Abstract: Systems and methods for treating proppant to mitigate erosion of equipment used in certain subterranean fracturing operations are provided. In some embodiments, the methods comprise: conveying a plurality of coated proppant particulates into a blender, wherein the coated proppant particulates comprise at least a partial coating of DFR and/or a hydratable polymer; blending the plurality of coated proppant particulates with an aqueous base fluid in the blender to form a treatment fluid; and introducing the treatment fluid from the blender into at least a portion of a subterranean formation.

Abstract: Proppant aggregates comprising proppant particulates and a binding agent, wherein the proppant aggregate exhibits a conductivity of less than about 3000 millidarcy-feet when exposed to aggregate operational conditions, the aggregate operational conditions having a closure stress of at least about 100 pounds per square inch and a temperature of at least about 10° C.

Abstract: A downhole treatment fluid made up of a binding composition and a proppant, the binding composition including an aluminosilicate source, a metal silicate, an alkali metal activator. The binding composition may form a coated particulate or an aggregate with the proppant and provides strength-enhancing properties. The binding composition has easy handling properties facilitating on-the-fly preparation and downhole injection procedures. Furthermore, the binding composition has a low strength-hardening temperature and so may strength-harden in the presence of downhole temperatures.

Abstract: A foamed treatment fluid comprising: an external phase, wherein the external phase comprises: (A) water; (B) a curable resin; and (C) a foaming agent; and an internal phase, wherein the internal phase comprises an inert gas. A method of treating particles of a particle pack located in a subterranean formation comprising: introducing the foam into the subterranean formation; and consolidating the particles of the particle pack after introduction into the subterranean formation.

Abstract: Proppant aggregates comprising proppant particulates and a binding agent, wherein the proppant particulates in the absence of the binding agent pack together to exhibit a conductivity of less than about 3000 millidarcy-feet when exposed to operational conditions, the operational conditions having a closure stress of greater than about 1000 pounds per square inch and a temperature of greater than about 50° F.

Abstract: A method to produce reconstituted structures that recreate the chemical, geological, and structural characteristics of a portion of a target reservoir formation by using drill cuttings material from the target reservoir formation. The method includes providing drill cuttings material from a known reservoir formation and grinding the drill cuttings material to particulates of one or more known particle sizes. In particular, an actual core sample may be replicated via a three-dimensional printer using the ground drill cuttings material from the target reservoir formation. A representative reconstituted structure may also be formed by applying a load to the ground drill cuttings material from the target reservoir formation. A slot flow device may also be formed via either three-dimensional printing with drill cutting particulates or the application of a load to the drill cutting particulates.

Abstract: A method comprises creating a fracture network extending from a wellbore into a subterranean formation; then, introducing a series of fluids into the fracture network in a subterranean formation, thereby forming a proppant pack in the fracture network, wherein the series of fluids comprise: a microproppant slurry comprising a microproppant having an average diameter less than about 25 microns; a proppant slurry comprising a proppant having an average diameter of about 75 microns to about 500 microns; and a sweep fluid having a microproppant weight percentage by weight of the sweep fluid that is from 0 to about the same of the microproppant weight percentage in the microproppant slurry by weight of the microproppant slurry; and wherein introduction of the microproppant slurry is not immediately followed by introduction of the proppant slurry, and wherein introduction of the proppant slurry is not immediately followed by introduction of the microproppant slurry.

Abstract: Methods and compositions for mitigating the embedment of proppant into fracture faces in subterranean formations are provided. In some embodiments, the methods comprise: introducing a treatment fluid into a subterranean formation at or above a pressure sufficient to create or enhance one or more fractures in the subterranean formation; introducing an anchoring agent into the subterranean formation to deposit the anchoring agent on a portion of a fracture face in the one or more fractures within the subterranean formation; introducing a first particulate material comprising fine particulates into the subterranean formation to attach to the anchoring agent on the portion of the fracture face, wherein said fine particulates have a mean particle size of up to about 50 ?m; introducing a second particulate material comprising proppant into the one or more fractures in the subterranean formation.

Abstract: Systems and methods for enhancing the conductivity of fractures in a subterranean formation using cements and electrically controlled propellant materials are provided. In some embodiments, the methods comprise: introducing a cement fluid comprising an aqueous base fluid, an inorganic cement, an electrically controlled propellant, and a plurality of electrically conductive particles into at least one fracture in a subterranean formation; allowing at least a portion of the cement fluid to at least partially harden in the fracture to form a solid cement mass; and applying an electrical current to at least a portion of the electrically controlled propellant in the fracture to ignite the electrically controlled propellant, whereby the solid cement mass in the fracture is at least partially ruptured by the ignition of the electrically controlled propellant.

Abstract: Systems and methods for forming and/or enhancing fractures in a subterranean formation using electrically controlled propellant materials are provided. In some embodiments, the methods comprise: introducing a treatment fluid comprising an electrically controlled propellant and a plurality of electrically conductive particles in at least one primary fracture in a portion of a subterranean formation; placing the plurality of electrically conductive particles in at least the primary fracture; placing the electrically controlled propellant in one or more areas of the subterranean formation proximate to the primary fracture; and applying an electrical current to at least a portion of the electrically controlled propellant to ignite the portion of the electrically controlled propellant in the one or more areas of the subterranean formation proximate to the primary fracture to form one or more secondary or tertiary fractures in the subterranean formation.

