Abstract: A method is disclosed that includes introducing one or more dual function inhibitor compounds through an umbilical into a deepwater environment such that the one or more dual function inhibitor compounds are introduced into a fluid in the deepwater environment. The dual function inhibitor is a corrosion inhibitor and a hydrate inhibitor.

Abstract: 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.

Abstract: A variety of systems, methods and compositions are disclosed, including, in one method, a method may comprise providing a proppant-free fracturing fluid; providing a proppant composition, wherein the proppant composition comprises proppant particulates and degradable thermoplastic particulates; introducing the proppant-free fracturing fluid into a subterranean formation at an injection rate above a fracture gradient to create or enhance at least one fracture in the subterranean formation; introducing the proppant composition into the at least one fracture; and allowing the proppant composition to form a proppant pack in the fracture, wherein the degradable thermoplastic particulates are degradable to generate voids in the proppant pack.

Abstract: An acidizing and formation stabilizing treatment fluid for stabilizing a fracture in a subterranean formation. An acid generating agent generates an acid in situ to acidize the formation thereby enhancing the fractures within and to cure an acid-catalyzed, curable resin to stabilize the formation.

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: Treatment fluid compositions that include a carrier fluid, a crosslinkable polymer, one or more degradable fibers grafted with a crosslinking moiety capable of crosslinking the crosslinkable polymer, and optionally a proppant or gravel. Methods and systems for treating a subterranean wellbore or formation using the grafted degradable fiber treatment fluids are further provided. The presently disclosed treatment fluids may be suitable for use as hydraulic fracturing treatment fluids, gravel packing treatment fluids, or fluid diversion treatment fluids.

Abstract: A method is disclosed that includes introducing one or more dual function inhibitor compounds through an umbilical into a deepwater environment such that the one or more dual function inhibitor compounds are introduced into a fluid in the deepwater environment. The dual function inhibitor is a corrosion inhibitor and a hydrate inhibitor.

Abstract: Methods of treating a subterranean formation include obtaining or providing compositions that include an alkenoate ester. The compositions also includes at least one of a dialkenyldihydrocarbylammonium halide and an N,N-dihydrocarbyl-substituted alkenamide. The methods also include placing the composition in a subterranean formation downhole. Methods of treating a subterranean formation include using a composition including a polymer that is a reaction product of a mixture including an alkenoate ester and at least one of a dialkenyldihydrocarbylammonium halide and an N,N-dihydrocarbyl-substituted alkenamide.

Abstract: A variety of systems, methods and compositions are disclosed, including, in one method, a method may comprise providing a proppant-free fracturing fluid; providing a proppant composition, wherein the proppant composition comprises proppant particulates and degradable thermoplastic particulates; introducing the proppant-free fracturing fluid into a subterranean formation at an injection rate above a fracture gradient to create or enhance at least one fracture in the subterranean formation; introducing the proppant composition into the at least one fracture; and allowing the proppant composition to form a proppant pack in the fracture, wherein the degradable thermoplastic particulates are degradable to generate voids in the proppant pack.

Abstract: A variety of systems, methods and compositions are disclosed, including, in one method, a method may comprise providing a proppant-free fracturing fluid; providing a proppant composition, wherein the proppant composition comprises proppant particulates and degradable thermoplastic particulates; introducing the proppant-free fracturing fluid into a subterranean formation at an injection rate above a fracture gradient to create or enhance at least one fracture in the subterranean formation; introducing the proppant composition into the at least one fracture; and allowing the proppant composition to form a proppant pack in the fracture, wherein the degradable thermoplastic particulates are degradable to generate voids in the proppant pack.

Abstract: A method, comprising contacting a proppant, water, and a water external emulsion to form a mixture, wherein the water external emulsion has an organic internal phase comprising a surface modifying agent; contacting the mixture with an emulsion breaker to form a wellbore servicing fluid comprising a proppant coated with the surface modifying agent; an placing the wellbore servicing fluid in a wellbore penetrating a subterranean formation. A method comprising contacting a proppant, water, and a water external emulsion to form a first mixture, wherein the water external emulsion has an organic internal phase comprising a surface modifying agent; contacting the first mixture with an emulsion breaker to form second mixture comprising a proppant coated with the surface modifying agent; and recovering a coated proppant from the second mixture.

