Abstract: Methods and compositions for treating proppant and/or formation sand to enhance proppant pack conductivity, control fines migration, and stabilize formation sand during the well production are provided. In one embodiment, the method comprises: introducing a fines migration control agent into a fluid comprising a base fluid and a plurality of proppants, wherein the fines migration control agent comprises a core group capable of attaching to the proppant and at least one end group connected to the core group capable of capturing fines; mixing the fines migration control agent with the fluid to form a proppant slurry; and injecting the proppant slurry into a wellbore penetrating at least a portion of a subterranean formation.

Abstract: A treatment fluid for treating a portion of a water- sensitive subterranean formation comprising: a base fluid; and a stabilizing compound, wherein the stabilizing compound reduces or eliminates swelling of a water-swellable mineral of the portion of the water-sensitive subterranean formation, and wherein the stabilizing compound comprises: (A) a cationic functional group; and (B) a hydrophobic portion. A method of treating a portion of a water-sensitive subterranean formation comprising: introducing a treatment fluid into a wellbore, wherein the wellbore penetrates the subterranean formation, wherein the portion of the subterranean formation comprises a water-swellable mineral.

Abstract: Embodiments herein include methods comprising introducing a treatment fluid into a subterranean formation, wherein the treatment fluid comprises a base fluid, an acid, and a fluoride releasing agent selected from the group consisting of an amine monofluorophosphate; a bisamine monofluorophosphate; any derivative thereof; and any combination thereof, wherein the acid and the fluoride releasing agent react to generate hydrofluoric acid over time in the subterranean formation so as to create or enhance at least one microfracture therein.

Abstract: Methods are provided for chemically removing cured resin product from surfaces and subterranean formations in case of inappropriate consolidation, plugging of screens or tubing, and equipment damage. A chemical solvent is introduced to a wellbore where a resin has cured. The resin is contacted with the chemical solvent until the resin at least partially dissolves. At least a portion of the dissolved resin is then removed from the wellbore.

Abstract: Methods including preparing a treatment fluid comprising an aqueous base fluid, functionalized proppant particulates, and a curing agent, wherein the functionalized proppant particulates comprise proppant particulates having a functional group hydrolytically deposited thereon; introducing the treatment fluid into a subterranean formation having at least one fracture therein; placing the functionalized proppant particulates into the at least one fracture; and reacting the curing agent with the functional group on the functionalized proppant particulates, thereby forming a consolidated proppant pack in the at least one fracture.

Abstract: Coated proppant particulates for use in subterranean formation operations comprising: proppant particulates at least partially coated with a dual tackifying-hardening agent selected from the group consisting of a dimer acid/trimer acid blend, with a crosslinking agent at least partially coated thereon, wherein the dual tackifying-hardening agent both exhibits tackifying qualities and is capable of hardening a curable resin.

Abstract: Conformance fluids comprising a base fluid; and a canola protein-based hydrogel comprising a copolymer of a water-swellable polymeric material grafted onto a hydrolyzed canola protein backbone, wherein the canola protein-based hydrogel is present in the conformance fluid in an amount in the range of from about 1% to about 10% by weight of the conformance fluid.

Abstract: Various embodiments disclosed relate to compositions for treating a subterranean formation and methods of using same, such as for consolidation. In various embodiments, the present invention provides a method of treating a subterranean formation, the method including obtaining or providing a composition. The composition includes an aryl component including at least one of an aryldicarboxylic acid, an ester thereof, a salt thereof, and an acid halide thereof. The composition includes an amine or epoxide component that includes at least one of component A and component B. Component A is a linear diepoxide, a poly(alkylamine), or a combination thereof. Component B is an alkoxy- or hydroxy-substituted silane including an epoxy group, an alkoxy- or hydroxy-substituted silane including an amine group, or a combination thereof. The method also includes placing the composition in a subterranean formation.

Abstract: A method of treating a subterranean formation comprising: introducing a first treatment fluid into a well, wherein the first treatment fluid comprises a base fluid and a scale inhibitor; and introducing a second treatment fluid into the well, wherein the second treatment fluid comprises a base fluid and a surface modification agent, wherein the surface modification agent is a hydrophobically modified polyamide. A method of fracturing a subterranean formation comprising: introducing a fracturing fluid into a well, wherein the introduction of the fracturing fluid creates or enhances a fracture in the subterranean formation, wherein the fracturing fluid comprises: a base fluid; proppant; a scale inhibitor; and the surface modification agent.

