Abstract: A fracturing fluid and method of including a cellulose polymer derivative, a diol functional group, and a borate crosslinker. The diol functional group may be a cis-diol functional group, a 1,2-diol functional group, or a 1,3-diol functional group. The cellulose polymer derivative further may include a hydroxyethyl group or a hydroxypropyl group. The fracturing fluid may also include at least one metallic crosslinker. The method may also include the steps of adding a pH adjusting agent, at least one breaker, a surfactant, a scale inhibitor, and/or a bactericide to the fracturing fluid, or mixing the fracturing fluid using mixing equipment or wherein the fracturing fluid is introduced into a subterranean formation using one or more pumps.

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 of treating particles of a particle pack located in a subterranean formation comprising: introducing an additive into the subterranean formation, wherein the additive: (i) comes in contact with the particles of the particle pack; (ii) has a chemical attraction to the particles of the particle pack; and (iii) comprises a first functional group, wherein the first functional group is a water-control agent.

Abstract: Processes for chemically removing cured resin product from surfaces and subterranean formations in case of inappropriate consolidation, plugging of screens or tubing, and equipment damage. A chemical solvent is introduced to a wellbore where a resin has cured. The resin is contacted with the chemical solvent until the resin at least partially dissolves. At least a portion of the dissolved resin is then removed from the wellbore.

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: Various embodiments disclosed related to compositions and methods of using the same for treating subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in a subterranean formation a composition that includes a viscosifier and that also includes a hydrophobically-modified polymer including at least one nitrogen-containing repeating unit.

Abstract: Various embodiments disclosed related to compositions and methods of using the same for treating subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in a subterranean formation a composition that includes a viscosifier and that also includes a hydrophobically-modified polymer including at least one nitrogen-containing repeating unit.

Abstract: Various embodiments disclosed relate to scale inhibitors and methods of treating a subterranean formation with the same. In various embodiments, the present invention provides a method of treating a subterranean formation including obtaining or providing a composition including a scale inhibitor, wherein at least one of A and B is satisfied. In A, the scale inhibitor can include at least one of 1) a copolymer including a repeating unit including at least one sulfonic acid or sulfonate group and a repeating unit including at least two carboxylic acid or carboxylate groups, and 2) a protected scale inhibitor including hydrolyzably-unmaskable coordinating groups. In B, the composition includes an aqueous phase and a lipophilic phase, wherein the lipophilic phase protectively encapsulates the scale inhibitor. The method includes placing the composition in a subterranean formation.

Abstract: Methods and compositions for treating proppant and/or formation sand to enhance proppant pack conductivity, control fines migration, and stabilize formation sand during the well production are provided. In one embodiment, the method comprises: introducing a fines migration control agent into a fluid comprising a base fluid and a plurality of proppants, wherein the fines migration control agent comprises a core group capable of attaching to the proppant and at least one end group connected to the core group capable of capturing fines; mixing the fines migration control agent with the fluid to form a proppant slurry; and injecting the proppant slurry into a wellbore penetrating at least a portion of a subterranean formation.

Abstract: A method and apparatus that includes isolating a sample having a known volume and obtained near a reservoir that has a reserve; extracting hydrocarbons from the sample; and identifying data associated with the hydrocarbons. The data may include the volume of the extracted hydrocarbons. The method also includes using the data to estimate the reserve of the reservoir. The method can also include pulverizing the sample to release additional hydrocarbons.

Abstract: Compositions and methods for storing, transporting, and/or delivering micron- and/or nano-sized solid materials in subterranean operations are provided. In one embodiment, the methods comprise: providing a fluid comprising an aqueous fluid and one or more gelling agents; mixing one or more small-sized solid materials into the fluid to form a slurry; storing the slurry for a period of storage time; mixing at least a portion of the slurry with a base fluid after the period of storage time to form a treatment fluid; and introducing the treatment fluid into a well bore penetrating at least a portion of a subterranean formation.

