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 at least one resin of formula (I) and at least one compound of formula (II).

Abstract: In some examples a method of well treatment may comprise: providing a treatment fluid comprising a microemulsified resin additive, wherein the microemulsified resin additive comprises a continuous phase and a discontinuous phase, wherein the continuous phase comprises an aqueous liquid, wherein the discontinuous phase is in form of micelles of about 200 nm or less in diameter and comprises a resin; introducing the treatment fluid into a subterranean formation penetrated by a wellbore; and allowing the treatment fluid to set in the subterranean formation.

Abstract: The present invention relates to cocrystals including a scale-inhibiting compound, and methods of using the cocrystals for treating a subterranean formation. In various embodiments, the present invention provides a method of treating a subterranean formation including obtaining or providing a composition including cocrystals. Each cocrystal independently includes a scale-inhibiting compound and a secondary material. The method also includes placing the composition in a subterranean formation.

Abstract: A thin-layer chromatography device can be used to determine or select a surfactant solution for use during hydrocarbon-fluid production operations. The thin-layer chromatography device can include a chamber that can receive a surfactant solution that includes a surfactant and a fluid. The thin-layer chromatography device can also include a substrate that can be coated with a layer of adsorbent material to form a thin-layer substrate and a hydrocarbon fluid can be disposed on the thin-layer substrate. The thin-layer substrate, along with the hydrocarbon fluid, can be positioned within the chamber to determine a mobility index of the hydrocarbon fluid when the hydrocarbon fluid contacts the surfactant solution. The mobility index can indicate an eluting capability of the surfactant solution with respect to the hydrocarbon fluid and can be used to select the surfactant solution to be injected into a wellbore that includes the hydrocarbon fluid to enhance hydrocarbon-fluid production operations.

Abstract: Various embodiments disclosed relate to surfactant compositions for treatment of subterranean formations and produced oil. In various embodiments, the present invention provides a method of treating a subterranean formation including placing in the subterranean formation a surfactant composition. The surfactant composition includes an alkanolamide surfactant and an alkoxylated alcohol surfactant. The surfactant composition also includes an ionic surfactant, a nonionic surfactant, or a combination thereof at least one compound according to Formula H.

Abstract: Methods and compositions for treatment fluids that include carbonate and bicarbonate to control pH for use in subterranean treatments are provided. In one embodiment, the methods comprise providing a treatment fluid comprising an aqueous base fluid; a crosslinkable polymer; a crosslinking agent; and an amount of carbonate and an amount of bicarbonate, wherein the molar ratio of the amount of carbonate to the amount of bicarbonate is in the range of from about 1:2.3 to about 1:2.7; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.

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 surfactant compositions for treatment of subterranean formations and produced oil. In various embodiments, the present invention provides a method of treating a subterranean formation including placing in the subterranean formation a surfactant composition. The surfactant composition includes an alkanolamide surfactant and an alkoxylated alcohol surfactant. The surfactant composition also includes an ionic surfactant, a nonionic surfactant, or a combination thereof.

Abstract: A fluid comprising: an aqueous phase; a cellulose derivative dispersed or dissolved in the aqueous phase; a guar derivative dispersed or dissolved in the aqueous phase; a titanium crosslinker dispersed or dissolved in the aqueous phase; and a zirconium crosslinker dispersed or dissolved in the aqueous phase. A method of treating a well or a well system can include: (A) forming a treatment fluid according to the disclosure; and (B) introducing the treatment fluid into a treatment zone of a well.

Abstract: Various embodiments disclosed relate to methods of treating subterranean formations including sequential use of at least two surfactants. In various embodiments, the present invention provides a method of treating a subterranean formation including sequentially placing in the subterranean formation a penetrating-aid surfactant and a pore-declogging surfactant.

Abstract: Degradable particulates may allow for temporary redirection or occlusion of a fluid within a subterranean formation. However, many types of degradable particulates can be problematic for large-scale use, such as during subterranean treatment operations. Methods for treating a subterranean formation using degradable particulates may comprise: providing pre-coated particulates comprising a latently dissolvable core and a transient coating surrounding the latently dissolvable core, the latently dissolvable core and the transient coating comprising different materials; and introducing a treatment fluid comprising a carrier fluid and a plurality of the pre-coated particulates into a wellbore penetrating a subterranean formation in conjunction with a stimulation operation, a material comprising the latently dissolvable core being soluble in the carrier fluid or a formation fluid present within the subterranean formation.

Abstract: Methods including introducing a low-polymer loading treatment fluid (LPLTF) into a subterranean formation for performing a subterranean formation operation at a target interval. The LPLTF comprises an aqueous-based fluid, a guar-based gelling agent in an amount of less than about 2.4 grams/liter of the liquid portion of the LPLTF, and a dual crosslinking additive comprising a metal crosslinker and a multifunctional boronic acid crosslinker in a ratio in the range of about 1:100 to about 100:1.

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: 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: 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: 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.

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: A thin-layer chromatography device can be used to determine or select a surfactant solution for use during hydrocarbon-fluid production operations. The thin-layer chromatography device can include a chamber that can receive a surfactant solution that includes a surfactant and a fluid. The thin-layer chromatography device can also include a substrate that can be coated with a layer of adsorbent material to form a thin-layer substrate and a hydrocarbon fluid can be disposed on the thin-layer substrate. The thin-layer substrate, along with the hydrocarbon fluid, can be positioned within the chamber to determine a mobility index of the hydrocarbon fluid when the hydrocarbon fluid contacts the surfactant solution. The mobility index can indicate an eluting capability of the surfactant solution with respect to the hydrocarbon fluid and can be used to select the surfactant solution to be injected into a wellbore that includes the hydrocarbon fluid to enhance hydrocarbon-fluid production operations.

Abstract: Methods including preparing a treatment fluid comprising a bulk amount of anhydrous ammonia, wherein the anhydrous ammonia is present in an amount greater than about 10% by weight of a liquid portion of the treatment fluid, and wherein the anhydrous ammonia is in a phase selected from the group consisting of a liquid phase, a gaseous phase, supercritical phase, and any combination thereof; and introducing the treatment fluid into a subterranean formation.

Abstract: A method is provided for improved degradation of metal-crosslinked polymer gels, which are useful in oil and gas treating operations. In this method a polysaccharide having a higher degree of substitution than the polymer in the polymer gel is added to the gel. The polysaccharide removes the crosslinking metal ion from the gel to thus break down the gel and reduce its viscosity.