The present invention relates to friction reducers and to well treatment fluids. In one embodiment there is provided a friction reducing composition comprising (a) a phosphonium compound and (b) a polymeric friction reducer. In a further embodiment there is provided a well treatment fluid comprising a phosphonium compound.

Water-in-oil emulsions are provided that include an alkyl propylene diamine and an ethoxylated alcohol as the inverting surfactant, which is present in an amount less than 5 percent by weight of the water-in-oil emulsion.

Electro-responsive hydrogel particles are flowed into a first wellbore formed in a subterranean formation. An electric circuit is established between the first wellbore and a second wellbore formed in the subterranean formation. An electric current is applied through the electric circuit, thereby exposing the electro-responsive hydrogel particles to an electric field and causing at least one of swelling or aggregation of the electro-responsive hydrogel particles to form a flow-diverting plug within the subterranean formation. Water is flowed into the first wellbore to increase hydrocarbon production from the second wellbore.

Tracer eluting proppants, such as proppants that have polymeric coatings on them that include tracers, such as a fluorescent dye. The tracer eluting proppants can comprise proppant particles coated with a polymeric coating that can elute tracer under some, but not all conditions. For example, the tracer can be eluted at elevated temperature, pH, and/or salinity conditions, but not elute at lower temperature, pH, and/or salinity conditions. Methods of making and using tracer eluting proppants are also disclosed, including methods for characterizing subterranean reservoirs.

Methods for treating a subterranean formation. An example method includes introducing a treatment fluid into a wellbore penetrating the subterranean formation. The treatment fluid includes an aqueous base fluid, a cationic or amphoteric friction reducer, and a substituted alkanolamine scale inhibitor. The method further includes contacting scale deposits on a surface in fluid communication with the wellbore and/or subterranean formation with the treatment fluid.

Core-shell particles for treatment of subterranean formations are provided. A method may include placing in the subterranean formation a composition including a core-shell particle including a hydrophilic core and a hydrophobic shell.

Provided herein are methods of using chlorate compositions to decrease the viscosity of polyacrylamide containing fluids, such as, for instance, petroleum well treatment fluids (e.g., fracturing fluids). Also provided herein are methods of treating polymer plugging in hydrocarbon bearing subterranean formations using chlorate compositions. Also provided herein are well treatment fluids comprising polyacrylamide and chlorate.

Disclosed herein are degradable diverter materials comprising a polyacrylate compound. In particular, the degradable diverter material may be a particulate with each individual particle being having a polyacrylate compound and optionally at least one inert filler. The degradable diverter material may be introduced into a wellbore penetrating a subterranean formation. The degradable diverter material may then be allowed to divert at least a portion of fluid present downhole, the fluid being introduced from the surface or already present downhole. The degradable diverter material can then be allowed to at least partially degrade via dissolution.

Methods for preparing and using invert emulsions and treatment fluids including the invert emulsions are provided herein. In one or more embodiments, the methods of the present disclosure comprise providing an aqueous fluid comprising water and one or more water-soluble monomers; providing an oil-based fluid comprising a solvent and one or more polymerization surfactants, wherein the solvent comprises a linear or branched dibasic ester; combining the aqueous fluid and the oil-based fluid to form an invert emulsion that comprises an aqueous phase comprising the aqueous fluid and an oil phase comprising the oil-based fluid; and polymerizing at least a portion of the one or more water-soluble monomers in the invert emulsion.

An aqueous formulation for slick water fracturing includes (i) a polymer (AA) which includes acrylamido repeat units and may be a polyacrylamide; (ii) water; and (iii) a quaternary ammonium compound.