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 may comprise: determining a total dissolved solids (TDS) concentration of a water source; correlating the TDS concentration to an ion concentration; and selecting at least one friction reducing polymer for a hydraulic fracturing operation based at least in part on the ion concentration.

Abstract: A method may include: determining a total dissolved solids (TDS) concentration of a water source; correlating the TDS concentration to an ion concentration; and selecting at least one friction reducing polymer for a hydraulic fracturing operation based at least in part on the ion concentration.

Abstract: A treatment fluid is described suitable for use in subterranean formations comprising an aqueous phase, a carboxymethyl hydroxyethyl cellulose, and a breaker. The aqueous phase comprises water having at least 1,000 ppm total dissolved inorganic salts and at least one of: a sulfate concentration of about 4,000 ppm or greater, a phosphate concentration of about 100 ppm or greater, a carbonate concentration of about 100 ppm or greater, or a barium concentration of about 37,000 ppm or greater. The carboxymethyl hydroxyethyl cellulose has a carboxymethyl degree of substitution in the range of about 0.3 to about 0.45 per glucopyranose unit in the carboxymethyl hydroxyethyl cellulose polymer; and a hydroxyethyl molecular substitution in the range of about 2.1 to about 2.9 per glucopyranose unit in the carboxymethyl hydroxyethyl cellulose polymer; The treatment fluid is substantially free of any crosslinker.

Abstract: Treatment fluids (e.g., fracturing fluids) comprising ionic water, and associated methods of use are provided. In one embodiment, the methods comprise providing a treatment fluid comprising an aqueous base fluid comprising one or more ionic species, a polymeric viscosifying agent carrying a first ionic charge, and an ionic surfactant carrying a second ionic charge that is the opposite of the first ionic charge; and introducing the treatment fluid into a well bore penetrating at least a portion of a subterranean formation.

Abstract: A method of treating a subterranean formation includes providing a treatment fluid comprising a crosslinkable polymer prepared by a redox reaction with vinyl phosphonic acid monomers or polymers and a polysaccharide, and at least one of a hydrolysable in-situ acid generator and a chelating agent, providing a carrier fluid comprising a brine, providing a metal crosslinker, placing all into a formation, allowing the polymer of to crosslink, and allowing the crosslinked polymer to become uncrosslinked. A wellbore fluid includes a crosslinkable polymer prepared by a redox reaction with vinyl phosphonic acid monomers or polymers and hydroxyethyl cellulose; at least one of a hydrolysable in-situ acid generator, a chelating agent, and mixtures thereof; a carrier fluid comprising a brine; and a metal crosslinker.

Abstract: Methods including providing memory particulates having a compressed configuration and a decompressed configuration; providing a treatment fluid comprising a treatment base fluid and memory particulates in a configuration; introducing the treatment fluid into a subterranean formation comprising at least one fracture therein, so as to place the memory particulates in the at least one fracture in their compressed configuration; and expanding the memory particulates to the decompressed configuration, thereby mechanically interlocking the memory particulates and propping open at least a portion of the at least one fracture.

Abstract: Compositions and methods for use for hydraulic fracturing and creating high porosity propped fractures in portions of subterranean formations are provided. In one embodiment, the methods include introducing a fracturing fluid into the well bore at or above a pressure to create or enhance at least one fracture in the subterranean formation; providing a carrier fluid including reticulated materials, wherein the carrier fluid is substantially proppant free; providing a proppant slurry; and introducing the carrier fluid and the proppant slurry into the at least one fracture to form a plurality of proppant aggregates.

Abstract: A method comprises obtaining or providing a treatment fluid comprising a viscosifier polymer; an aqueous carrier fluid comprising high total dissolved solids; and a polymer composition comprising at least one of polyvinyl alcohol and polylactic acid. In some embodiments, the treatment fluid has a viscosity at 140C and at a shear rate of about 0.1 s?1 to about 1 s?1 of about 1,500 cP to about 10,000 cP. The method includes placing the treatment fluid in a subterranean formation.

Abstract: A method of servicing a wellbore comprising providing a degradable polymer and a delayed action construct within a portion of a wellbore, a subterranean formation or both; wherein the delayed action construct comprises (i) a degradation accelerator comprising an alkanolamine, an oligomer of aziridine, a polymer of azridine, a diamine, or combinations thereof, (ii) a solid support, and (iii) an encapsulating material; and placing the wellbore servicing fluid comprising the degradable polymer and delayed action construct into the wellbore, the subterranean formation or both.

