Abstract: A method of foam fracturing a subterranean formation includes providing an fracturing foam fluid comprising an aqueous base fluid, a cationic polymer, optionally a foam surfactant comprising at least one of an amphoteric surfactant, cationic surfactant, an anionic surfactant, and combinations thereof, and sufficient gas to form a foamed fracturing fluid; and fracturing the subterranean formation with the foamed fracturing fluid. Stable fracturing foams include an aqueous base fluid, a cationic polymer, optionally a foam surfactant comprising at least one of an amphoteric surfactant, cationic surfactant, an anionic surfactant, and combinations thereof, and sufficient gas to form a foamed fracturing fluid.

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 and compositions for use in subterranean operations are disclosed comprising providing a treatment fluid that comprises a base fluid, a gelling agent, and a synergistic breaker composition, comprising: a controlled degradable acid generating material, and an oxidizing component; introducing the treatment fluid into a formation; allowing the synergistic breaker composition to substantially reduce the viscosity of the treatment fluid.

Abstract: Methods including introducing a treatment fluid into a subterranean formation having at least one fracture therein, the treatment fluid comprising an aqueous base fluid and brush photopolymerized coated proppant particulates (bPCPPs), and placing the bPCPPs into the at least one fracture to form a proppant pack therein. The bPCPPs comprise proppant modified with a coupling agent photopolymerized to a derivatized hydrophilic polymer, thereby resulting in a brush polymer structure of the derivatized hydrophilic polymer extending from the proppant.

Abstract: Various embodiments disclosed relate to compositions including acidic chelator or salt or ester thereof for treatment of subterranean formations including one or more fractures. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a composition including an acidic chelator or a salt or ester thereof. The subterranean formation includes one or more fractures.

Abstract: Methods including introducing a first particulate-free treatment fluid (first PFTF) into a subterranean formation above the fracture gradient. Alternatingly introducing a first particulate-laden treatment fluid (first PLTF) and a second particulate-laden treatment fluid (second PLTF) into the subterranean formation, wherein the first PLTF comprises nano-particles and degradable particles and the second PLTF comprises proppant particulates, and wherein the alternating introduction causes the proppant particulates in the second PLTF to agglomerate into proppant aggregates being surrounded by the first PLTF. Placing the proppant aggregates into at least one fracture, removing the hydraulic pressure to close the at least one fracture, and degrading the degradable particulates to form at least one channel between adjacent proppant aggregates.

Abstract: A diverter fluid having a carbon-containing particulate dispersed therein for controlling fluid flow within subterranean formations. The diverter fluid can be injected into a wellbore for formation of a filter cake by the carbon-containing particulate, and which disperses in hydrocarbons for return to the surface.

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: Methods including creating or extending a first main fracture with a pad fluid into a subterranean formation, wherein the pad fluid is a high-viscosity fluid; alternatingly introducing a micro-proppant fluid with the pad fluid, wherein the micro-proppant fluid is a low-viscosity fluid comprising micro-sized proppant particulates; creating or extending a first branch fracture extending from the first main fracture with the alternatingly introduced micro-proppant fluid, whereby at least a portion of the micro-sized proppant particulates enter into the first branch fracture and form at least a partial monolayer of micro-sized proppant particulates therein; and introducing a macro-proppant fluid through the first opening at a second flow rate, wherein the macro-proppant fluid is a low-viscosity fluid comprising macro-sized proppant particulates, and whereby at least a portion of the macro-sized proppant particulates enter into the first main fracture and form a proppant pack therein.

Abstract: Methods of preventing or minimizing communication between adjacent wells are described. The methods include providing a pre-pad fluid, pad fluid, and/or slurry including a material, introducing the pre-pad fluid, pad fluid, and/or slurry and material into a first well adjacent a second well, allowing the material to block fractures in the first well to prevent or minimize communication between the first well and the second well, stimulating the second well after blocking the fractures, and recovering a formation fluid from the first well, the second well, or both. The material includes one or more of a conformance chemical, diverting agent, or a combination thereof.

Abstract: A method of propping created fractures and microfractures in tight formation. The method includes injecting into a wellbore a first pad fluid stage; injecting into the wellbore a second pad fluid stage; injecting into the wellbore a diverting agent; and injecting into the wellbore a main proppant slurry stage; wherein the first pad fluid stage includes an aqueous-based fluid at a rate above the fracturing gradient to create a fracture, wherein the second pad fluid stage includes an aqueous-based fluid and a low concentration of a proppant mixture including a slurry of small proppant materials and/or a slurry of conventional proppant materials to extend the fracture and open up secondary induced fractures, and wherein the main proppant slurry stage includes an aqueous-based fluid and a proppant with a larger size than the small proppant particles in the second pad fluid stage.

