Methods of treating a subterranean formation are described. The methods include introducing a treatment fluid that includes a friction reducing polymer (e.g., a cationic friction reducing polymer or an anionic friction reducing polymer) into the subterranean formation. The cationic friction reducing polymer is allowed to degrade and release choline chloride or polyDADMAC, which can each act as a clay stabilizer. The anionic friction reducing polymer is allowed to degrade and release AMPS, which can act as a surfactant, a scale inhibitor, a paraffin inhibitor, or an asphaltene inhibitor, or polyacrylic acid, which can act as a scale inhibitor.

A composition includes an emulsion of nanocomposite in water and a proppant. The nanocomposite includes an epoxy resin and an organically modified montmorillonite compatible to the epoxy resin.

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.

Compositions containing a diverting material, and related methods and systems for diverting a fluid from a high permeability zone in an underground formation to a low permeability zone in the underground formation. The diverter material contains a polyurethane and a second polymer. The compositions, methods and systems may be used to achieve more homogeneous stimulation during a well stimulation treatment.

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.

Emulsions, treatment fluids and methods for treating subterranean formations are provided, wherein the emulsions comprise water, a water-immiscible liquid, one or more polymers, one or more ethoxylated amine compounds and optionally, one or more organic or inorganic salts. The emulsions are particularly suitable for use in harsh brine conditions.

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.

The disclosure relates to an aqueous acidizing fluid. In addition to an acid, the fluid contains an organophosphorus surfactant and/or an acid retarder. The organophosphorus surfactant may be an amino phosphonate or a phosphino carboxylate. The acid retarder comprises the combination of urea or a urea derivative and a bifunctional organic compound. Suitable bifunctional organic compounds contain at least one quaternary ammonium or phosphonium and at least one alcohol as well as salts of nitrogen containing heterocyclic rings.

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.

Process for producing hydrophobically associating polyacrylamides Summary Process of manufacturing hydrophobically associating polyacrylamides comprising at least acrylamide or derivatives thereof and an associative monomer by adiabatic gel polymerization of an aqueous monomer solution, wherein the concentration of the monomers in the aqueous solution is from 1 mole/kg to 3.3 mole/kg, relating to the total of all components of the aqueous monomer solution. The process yields hydrophobically associating polyacrylamides having an improved viscosity efficiency. Hydrophobically associating polyacrylamides obtainable by the process of the present invention and use of such hydrophobically associating polyacrylamides for oilfield applications, in particular for enhanced oil recovery, conformance control and hydraulic fracturing.