Abstract: Systems, methods, and computer-readable storage devices for scanning a retrieved geological core sample to produce a digital file representing the core sample. Then the digital file is transmitted to a three-dimensional printer that can execute the digital file to make a geologically, chemically, and structurally equivalent replica of the retrieved geological core sample. The three-dimensional printer can optionally combine a base geological material with one or more additives or with an inert binding agent layer by layer as three-dimensional pixels. The replica core sample can then be used for testing or for other purposes at a greatly reduced cost than retrieving multiple actual core samples. Further, the replica core sample can be reproduced at virtually any location rather than transporting an actual core sample.

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 portion of a well comprising: forming a treatment fluid, wherein the treatment fluid comprises: (A) water; and (B) a surfactant, wherein the surfactant is environmentally-friendly, and wherein the surfactant causes a liquid hydrocarbon to become soluble in the treatment fluid; and introducing the treatment fluid into the well, wherein the treatment fluid comes in contact with wellbore particles after introduction into the well, wherein at least a portion of the wellbore particles are coated with the liquid hydrocarbon prior to contact with the treatment fluid.

Abstract: Compositions and methods for forming and using clusters of micron- and/or nano-sized solid materials (e.g., particulates, fibers, etc.) as proppants in subterranean operations are provided. In one embodiment, the methods comprise: providing a fracturing fluid comprising a base fluid, a plurality of small-sized solid materials and one or more surface modifying agents; forming a plurality of proppant clusters, each proppant cluster comprising two or more of the small-sized solid materials bound together with a portion of the one or more surface modifying agents; and introducing the fracturing fluid into a well bore penetrating at least a portion of a subterranean formation at or above a pressure sufficient to create or enhance one or more fractures in the portion of the subterranean formation.

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 particles of a particle pack located in a subterranean formation comprising: introducing an additive into the subterranean formation, wherein the additive: (i) comes in contact with the particles of the particle pack; (ii) has a chemical attraction to the particles of the particle pack; and (iii) comprises a first functional group, wherein the first functional group is a water-control agent.

Abstract: A fracturing fluid and method of including a cellulose polymer derivative, a diol functional group, and a borate crosslinker. The diol functional group may be a cis-diol functional group, a 1,2-diol functional group, or a 1,3-diol functional group. The cellulose polymer derivative further may include a hydroxyethyl group or a hydroxypropyl group. The fracturing fluid may also include at least one metallic crosslinker. The method may also include the steps of adding a pH adjusting agent, at least one breaker, a surfactant, a scale inhibitor, and/or a bactericide to the fracturing fluid, or mixing the fracturing fluid using mixing equipment or wherein the fracturing fluid is introduced into a subterranean formation using one or more pumps.

Abstract: Embodiments herein include methods comprising introducing a treatment fluid into a subterranean formation, wherein the treatment fluid comprises a base fluid, an acid, and a fluoride releasing agent selected from the group consisting of an amine monofluorophosphate; a bisamine monofluorophosphate; any derivative thereof; and any combination thereof, wherein the acid and the fluoride releasing agent react to generate hydrofluoric acid over time in the subterranean formation so as to create or enhance at least one microfracture therein.

Abstract: Various embodiments disclosed relate to compositions for treating a subterranean formation and methods of using same, such as for consolidation. In various embodiments, the present invention provides a method of treating a subterranean formation, the method including obtaining or providing a composition. The composition includes an aryl component including at least one of an aryldicarboxylic acid, an ester thereof, a salt thereof, and an acid halide thereof. The composition includes an amine or epoxide component that includes at least one of component A and component B. Component A is a linear diepoxide, a poly(alkylamine), or a combination thereof. Component B is an alkoxy- or hydroxy-substituted silane including an epoxy group, an alkoxy- or hydroxy-substituted silane including an amine group, or a combination thereof. The method also includes placing the composition in a subterranean formation.

Abstract: Conformance fluids comprising a base fluid; and a canola protein-based hydrogel comprising a copolymer of a water-swellable polymeric material grafted onto a hydrolyzed canola protein backbone, wherein the canola protein-based hydrogel is present in the conformance fluid in an amount in the range of from about 1% to about 10% by weight of the conformance fluid.

Abstract: Methods and compositions are provided for removing a residue of resin from the surface of equipment. In one embodiment, the methods comprise: providing a cleaning solution comprising a pH-adjusting agent, a chemical solvent, and water, wherein the chemical solvent is selected from the group consisting of ?-lactam, ?-lactam, ?-lactam, ?-lactam, 2-pyrrolidone, N-methylpyrrolidone, 1,3-dimethyl-2-imidazolidinone (DMI), caprolactam, cyclohexanone, cyclopentanone, ?-butyrolactone, ?-butyrolactone, ?-decalactone, ?-valerolactone, ?-caprolactone, butylene carbonate, propylene carbonate, and ethylene carbonate, any combination thereof, and any derivative thereof; allowing the cleaning solution to contact a surface at least partially coated with a layer of resin; and allowing the cleaning solution to at least partially dissolve the resin.