Abstract: Mapping propped fractures in a well can be performed using a mixture including a proppant and an encapsulated salt. The proppant can be positioned in a fracture in the well for propping open the fracture to form a propped fracture. The encapsulated salt can be positioned in the propped fracture proximate to the proppant and include a salt and a non-permeable coating. The salt can be dissolved in response to fracture closure, encapsulant degradation, or encapsulant dissolution to form an electrically conductive solution usable for mapping the propped fracture. The non-permeable coating can prevent a fluid from contacting the salt during pumping and placement operations.

Abstract: Proppant-free channels may be formed in a proppant pack in subterranean formations by using the miscibility and immiscibility of proppant-laden and proppant-free fluids. For example, a method of forming a proppant pack may include: introducing, in alternating order, a proppant-laden fluid and a proppant-free fluid into a wellbore penetrating a subterranean formation, wherein the proppant-laden fluid comprises an oil-external emulsion and a proppant, and wherein the proppant-free fluid is immiscible with the proppant-laden fluid; and forming a proppant pack in a fracture in the subterranean formation, wherein the proppant pack comprises proppant-laden clusters and proppant-free channels.

Abstract: Systems and methods for stabilizing portions of a subterranean formation, including portions of a subterranean formation having unconsolidated particulates, using a consolidating agent comprising polyamino-functionalized nanoparticles are provided. Certain of the methods include the steps of providing a treatment fluid comprising a base liquid and polyamino-functionalized nanoparticles; and introducing the treatment fluid into a portion of a subterranean formation. Treatment fluids comprising polyamino-functionalized nanoparticles include gravel packing fluids, consolidation fluids, and hydraulic fracturing fluids are also provided.

Abstract: A method of fracturing a subterranean formation is provided. A fracturing fluid is pumped into the formation to fracture the formation. A plurality of nanoparticles is mixed with the fracturing fluid and placed in the fracture. A plurality of conventional proppant particulates is also mixed with the fracturing fluid and placed in the fracture.

Abstract: A method can include receiving acoustic emission data for acoustic emissions originating in a formation, performing a moment tensor analysis of the data, thereby yielding acoustic emission source parameters, determining at least one acoustic emission source parameter angle having a highest number of associated acoustic emission events, and calculating an in situ stress parameter, based on the acoustic emission source parameter angle. A system can include multiple sensors that sense acoustic emissions originating in a formation, and a computer including a computer readable medium having instructions that cause a processor to perform a moment tensor analysis of the data and yield acoustic emission source parameters, determine at least one acoustic emission source parameter angle having a highest number of associated acoustic emission events, and calculate an in situ stress parameter, based on the acoustic emission source parameter angle.

Abstract: A method of treating a subterranean formation comprising: providing a proppant; coating the proppant with a geopolymer composition to create a coated proppant; injecting a fracturing fluid into the subterranean formation, wherein the fracturing fluid comprises a base fluid and the coated proppant; and allowing the geopolymer composition to set in the formation to form a geopolymer on the proppant.

Abstract: Methods including isolating a first treatment zone comprising an opening into a subterranean formation. A high-viscosity treatment fluid (HVTF) is introduced through the opening and incrementally increased fracturing rate steps (IIFRSs) are applied to create or enhance a dominate fracture, wherein between each IIFRS a downhole pressure slope over time will increase, decline, or stabilize at a measured pressure slope. The measured pressure slope is evaluated to determine whether an increasing pressure slope, a stabilizing pressure slope, or a declining pressure slope exists to determine whether and when to apply a subsequent IIFRS. The result is increasing a volume of the dominate fracture due to efficient dominate fracturing with generated back pressure until a first maximum fracturing rate is reached.

Abstract: The embodiments of the present disclosure relate to increasing fracture network complexity within a subterranean formation using a plurality of fluid stages where one or more of such fluid stages utilizes a liquid gas treatment fluid. The embodiments described herein allow creation or extension of a dominant fracture and branch fractures extending therefrom at one or both of the near-wellbore region and/or the far-field region of a fracture network, thereby enhancing fracture network complexity.

Abstract: The embodiments of the present disclosure provide for enhanced production of subterranean formations (i.e., wellbores in such formations) for the recovery of hydrocarbons, for example. The embodiments utilize various sizes and concentrations of proppant (e.g., sand proppant, micro-proppant, and/or macro-sand proppant) in created or enhanced fractures or fracture networks in subterranean formations penetrated by a wellbore using a plurality of fluid stages. As used herein and with reference the embodiments here described, the wellbore may be vertical, horizontal, or deviated (neither vertical, nor horizontal), without departing from the scope of the present disclosure.

Abstract: Methods of treating a subterranean formation having a vertically oriented fracture with a treatment fluid comprising an aqueous base fluid, a gelling agent, proppant particulates, and swellable particulates having an unswelled form and a swelled form; placing the treatment fluid into the vertically oriented fracture; swelling the swellable particulates at a first location against walls of the vertically oriented fracture, thereby forming a first swelled particulates plug; swelling the swellable particulates at a second location above or below the first location against the walls of the vertically oriented fracture, thereby forming a second swelled particulates plug; and settling the proppant particulates atop the first swelled particulates plug and the second swelled particulates plug to form a proppant-free channel.