Discrete, individualized carbon nanotubes having targeted, or selective, oxidation levels and/or content on the interior and exterior of the tube walls can be used for nanotube-mediated controlled delivery of degradative molecules, such as oxidizers and enzymes, for oil-field drilling applications. A manufacturing process using minimal acid oxidation for carbon nanotubes may also be used which provides higher levels of oxidation compared to other known manufacturing processes.

A method of preparing a fracturing fluid comprising: preparing or providing an aqueous fluid containing iron ions; screening a plurality of friction reducers against the aqueous fluid wherein the plurality of friction reducers are anionic, cationic, nonionic, amphoteric, or combinations thereof; selecting at least one friction reducer from the plurality of friction reducers based at least in part on the step of screening; and preparing a fracturing fluid including the at least one friction reducer.

A treatment fluid system for reducing permeability of high permeability zones in a subterranean reservoir formation comprising a fluid composition comprising a nano-crosslinker, the nano-crosslinker comprising a nanomaterial, and a crosslinker, wherein the crosslinker comprises a chemical group selected from the group consisting of carbonyl, sulfhydryl, amine and imine, wherein the nano-crosslinker is produced by a method selected from the group consisting of pre-treating the nanomaterial with the crosslinker such that the crosslinker has been functionalized onto the nanomaterial, embedding the crosslinker on the nanoparticle, grafting the crosslinker onto the nanomaterial, and coating the crosslinker on the nanomaterial, a base polymer, and a base fluid, the base fluid operable to suspend the fluid composition, wherein the base fluid comprises water, wherein the treatment fluid system is operable to reduce permeability of a high permeability zone in the subterranean reservoir formation.

A dry polymer powder for use in enhanced petroleum recovery without being prehydrated before being added to water or brine to be introduced into a wellhead. The dry polymer powder consisting of at least one of a polyacrylamide, a copolymer of acrylamide and acrylic acid, a galactomannan, or cellulosic polymer or derivatives thereof, and the polymer can be crosslinked or not crosslinked, provided that if they are homo- or co-polymers of acrylic acid, they are not crosslinked. The dry polymer powder has a polymer size range distribution of 6.6%<40 mesh and 85.4% of 40 to 200 mesh and 8%>200 mesh, and wherein the polymer size range ensures that the dry polymer powder will efficiently hydrate in the water or brine within about one minute without forming fisheyes.

Compositions and methods for fracturing a subterranean formation are presented. Also provided are compositions and methods for reducing friction-related losses in a well treatment fluid. In general, the compositions include a copolymer that includes one or more vinylphosphonic acid (VPA) monomers.

Emulsions, treatment fluids and methods for treating subterranean formations are provided, wherein the emulsions comprise water, a water-immiscible liquid, one or more polymers, and an inverting surfactant composition comprising one or more surfactants selected from the group consisting of ethoxylated amine compounds, ethoxylated fatty acid compounds, and alkyl polyethyleneglycol ether carboxylic acid compounds, alkyl polyglycol ether carboxylic acid compounds, and salts or esters thereof. The emulsions are particularly suitable for use in brine.

Provided herein are methods systems and compositions of a fracturing fluid comprising an associative polymer and clay nanoparticles. A method may comprise: providing a fracturing fluid comprising: a carrier fluid; an associative polymer; and clay nanoparticles; and injecting the fracturing fluid into a subterranean formation at or above a fracture gradient.

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.

Methods for fracturing a subterranean formation penetrated by a well bore are provided, the method comprising the step of injecting a well treatment fluid into the well bore at a pressure and flow rate sufficient to fracture the subterranean formation, wherein the well treatment fluid comprises one or more iron-containing compounds and one or more booster compounds. The methods can be used to reduce viscosity and to facilitate the decomposition of acrylamide-containing polymers.

Systems and methods include using a fracture fluid downhole for fracturing a formation. The method includes providing an aqueous solution comprising dissolved solids at a certain ionic strength, and adding a proppant to create a fracture fluid. The method continues by adding a polymeric additive and a surfactant to the fracture fluid, wherein the polymeric additive comprises friction reducing capabilities that can be decreased by the ionic strength present in the fracture fluid (i.e., ionic strength originally found in the water). The addition of the polymeric additive and the surfactant to the fracture fluid creates an enhanced fracture fluid, wherein the surfactant increases the performance of the friction reducing capabilities of the polymeric additive in the enhanced fracture fluid, which provides a more efficient fracturing operation. The method concludes by pumping the enhanced fracture fluid downhole for a more efficient fracture of the formation.