Abstract: Methods for preparing and using invert emulsions and treatment fluids including the invert emulsions are provided herein. In one or more embodiments, the methods of the present disclosure comprise providing an aqueous fluid comprising water and one or more water-soluble monomers; providing an oil-based fluid comprising a solvent and one or more polymerization surfactants, wherein the solvent comprises a linear or branched dibasic ester; combining the aqueous fluid and the oil-based fluid to form an invert emulsion that comprises an aqueous phase comprising the aqueous fluid and an oil phase comprising the oil-based fluid; and polymerizing at least a portion of the one or more water-soluble monomers in the invert emulsion.

Abstract: Treatment fluids and associated methods and systems for demulsifying an emulsified well fluid. An example method includes contacting the emulsified well fluid with a treatment fluid comprising: an aqueous base fluid; an alcohol; a resin alkoxylated oligomer; a polyol; and a polyamine polyether. The emulsified well fluid is separated into an aqueous phase and an oleaginous phase after contact with the treatment fluid.

Abstract: A method of servicing one or more wellbores penetrating a subterranean formation comprising placing into at least one of one or more injection wells a communication enhancing fluid, wherein the subterranean formation comprises a plurality of zones having a natural resource proximate to the at least one of the one or more injection wells, wherein the communication enhancing fluid establishes a fluid communication network between at least a portion of the plurality of zones, and wherein establishing of the fluid communication network results in an increased production of the natural resource from one or more production wells penetrating the subterranean formation.

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: A method of enhanced oil recovery comprising placing into a subterranean formation a treatment fluid comprising (i) a compound comprising a phosphonoalkyl moiety; and (ii) a base fluid wherein a pH of the treatment fluid ranges from about 5 to about 9 wherein the treatment fluid is placed into the subterranean formation via one or more injection wells and travels a distance into the subterranean formation in a direction of one or more recovery/production wells.

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 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: Described herein are penetrating compositions that include ethoxylated C12-C16 alcohols, 2-ethyl hexanol, and isopropyl alcohol, and are injectable into a near-wellbore subterranean formation. The penetrating compositions may include water or brine. The penetrating compositions are free of ethylene glycol monobutyl ether (EGMBE) and nonylphenol ethoxylates (NPE). Also described are methods of using penetrating compositions that that include introducing a penetrating composition into a near-wellbore formation and reducing surface tension at an oil/water interface within the formation.

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: Energy created by a propellant can form a fracture in a subterranean formation. For example, a treatment fluid can be introduced into a subterranean formation. A propellant can be positioned in the subterranean formation. The propellant can be detonated to generate a fracture in the subterranean formation for receiving at least part of the treatment fluid. The treatment fluid may include an acid, a hydrolysable in-situ acid generator, a chelating agent, a hydrolysable in-situ chelating agent generator, or mixtures thereof.

Abstract: A method may comprise: introducing a treatment fluid into a wellbore penetrating a subterranean formation wherein the treatment fluid comprises a base fluid; a carbonate compound, wherein the carbonate compound at least partially plugs a zone in the subterranean formation; and an acid; and diverting at least a portion of the treatment fluid and/or a subsequently introduced fluid away from the zone.

Abstract: A method of treating a well using a well treatment fluid that comprises an aqueous base fluid and a wettability modifier is provided. 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. Also provided is a well treatment fluid.

Abstract: Complexation of metal ions using chelating agents within a subterranean formation can often be desirable, such as to temper the formation of metal-containing precipitates. However, many chelating agents are produced commercially in an alkali metal salt form that may not be entirely suitable for use downhole, particularly in subterranean formations containing a siliceous material. The working pH range of some types of chelating agents may also be limiting. Treatment fluids comprising an aqueous carrier fluid having an acidic pH, a sulfonated iminodialkanoic acid, and ammonium ions may at least partially address downhole precipitation issues, while providing further advantages as well. Methods for forming sulfonated iminodialkanoic acids can comprise reacting an iminodialkylnitrile with a sultone under acidic conditions to form a fluid comprising a sulfonated iminodialkanoic acid and ammonium ions.

Abstract: A method for treating a subterranean formation that includes preparing a treatment fluid comprising a base fluid, a relative permeability modifier (RPM) and a particulate and performing a treatment operation by injecting the treatment fluid into a portion of the subterranean formation.

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: 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: Treatment fluids and associated methods for treating a subterranean formation. An example method includes introducing a treatment fluid into a wellbore penetrating the subterranean formation. The treatment fluid includes an oleofuransulfonate surfactant; a treatment fluid additive capable of interaction with a cation; and an aqueous fluid. The cation is present in the treatment fluid or contacts the treatment fluid. The method further includes solvating the treatment fluid additive with the oleofuransulfonate surfactant.

Abstract: Various embodiments disclosed relate to demulsifier compositions for treatment of subterranean formations or produced petroleum comprising an emulsion. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a demulsifier composition. The demulsifier composition includes an alkanolamide surfactant that is a (C1-C50)hydrocarbyl amide having groups R1 and R2 substituted on the amide nitrogen, wherein R1 and R2 are each independently selected from the group consisting of —H, —(C1-C50)hydrocarbyl, and —(C1-C50)hydrocarbylene-OH, wherein at least one of R1 and R2 is —(C1-C50)hydrocarbylene-OH. The demulsifier composition includes an alkoxylated alcohol surfactant that is a (C1-C50)hydrocarbyl-OH having a —((C2-C3)alkylene-O)n—H group on the —OH group, wherein n is about 1 to about 100. The demulsifier composition also includes an amine-oxide surfactant.

Abstract: Various embodiments disclosed relate to demulsifier compositions for treatment of subterranean formations or produced petroleum comprising an emulsion. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a demulsifier composition. The demulsifier composition includes an alkanolamide surfactant that is a (C1-C50)hydrocarbyl amide having groups R1 and R2 substituted on the amide nitrogen, wherein R1 and R2 are each independently selected from the group consisting of —H, —(C1-C50)hydrocarbyl, and —(C1-C50)hydrocarbylene-OH, wherein at least one of R1 and R2 is —(C1-C50)hydrocarbylene-OH. The demulsifier composition includes an alkoxylated alcohol surfactant that is a (C1-C50)hydrocarbyl-OH having a —((C2-C3)alkylene-O)n-H group on the —OH group, wherein n is about 1 to about 100. The demulsifier composition also includes an amine-oxide surfactant.

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.