The embodiments described herein generally relate to methods and chemical compositions for fracturing fluid applications. In one embodiment, a fracturing fluid composition is provided comprising a fracturing fluid and an additive composition including a reaction product of a diglycidyl ether or a polyacid selected from the group consisting of an aromatic polyacid, an aliphatic polyacid, an aliphatic polyacid with an aromatic group, and combinations thereof; and a polyamine; and one or more compounds selected from the group consisting of a branched aliphatic acid, a cyclic aliphatic acid with a cyclic aliphatic group, a linear aliphatic, and combinations thereof.

According to one or more embodiments of the present disclosure, a method for hydraulic fracturing includes pumping a hydraulic fracturing fluid through a wellbore into a subterranean formation at a pressure greater than a fracturing pressure of the subterranean formation. The hydraulic fracturing fluid may include an aqueous base fluid and a clay stabilizer consisting of one or more polyethylene polyamines having a first structure H.sub.2NCH.sub.2CH.sub.2(NHCH.sub.2CH.sub.2).sub.xNH.sub.2, where x is an integer greater than or equal to 3. The amount of the clay stabilizer may be from 1 lb.sub.m/bbl to 20 lb.sub.m/bbl relative to the total volume of the hydraulic fracturing fluid. The average molecular weight of the polyethylene polyamines in the hydraulic fracturing fluid having the first chemical structure may be from 200 g/mol to 400 g/mol. All of the polyethylene polyamines in the hydraulic fracturing fluid having the first chemical structure may be encompassed in the clay stabilizer.

Proppant particulates are commonly used in hydraulic fracturing operations to maintain one or more fractures in an opened state following the release of hydraulic pressure. In complex fracture networks, it can be difficult to deposit proppant particulates fully within the fractures. In addition, low crush strengths may result in problematic fines formation. Polyaromatic hydrocarbons, commonly encountered in various refinery process streams, may serve as an advantageous precursor to proppant particulates. Polyaromatic hydrocarbons may undergo crosslinking under acid-catalyzed conditions in an aqueous solvent in the presence of a surfactant to form substantially spherical particulates that may serve as effective proppant particulates during fracturing operations. In situ formation of the proppant particulates may take place in some cases.

A variety of systems, methods and compositions are disclosed. A method may comprise introducing a fracturing fluid into a subterranean formation, wherein the fracturing fluid comprises an aqueous based fluid, a proppant composition, an oxidizing breaker, and halloysite nanotubes, wherein the oxidizing breaker is positioned within the halloysite nanotubes; and reducing a viscosity of the fracturing fluid.

Producing proppants with nanoparticle proppant coating include coating the proppant particles with a strengthening agent, functionalized nanoparticles, and unfunctionalized organic resin to produce proppant with nanoparticle proppant coating. Additionally, a proppant comprising a proppant particle and a nanoparticle proppant coating is provided. The nanoparticle proppant coating includes a strengthening agent, functionalized nanoparticles, and unfunctionalized organic resin. The nanoparticle proppant coating coats the proppant particle.

Forming a hydrogel in-situ downhole by pumping multiple polymers together that synergistically work together to reduce the flow of water through a proppant pack

This disclosure relates to a fracturing fluid including an acrylamide-based copolymer, a graphene oxide additive, and a crosslinker, and methods of using the fracturing fluid to reduce fluid friction during treatment of a subterranean formation.

Producing proppants with nanoparticle proppant coatings includes reacting nanoparticles with at least one of an alkoxysilane solution or a halosilane solution to form functionalized nanoparticles and coating proppant particles with unfunctionalized organic resin, a strengthening agent, and the functionalized nanoparticles to produce the nanoparticle coated proppant. The functionalized nanoparticles include nanoparticles having at least one attached omniphobic moiety including at least a fluoroalkyl-containing group including 1H, 1H, 2H, 2H-perfluorooctylsilane. The strengthening agent comprises at least one of carbon nanotubes, silica, alumina, mica, nanoclay, graphene, boron nitride nanotubes, vanadium pentoxide, zinc oxide, calcium carbonate, or zirconium oxide. Additionally, increasing a rate of hydrocarbon production from a subsurface formation through the use of the nanoparticle coated proppant includes producing a first rate of production of hydrocarbons from the subsurface formation, introducing a hydraulic fracturing fluid into the subsurface formation, and increasing hydrocarbon production by producing a second rate of production of hydrocarbons.

A completion/stimulation/production fluid and injection mixture blend is disclosed. The blend may include an aqueous fluid, a polymer system and an injection mixture that includes a polyol, a natural sugar, an artificial sugar, or a combination thereof.

A fluid design with enhanced proppant-carrying capacity utilizes a low-viscosity fluid with high proppant carrying capacity and low required power for injection into a hydrocarbon-bearing, subterranean formation. A preferred viscosifying agent that comprises a copolymer polymerized from an acrylic acid monomer and a monomer selected from: a) at least one carboxylic acid monomer; b) at least one C.sub.1 to C.sub.5 alkyl ester and/or at least one C.sub.1 to C.sub.5 hydroxyalkyl ester of acrylic acid or methacrylic acid; c) one crosslinking monomer; and optionally d) at least one α,β-ethylenically unsaturated monomer, may be used to produce a fracturing fluid that has the pumpability of a slick water fluid and the proppant-carrying ability of a cross-linked gel. An optimization process to optimize hydraulic fracture design evaluates and quantifies the proppant-carrying capacity of the invented fluid and its impact in the proppant transport during fracturing.