Abstract: A method of treating in a subterranean formation including combining an aqueous base fluid and an anionic surfactant to form a first solution; hydrating a cationic polymer with the first solution to form a viscous fluid; combining the viscous fluid with a proppant thereby forming a treatment fluid; and introducing the treatment fluid into the subterranean formation. A method of making a well treatment fluid including combining an aqueous base fluid and an anionic surfactant to form a first solution; hydrating a cationic polymer with the first solution to form a viscous fluid; and combining the viscous fluid with a proppant thereby forming a treatment fluid.

Abstract: The present invention relates to hydrolyzable compounds for treatment of a subterranean formation and methods of using the same. In various embodiments, the present invention provides a method of treating a subterranean formation including obtaining or providing a composition comprising a hydrolyzable compound comprising at least one of an ester and an anhydride. The method can include placing the composition in a subterranean formation, and at least partially hydrolyzing the hydrolyzable compound to reduce the pH downhole. In various embodiments, the subterranean formation can include a crosslinked gel, and the method can include at least partially breaking the crosslinked gel to provide a broken gel. The method can include at least partially removing the broken gel from the subterranean formation.

Abstract: A method of treating in a subterranean formation including combining an aqueous base fluid, an oil based fluid, a hydrophobic proppant, and a non-hydrophobic proppant to form an immiscible fluid system; and introducing the immiscible fluid system into the subterranean formation. A method of treating includes combining an aqueous base fluid, an oil based fluid, a hydrophobic proppant, and a non-hydrophobic proppant to form an immiscible fluid system; introducing the immiscible fluid system into a fracture in the formation; allowing the immiscible fluid system to separate into at least two separate phases, wherein the oil based fluid and hydrophobic proppant to form proppant aggregates and the aqueous based fluid to act as a spacer fluid surrounding at least a portion of the proppant aggregates; and removing the spacer fluid from the fracture during flowback stage or well production to form proppant-free channels between proppant aggregates.

Abstract: Various embodiments disclosed relate to compositions including modified release material for treatment of subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation including placing in the subterranean formation a composition including a modified release material. The modified release material can include an additive and a solid substituted or unsubstituted fatty acid having a melting point of about 3° C. to about 250° C., wherein the additive is partially or wholly enveloped by the fatty acid.

Abstract: Wellbore servicing fluid are provided that comprise a viscosifying polymeric material, a breaking agent comprising an inorganic peroxide of a divalent metal M(II) characterized by the general formula MO2, and a break rate controlling additive comprising a M(II) soluble salt, a M(II) precipitating salt, a M(II) surface precipitating salt, a M(II) solution precipitating salt, or combinations thereof.

Abstract: Various embodiments disclosed relate to a cellulose or cellulose derivative, the cellulose or cellulose derivative including grafted acrylamide or acrylic acid groups for treatment of subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation including placing in the subterranean formation a composition including a cellulose or cellulose derivative, the cellulose or cellulose derivative including grafted groups. The grafted groups are selected from the group consisting of a) grafted acrylamide groups, b) grafted acrylic acid groups or a salt or a substituted or unsubstituted (C1-C10)hydrocarbyl ester thereof, and c) a combination thereof.

Abstract: A fracturing fluid comprising: a base fluid, wherein the base fluid comprises water; proppant; and an additive, wherein the additive: (i) is a cross-linkable polymer, wherein the polymer is a polysaccharide comprising a backbone and pendant functional groups, wherein the polysaccharide is derivatized by substituting one or more of the pendant functional groups with furan; (ii) is a viscosifying agent; and (iii) is a curable resin for consolidating the proppant. A method of fracturing a subterranean formation comprising: introducing the fracturing fluid into the subterranean formation; and creating or enhancing one or more fractures in the subterranean formation.

Abstract: A method includes steps of: providing a treatment fluid including an aqueous base fluid, a gelling agent, and a multifunctional boronic crosslinker, and introducing the treatment fluid into a subterranean formation. The multifunctional boronic crosslinker includes a dendritic polymer including a water-soluble monomer and a boronic acid group, and the ratio of the water-soluble monomer to the boronic acid group is in the range from about 1:210 to about 1:800.

Abstract: Embodiments including methods comprising providing a treatment fluid comprising a first aqueous base fluid and a polymeric gelling agent, wherein the treatment fluid comprises a first surface tension; introducing a fluid mobility modifier into the treatment fluid, wherein the fluid mobility modifier comprises: a first surfactant selected from the group consisting of a non-ionic surfactant; a cationic surfactant; and any combination thereof, and a solvent-surfactant blend comprising a second aqueous base fluid, a second surfactant, a solvent, and a co-solvent, wherein the ratio of the first surfactant to the solvent-surfactant blend is in the range of between about 1:5 to about 5:1, wherein the fluid mobility modifier causes the treatment fluid to adopt a second surface tension that is less than the first surface tension; and introducing the treatment fluid into a subterranean formation.