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 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 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 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: 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.

Abstract: Systems and methods wherein well-treatment fluids are evaluated for use in a subterranean reservoir. The systems and methods utilize quartz crystals configured to be quartz crystal microbalances (QCM). The QCM has a surface with a reservoir-specific material deposited on the surface. The reservoir-specific material is representative of formation material or proppant. Changes in mass of the reservoir-specific material are measured using the QCM. The changes reflect the interaction of the treatment fluid with the reservoir-specific material and/or hydrocarbons in the reservoir-specific material.

Abstract: Methods and treatment fluids for removing mixed scale. A treatment fluid is introduced into a wellbore comprising a mixed scale of interspersed calcium carbonate and calcium sulfate. The treatment fluid comprises: phosphonomethyliminodiacetic acid, N,N-bis(phosphonomethyl)glycine, or a combination thereof; and an aqueous base fluid. The treatment fluid has a pH in a range between about 6 to about 8. The method further comprises contacting the mixed scale with the treatment fluid.

Abstract: A wellbore servicing fluid comprising (a) a cationic formation stabilizer having (i) a molecular weight in a range of from equal to or greater than 0.05 to equal to or less than 2.0 kiloDaltons (kDa), or (ii) cationic charge functional groups of greater than 2 to equal to or less than 5 cationic charges per molecule, or (iii) both (i) and (ii), (b) an anionic friction reducer, and (c) an aqueous fluid.

Abstract: A method of producing natural resources from a wellbore penetrating a subterranean formation with a Huff and Puff process comprising: (a) placing a recovery enhancing fluid system into the wellbore during an injection (Huff) period of time wherein placing the recovery enhancing fluid system comprises injecting under pressure; (b) ceasing injection of the recovery enhancing fluid system and allowing the composition to soak in the subterranean formation for a soak period of time; (c) producing fluids from the subterranean formation during a production (Puff) period of time; and (d) optionally repeating steps (a) to (c) for a plurality of Huff, soak, and Puff periods of time, respectively.

Abstract: A method of enhanced oil recovery comprising introducing into one or more injection wells located within a subterranean formation a treatment fluid comprising (i) an aminopolycarboxylic acid comprising a phosphonoalkyl moiety; and ii) a surfactant blend; and removing hydrocarbons from one or more production wells. A method of enhanced oil recovery comprising introducing into one or more injection wells located within a subterranean formation a treatment fluid comprising (i) an aminopolycarboxylic acid comprising a phosphonoalkyl moiety; and ii) a surfactant blend wherein the subterranean formation comprises non-source rock, naturally-fractured rock, low porosity rock, calcite rich reservoir rock or a combination thereof; and removing hydrocarbons from one or more production wells.

Abstract: Surfactant compositions and methods for hydrocarbon recovery from a subterranean formation are provided. In some embodiments, the methods include: introducing a surfactant composition comprising an aqueous phase, an oil phase, an organic solvent, and one or more surfactants into a wellbore penetrating at least a portion of a subterranean formation; introducing an organic compound comprising a phosphonoalkyl moiety into the wellbore; and at least partially displacing a hydrocarbon from the subterranean formation by contacting a surface in the subterranean formation with the surfactant composition or the organic compound. In some embodiments, the compositions include: an aqueous phase; an oil phase comprising at least one solvent; an organic solvent; one or more surfactants; and at least one organic compound comprising a phosphonoalkyl moiety.

Abstract: A method of treating a well, comprising introducing a well treatment fluid into the well. The well treatment fluid includes an aqueous base fluid and a dewatering agent. The dewatering agent includes water, a demulsifying surfactant, and a polyamine polyether.

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: 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 treatment fluids for removing mixed scale. A treatment fluid is introduced into a wellbore comprising a mixed scale of interspersed calcium carbonate and calcium sulfate. The treatment fluid comprises: phosphonomethyliminodiacetic acid, glycine-N,N-bis(methylene phosphonic acid), or a combination thereof; and an aqueous base fluid. The treatment fluid has a pH in a range between about 6 to about 8. The method further comprises contacting the mixed scale with the treatment fluid.

Abstract: A well treatment fluid comprising an aqueous base fluid and a wettability modifier, and a method using the well treatment fluid. The wettability modifier includes an alkylamine oxide surfactant, and an organic compound having a phosphonoalkyl moiety. As an example, the well treatment fluid is suitable for treating oil-wet formations.