Abstract: Methods for selecting a surfactant for treating a subterranean formation based on the performance of the surfactant and the characteristics of the subterranean formation and the treatment fluids that may be used to treat that formation are provided. In one embodiment, the method may comprise providing a treatment fluid, formation materials, hydrocarbon, and a plurality of surfactants, wherein the hydrocarbon is acquired from a subterranean formation; selecting at least two surfactants from the plurality of surfactants by determining whether each of the plurality of surfactants separates a mixture of the treatment fluid and the hydrocarbon; and selecting at least one surfactant from the at least two surfactants by determining whether the hydrocarbon displaces the treatment fluid from the formation materials in the presence of each of the at least two surfactants.

Abstract: Methods comprising introducing a treatment fluid into a wellbore and through a perforation into a first propped main fracture at a first treatment interval above a fracture gradient of the subterranean formation, the treatment fluid comprising a first aqueous base fluid, expandable particulates, and degradable particulates; expanding the expandable particulates to fluidically seal the first propped main fracture to fluid flow between the first propped main fracture and the wellbore with the expanded expandable particulates and the degradable particulates; diverting the treatment fluid to a second treatment interval in the subterranean formation along the wellbore, wherein the rate of the treatment fluid creates or enhances a second main fracture therein; introducing a proppant fluid comprising a second aqueous base fluid and proppant particulates into the wellbore at the second treatment interval; and placing the proppant particulates into the second main fracture, thereby forming a second propped main fractu

Abstract: Methods and systems of delivering a treatment chemical are disclosed, including providing a plurality of porous particles each having an outer surface, wherein each of the plurality of porous particles comprises a plurality of pores; infusing the plurality of porous particles with the treatment chemical; coating the plurality of porous particles with a degradable film; adding the plurality of porous particles to a carrier fluid, wherein the degradable film substantially separates the treatment chemical from the carrier fluid; introducing the carrier fluid into a formation; and allowing the degradable film to degrade within the formation.

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: A method of fabricating a sand control screen assembly includes determining an anatomy of a facsimile sand control screen assembly, the sand control screen assembly including one or more component parts. A virtual three-dimensional (3D) model of the facsimile sand control screen assembly is then generated based on the anatomy. The virtual 3D model of the facsimile sand control screen assembly is provided to a 3D printer, and the 3D printer forms at least a portion of the facsimile sand control screen assembly based on the virtual 3D model.

Abstract: Methods including preparing a surface modification agent emulsion comprising an aqueous base fluid, a surfactant, and a hydrophobically-modified amine-containing polymer (HMAP), the HMAP comprising a plurality of hydrophobic modifications on an amine-containing polymer, and wherein the aqueous base fluid forms an external phase of the surface modification agent emulsion and the HMAP forms an internal phase of the surface modification agent emulsion; and introducing the surface modification agent emulsion into a subterranean formation.

Abstract: A method of treating a subterranean formation including providing a treatment fluid comprising a hardenable acid curable resin and a hydrolysable dimer acid ester. The treatment fluid is combined with a carrier fluid and is introduced into a subterranean formation. Upon the hydrolyzing of the ester in the formation and the contacting of unconsolidated proppants, the treatment method produces consolidated proppants.

Abstract: Various embodiments disclosed relate to treatment fluids comprising a compound of the formula (I): wherein G1, G2, L1, L2, L3, q, and r are defined herein. Various other embodiments relates to methods of treating subterranean formations with such treatment fluids.

Abstract: Methods for selecting a surfactant for treating a subterranean formation based on the performance of the surfactant and the characteristics of the subterranean formation and the treatment fluids that may be used to treat that formation are provided. In one embodiment, the method may comprise providing a treatment fluid, formation materials, hydrocarbon, and a plurality of surfactants, wherein the hydrocarbon is acquired from a subterranean formation; selecting at least two surfactants from the plurality of surfactants by determining whether each of the plurality of surfactants separates a mixture of the treatment fluid and the hydrocarbon; and selecting at least one surfactant from the at least two surfactants by determining whether the hydrocarbon displaces the treatment fluid from the formation materials in the presence of each of the at least two surfactants.

Abstract: Treatment fluids including a base fluid; and fly ash microspheres, wherein the fly ash microspheres are of a material selected from the group consisting of Class C fly ash, Class F fly ash, and any combination thereof, wherein the fly ash microspheres have a diameter in the range of from about 0.1 ??? to about 150 ???, and wherein the fly ash microspheres are present in the treatment fluid in an amount in the range of from about 0.001 ppg to about 1 ppg of the treatment fluid.