade.

Abstract: An example apparatus includes a formation description module that interprets a formation description corresponding to a formation of interest, a fluid description module that interprets a high solids content fluid (HSCF) description, and a fracture modeling module that models a fracturing operation in the formation of interest in response to the formation description and the HSCF description. The apparatus further includes a fracture results module that provides a fracture treatment description parameter in response to the model.

Abstract: Disclosed is a population of ceramic particles that includes a plurality of individual, free flowing particles. The plurality has a total weight and particle size distribution. The effective width of the distribution is the difference between the distribution's d95 and d5 particle sizes. The distribution's effective width exceeds 100 microns and includes three abutting and non-overlapping regions that include a first region, a second region, and a third region. The first region abuts the second region and the second region abuts the third region. The width of the second region is at least 25% of the effective width. The weight of particles in the second region does not exceed 15% of the plurality of particle's total weight. The weight of particles in the first region and the third region each exceed the weight of particles in the second region. Methods of making the populations of ceramic particles are also disclosed.

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. In addition, the non-spherical particulates exhibit higher conductivity at higher stresses than spherical shaped particulates.

Abstract: A method of predictive modeling of a treatment fluid comprises: determining the value of properties of a base fluid and insoluble particulates; providing a proposed suspending agent; performing a first calculation of the suspendability of the proposed suspending agent as determined by a yield gravity function equation; evaluating if the result from the first calculation indicates a stable treatment fluid comprising the base fluid, the insoluble particulates, and the proposed suspending agent, or if the result does not indicate a stable treatment fluid, then: modifying the value of at least one of the properties of the proposed suspending agent, base fluid, and/or insoluble particulate; and performing a second calculation, wherein the same or different property values are continued to be modified and the calculation is continued to be performed until the result indicates a stable treatment fluid; and introducing the stable treatment fluid into a wellbore.

Abstract: A method to improve fluid flow in a hydraulic fracture from a subterranean formation which includes the steps of (1) formulating a slurry which comprises (a) proppant particles, (b) a carrier fluid, and (c) low density particles, wherein the fluid is capable of undergoing a transformation to cause an agglomeration of two or more proppant particles and/or low density particles; and (2) injecting the slurry into the formation; and (3) the agglomeration of the proppant particles and/or low density particles, is provided.