Abstract: Fracturing fluids for treating subterranean formations. An example fracturing fluid includes an anti-syneresis agent, a water-soluble terpolymer, a terpolymer hydration aid, an antioxidizing agent, a metal crosslinking agent, a breaker, and an aqueous base fluid. The fracturing fluid is introduced into a wellbore penetrating the subterranean formation at a pressure sufficient to fracture the subterranean formation and the subterranean formation is fractured with the fracturing fluid.

Abstract: Fracturing fluids for fracturing a subterranean formation. An example fracturing fluid includes an organic acid ester, a water-soluble terpolymer, a terpolymer hydration aid, an antioxidizing agent, a metal crosslinking agent, a breaker, and an aqueous base fluid. The fracturing fluid is introduced into the subterranean formation and the subterranean formation is fractured with the fracturing fluid.

Abstract: Fracturing fluids for treating subterranean formations. An example fracturing fluid includes an anti-syneresis agent, a water-soluble terpolymer, a terpolymer hydration aid, an antioxidizing agent, a metal crosslinking agent, a breaker, and an aqueous base fluid. The fracturing fluid is introduced into a wellbore penetrating the subterranean formation at a pressure sufficient to fracture the subterranean formation and the subterranean formation is fractured with the fracturing fluid.

Abstract: A coupling agent for deployment around an optical fiber in a subsurface wellbore, the coupling agent including a curable or non-curable compound that can form into a reversible polymerized gel state located around at least a portion of the optical fiber and there is a gel-optical fiber interface strain gradient that is greater than a wellbore fluid-optical fiber strain gradient. A method of deploying an optical fiber in a fluid path of a subsurface wellbore and introducing a coupling agent in the fluid path.

Abstract: Methods and treatments fluids for treating a wellbore. One example method introduces the treatment fluid into the wellbore. The treatment fluid comprises an aqueous fluid, an aminopolycarboxylic acid, a nanoparticle dispersed, and an organic solvent. The treatment fluid has a pH in a range between about 5 to about 9. The method further includes contacting a rock surface in the subterranean formation; wherein at least a portion of the rock surface is coated with a hydrocarbon. The treatment fluid removes a portion of the hydrocarbon from the rock surface and alters the rock surface to be water-wet.

Abstract: A method of servicing a well having a wellbore extending from a surface wellsite and penetrating a subterranean formation, can include contacting a binder composition with particulate material, and binding the particulate material with the binder composition to form consolidated particulate material in the wellbore, in the formation, or both. The binder composition can include an aqueous fluid, an alkali metal silicate, and a silicate bonding activator.

Abstract: A water-based carrier-fluid system comprising a brine formed from water saturated with at least one saturation salt, a viscoelastic surfactant, and one or more salt crystals. The water-based carrier-fluid system is formed by adding the viscoelastic surfactant to the brine to produce a first mixture prior to the one or more salt crystals being added to the mixture. The salt in the salt crystals has a Ksp value equal to or greater than the saturation salt.

Abstract: A method for acidizing a subterranean formation may include: preparing a water-in-oil emulsion comprising a non-polar phase, a polar phase, an emulsifier an acid, and a drag reducing agent; pumping the water-in-oil emulsion into a wellbore penetrating a subterranean formation above a fracture gradient of the subterranean formation to create or extend at least one fracture in the subterranean formation.

Abstract: A coupling agent for deployment around an optical fiber in a subsurface wellbore, the coupling agent including a curable or non-curable compound that can form into a reversible polymerized gel state located around at least a portion of the optical fiber and there is a gel-optical fiber interface strain gradient that is greater than a wellbore fluid-optical fiber strain gradient. A method of deploying an optical fiber in a fluid path of a subsurface wellbore and introducing a coupling agent in the fluid path.

Abstract: A variety of methods, systems, and compositions are disclosed, including, in one example, a method that includes: introducing a treatment fluid into a wellbore extending into a subterranean formation, wherein the treatment fluid comprises: water; an acid; a corrosion inhibitor; and a friction reducer having a vinyl phosphonic acid moiety, an acrylic acid moiety, a vinyl sulfonate moiety, a diallyl moiety, or an acrylamide moiety; and flowing at least a portion of the treatment fluid into the subterranean formation, wherein the pressure required to achieve a given flow rate of the treatment fluid into the subterranean formation is reduced by at least 1% as compared to the pressure required to achieve the given flow rate of the treatment fluid in the subterranean formation without the friction reducer.

Abstract: A solids-control fluid for controlling flow of solids in a subterranean formation is disclosed herein. The solids-control fluid can include a diluent and a curable resin. The diluent can include a glycol ether. The curable resin can be dispersed within the diluent for controlling flow of solids in the subterranean formation.

Abstract: A method may include: introducing a hydrocarbon containing waste source into a bioreactor, metabolizing at least a portion of hydrocarbons from the hydrocarbon containing waste source using a bacterial organism to form a biologically derived intermediate product; and introducing at least a portion of the biologically derived intermediate product into a chemical reactor and reacting at least a portion of the biologically derived intermediate product to form a chemical product.

