A fines-fixing agent that has improved compatibility with organic complexed borate fracturing fluids is disclosed. Existing fines fixing agents have a high concentration of unreacted caustic that results in a product pH of approximately 12. This high pH affects the crosslinker and the overall fracturing fluid system stability, promoting precipitation of the organic crosslinker. These effects can be mitigated by neutralizing the fines fixing agents with an acid such as hydrochloric or acetic acid to a pH of 6 or lower.

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.

An aqueous caustic composition comprising: a caustic component; an additive adapted to provide an extended buffering effect to the caustic composition when such is exposed to an acid; and water. Methods of using such compositions are also disclosed.

A completion/stimulation/production fluid and injection mixture blend is disclosed. The blend may include an aqueous fluid, a polymer system and an injection mixture that includes a polyol, a natural sugar, an artificial sugar, or a combination thereof.

Methods and compositions for treating subterranean formations with fluids containing superabsorbent polymer particles are provided. In one embodiment, the methods comprise introducing a treatment fluid into a well bore penetrating at least a portion of a subterranean formation, the treatment fluid including an aqueous base fluid, and one or more superabsorbent polymer particles comprising a plurality of monomers and one or more crosslinkers wherein at least one crosslinker is a labile crosslinker.

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 method of polymer flooding within a sandstone formation the method comprising: injecting a treatment fluid composition into a wellbore, the treatment fluid composition comprising: a base fluid, and a viscosifier comprising a branched block copolymer wherein the branched block copolymer is a crosslinked, polymerized reaction product of crosslinker C and monomer A and monomer B and monomer D; and increasing hydrocarbon production from the wellbore.

Fracturing fluid compositions including a base fluid including a high TDS produced and/or flow back water, brackish water, RO reject water, clear brine, and mixtures thereof with or without added fresh water and systems, and methods for making and using same, where the method includes: (a) adding a first buffer to adjust the pH of a base fluid to an acidic pH, (b) adding a hydratable polymer or polymer slurry to the base fluid to form a hydratable polymer fracturing fluid, (c) adding a cross-linking composition to the hydratable polymer fracturing fluid to form a pre-cross-linked fracturing fluid, and (d) if needed, adding a second buffer to the pre-cross-linked fracturing fluid to adjust the pH of the pre-cross-linked fracturing fluid to form a viscosified fracturing fluid having a crosslinked structure.

Methods of fracturing a subterranean formation containing a hydrocarbon include introducing a first fracturing fluid that includes natural gas into the formation at a rate and pressure sufficient to create a complex fracture in the formation; introducing a second fracturing fluid into the formation, wherein the second fracturing fluid comprises water, a gelling agent, a foaming agent, natural gas, and proppant particulates; and allowing the second fracturing fluid to transport a portion of the proppant particulates into the complex fracture.

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.