Abstract: Methods including introducing a first treatment fluid comprising a first aqueous base fluid and a chelating etching agent into a low-permeability subterranean formation comprising carbonate material having a first fracture network at a first treatment interval therein, wherein the first fracture network comprises a first main fracture and a first microfracture. The method further comprises placing the chelating etching agent in the first fracture network and reacting it with the carbonate material in the first fracture network. In certain embodiments, the reacting removes the carbonate material, thereby creating at least one conductive channel on a face of the first fracture network. The method further comprises introducing a second treatment fluid comprising a second aqueous base fluid and micro-sized proppant particulates into the low-permeability subterranean formation and placing the micro-sized proppant particulates into the first fracture network to form a partial monolayer in the first microfracture.

Abstract: Methods and systems employing a flocculation polymer and microparticulates. The flocculation polymer flocculates the microparticulates to form micro-aggregates for use in forming complex fracture networks. Additionally, the flocculation causes the flocculation polymer to be removed from a treatment fluid due to its interaction with the microparticulates, thereby effectively cleaning the flocculation polymer from a subterranean formation. Individual microparticulates are synergistically used alone or in the presence of a de-aggregating agent to enhance complex fracture networks.

Abstract: Methods for producing a coating on a fracture surface within a subterranean formation are provided. A pad fluid is injected or introduced into a wellbore to form a primary fracture in the subterranean formation and a coating fluid is injected or introduced into the primary fracture to form secondary fractures in the subterranean formation. The coating fluid is flowed into the secondary fractures to expose nucleation surfaces on the secondary fractures to the coating fluid and to produce a resin coating on the nucleation surfaces. Conductive flow paths are formed on and/or within the resin coating. Hydrocarbons can be retrieved from the subterranean formation via the conductive flow paths within the secondary fractures. A viscosity of the pad fluid is greater than a viscosity of the coating fluid and the coating fluid contains or includes a resin, a curing agent, a surfactant, and an organic solvent.

Abstract: Methods for providing an acidizing treatment and stabilizing a fracture in a subterranean formation in the same treatment are described. The methods relate to acid generating agents, which generate an acid in situ and to curing or crosslinking an acid-catalyzed, curable resin with an in situ generated acid. The method further comprises the steps of introducing a first treatment fluid comprising a first base fluid and an in situ acid generating agent into the subterranean formation; and introducing a second treatment fluid comprising a second base fluid and an acid-catalyzed, curable resin into the subterranean formation.

Abstract: A proppant suspension composition including a proppant, gelling agent, nanoparticles, at least one breaker, and a tackifying resin. The gelling agent may include cross-linkable polymers. The nanoparticles may be natural or synthetic clays. The at least one breaker may include oxidizers, monovalent salts and/or bis-quaternary ammonium compounds. The composition can be provided downhole during fracturing operations.

Abstract: Treatment fluid compositions that include a carrier fluid, a crosslinkable polymer, one or more degradable fibers grafted with a crosslinking moiety capable of crosslinking the crosslinkable polymer, and optionally a proppant or gravel. Methods and systems for treating a subterranean wellbore or formation using the grafted degradable fiber treatment fluids are further provided. The presently disclosed treatment fluids may be suitable for use as hydraulic fracturing treatment fluids, gravel packing treatment fluids, or fluid diversion treatment fluids.

Abstract: A method may include: placing into a wellbore penetrating a subterranean formation a foaming agent, wherein the wellbore comprises a produced fluid from the subterranean formation; and foaming the produced fluid. The foaming agent may include at least one of the following structures: wherein R1 and R2 are individually selected from an alkyl group, an alkenyl group, a heteroatom substituted alkyl group, or a heteroatom substituted alkenyl group, wherein R1 comprises 5 carbon atoms to 22 carbon atoms in length, and wherein R2 comprises 1 carbon atom to 8 carbon atoms.

Abstract: Methods and systems employing a flocculation polymer and microparticulates. The flocculation polymer flocculates the microparticulates to form micro-aggregates for use in forming complex fracture networks. Additionally, the flocculation causes the flocculation polymer to be removed from a treatment fluid due to its interaction with the microparticulates, thereby effectively cleaning the flocculation polymer from a subterranean formation. Individual microparticulates are synergistically used alone or in the presence of a de-aggregating agent to enhance complex fracture networks.

Abstract: Methods including (a) introducing an invert microemulsified acid (“IMA”) treatment fluid into a subterranean formation at a rate and pressure sufficient to create or enhance a fracture in a first treatment interval therein, wherein the IMA treatment fluid comprises a surfactant, a non-aqueous external phase, and aqueous dispersed phase droplets, and wherein the non-aqueous external phase further comprises micro-proppant particulates and at least a portion of the aqueous dispersed phase droplets further comprise an acid; (b) destabilizing the IMA treatment fluid in the fracture, thereby exposing the acid, wherein the micro-proppant particulates form a proppant pack in the fracture and the acid etches a channel in the fracture and/or adjacent to the fracture.