Abstract: A solids-control fluid for controlling flow of solids in a subterranean formation is disclosed herein. The solids-control fluid can include a diluent and a curable resin. The diluent can include a glycol ether. The curable resin can be dispersed within the diluent for controlling flow of solids in the subterranean formation.

Abstract: Compositions and methods for treating a well with a treatment fluid. An example method prepares a treatment fluid by combining a furan-based polymer, a Bronsted acid, at least one of an anhydride and/or dibasic ester, a wetting agent, and a docking agent. The treatment fluid is introduced into a wellbore and a wellbore operation is performed with the treatment fluid.

Abstract: A variety of methods and well treatment fluids are disclosed, including, in one embodiment, a method of treating a subterranean formation, comprising contacting the subterranean formation with a well treatment additive, wherein the well treatment additive comprises an ionic liquid comprising a cation and an anion having the following formula: [R1R2R3R4N]+[X]?, wherein R1, R2, R3, R4 are individually selected from the group consisting of an alkyl group, a hydroxyalkyl group, and a combination thereof provided that at least one of R1, R2, R3, R4 is the hydroxyalkyl group, and wherein the anion X? comprises at least one anion selected from the group consisting of F?, Cl?, Br?, I?, H2PO4?, HPO42?, PO43?, HSO4?, C7H7OSO3?, C7H7SO3?, SO42?, CH3SO3?, C2H5OSO3?, CH3OSO3?, C2H5OSO3?, and combinations thereof. In one or more embodiments, a well treatment fluid comprises a base fluid and a well treatment additive comprising the ionic liquid.

Abstract: A variety of methods and compositions are disclosed, including, in one embodiment, a method of synthesizing an ionic liquid comprising a cation and an anion, comprising: reacting an alkyl hydroxyalkyl tertiary amine with an alkyl sulfate to form the ionic liquid having the following formula: [R1R2R3R4N]+[X]?, wherein R1, R2, R3, R4 are individually selected from the group consisting of an alkyl group, a hydroxyalkyl group, and a combination thereof provided that at least one of R1, R2, R3, R4 is the hydroxyalkyl group, and wherein the anion X? comprises at least one anion selected from the group consisting of F?, Cl?, Br?, I?, H2PO4?, HPO42? PO43?, HSO4?, C7H7OSO3?, C7H7SO3?, SO42?, C2H5SO4?, CH3SO3?, C2H5SO3?, CH3OSO3?, C2H5OSO3?, and combinations thereof.

Abstract: Compositions and methods using subterranean treatment fluids comprising water-soluble polymers are provided. In some embodiments, the methods include: adding an anionic or amphoteric water-soluble polymer to a treatment fluid comprising an aqueous base fluid; adding a dewatering agent to the treatment fluid, wherein the dewatering agent comprises an aqueous phase, a solvent, a co-solvent, and one or more surfactants selected from the group consisting of: ethoxylated alcohol, a polyamine polyether, a resin alkoxylated oligomer, and any combination thereof; and introducing the treatment fluid into a well bore penetrating at least a portion of the subterranean formation.

Abstract: Methods and compositions for performing a sealing operation in a wellbore. An example method introduces a sealant composition into the wellbore while the sealant composition is under shear. The sealant composition comprises a thixotropic material, a conformance gel system, and an aqueous base fluid. The sealant composition is placed into a target location, and applied shear is reduced to the sealant composition when in the target location thereby allowing the sealant composition to thicken in the target location. Fluid flow across the target location is reduced by a fluid seal formed by the thickened sealant composition.

Abstract: Methods and fluids for consolidating unconsolidated particulates. An example method introduces a furfuryl alcohol-based resin treatment fluid into a wellbore; wherein the furfuryl alcohol-based resin treatment fluid is a furfuryl alcohol-based resin and a diluent. The method contacts the unconsolidated particulates within the wellbore with the furfuryl alcohol-based resin treatment fluid to produce resin-contacted unconsolidated particulates. The method further introduces a substituted amine acid treatment fluid into the wellbore after the introduction of the furfuryl alcohol-based resin treatment fluid into the wellbore; wherein the substituted amine acid treatment fluid is a substituted amine acid salt and a solvent. The method further contacts the resin-contacted unconsolidated particulates with the substituted amine acid treatment fluid.

Abstract: Methods and fluids for consolidating unconsolidated particulates. An example method introduces a furfuryl alcohol-based resin treatment fluid into a wellbore; wherein the furfuryl alcohol-based resin treatment fluid is a furfuryl alcohol-based resin and a diluent. The method contacts the unconsolidated particulates within the wellbore with the furfuryl alcohol-based resin treatment fluid to produce resin-contacted unconsolidated particulates. The method further introduces a substituted amine acid treatment fluid into the wellbore after the introduction of the furfuryl alcohol-based resin treatment fluid into the wellbore; wherein the substituted amine acid treatment fluid is a substituted amine acid salt and a solvent. The method further contacts the resin-contacted unconsolidated particulates with the substituted amine acid treatment fluid.