Abstract: Methods are provided for chemically removing cured resin product from surfaces and subterranean formations in case of inappropriate consolidation, plugging of screens or tubing, and equipment damage. A chemical solvent is introduced to a wellbore where a resin has cured. The resin is contacted with the chemical solvent until the resin at least partially dissolves. At least a portion of the dissolved resin is then removed from the wellbore.

Abstract: Treatment fluids (e.g., fracturing fluids) comprising ionic water, and associated methods of use are provided. In one embodiment, the methods comprise providing a treatment fluid comprising an aqueous base fluid comprising one or more ionic species, a polymeric viscosifying agent carrying a first ionic charge, and an ionic surfactant carrying a second ionic charge that is the opposite of the first ionic charge; and introducing the treatment fluid into a well bore penetrating at least a portion of a subterranean formation.

Abstract: A method of treating particles of a particle pack located in a subterranean formation comprising: introducing an additive into the subterranean formation, wherein the additive: (i) comes in contact with the particles of the particle pack; (ii) has a chemical attraction to the particles of the particle pack; and (iii) comprises a first functional group, wherein the first functional group is a water-control agent.

Abstract: A fracturing fluid and method of including a cellulose polymer derivative, a diol functional group, and a borate crosslinker. The diol functional group may be a cis-diol functional group, a 1,2-diol functional group, or a 1,3-diol functional group. The cellulose polymer derivative further may include a hydroxyethyl group or a hydroxypropyl group. The fracturing fluid may also include at least one metallic crosslinker. The method may also include the steps of adding a pH adjusting agent, at least one breaker, a surfactant, a scale inhibitor, and/or a bactericide to the fracturing fluid, or mixing the fracturing fluid using mixing equipment or wherein the fracturing fluid is introduced into a subterranean formation using one or more pumps.

Abstract: Various embodiments disclosed relate to compositions including polyether-functionalized linear polysiloxanes and methods and systems for using the same to treat subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation including obtaining or providing a composition including a polyetherfunctionalized linear polysiloxane. The method also includes placing the composition in a subterranean formation.

Abstract: Various embodiments disclosed relate to a curable composition for consolidation of particulates in a subterranean formation and methods of using the same. In various embodiments, the present invention provides a method of treating a subterranean formation. The method can include obtaining or providing a curable composition including a polyhedral oligomeric silsesquioxane (POSS) comprising at least one curable or curing group. The composition also includes an agent curably reactive with the curable or curing groups. The method can also include placing the composition in a subterranean formation downhole.

Abstract: The present invention relates to compositions for treatment of subterranean formations including a curable resin that is amine-curable and a curing agent having a structure including at least one primary amine and at least one secondary amine, and methods of using the same. In various embodiments, the present invention provides a method of treating a subterranean formation. The method can include obtaining or providing a composition including a curable resin that is amine-curable and a curing agent having a structure including at least one primary amine and at least one secondary amine. The method can include placing the composition in a subterranean formation downhole.

Abstract: Treatment fluid suitable for use in subterranean formations may comprise: (i) an aqueous phase comprising water having at least 1,000 ppm total dissolved inorganic salts, wherein the aqueous phase comprises at least one of: a sulfate concentration of about 4,000 ppm or greater, a phosphate concentration of about 100 ppm or greater, a carbonate concentration of about 100 ppm or greater, or a barium concentration of about 37,000 ppm or greater; (ii) a carboxymethyl hydroxyethyl cellulose, wherein: (a) the carboxymethyl hydroxyethyl cellulose has a carboxymethyl degree of substitution is in the range of about 0.3 to about 0.45 per glucopyranose unit in the polymer; and (b) the carboxymethyl hydroxyethyl cellulose has a hydroxyethyl molecular substitution is in the range of about 2.1 to about 2.9 per glucopyranose unit in the polymer; and (c) the treatment fluid is substantially free of any crosslinker; and (iii) a breaker.