Chemical additives useful for hydraulic fracturing operation are comprising of lubricant/nonpolar solvents; hydro-dual-phobic domains as core encapsulated by emulsifiers as shell, suspended in water by hydrogel polymers as hydrophilic domains; soy protein isolate (SPI) and sweet rice flour were modified with crosslinking polymers of isocyanate as hydrophobic domains, which is incorporated into the frac fluid as a standard alone friction reducer solution or as an enhancer of frac fluid viscosity of the final frac fluid products in high salinity brines having a concentration as high as 25.0% at an ambient temperature at a downhole well temperature from 30 to 180° F.

A composition for fracturing a wellbore may include a reacting fluid. The reacting fluid includes an encapsulated breaker, sodium nitrite, and an ammonium-comprising compound. The sodium nitrite and the ammonium-comprising compound undergo an exothermic reaction producing heat operable to release the encapsulated breaker, releasing the breaker that then reduces viscosity in the polymer-comprising fluid. A method for fracturing a wellbore may include injecting into a fractured wellbore a fluid comprising an ammonium-comprising compound and a fluid comprising sodium nitrite. The fractured wellbore has been fractured with a fracturing fluid comprising an encapsulated breaker. Sodium nitrite and the ammonium-comprising compound undergo an exothermic chemical reaction that generates heat to release the encapsulated breaker.

A method for minimizing the creation and existence of frac hits in an oil field comprising the step of pumping treatment fluids into the Parent well before performing the frac on the Child well wherein the treatment fluids contain brine resistant silica nanoparticles is described and claimed.

A method for treating kerogen in a subterranean zone which includes the use of supercritical carbon dioxide or emulsions of liquid carbon dioxide and an aqueous fluid. The carbon dioxide or emulsions can further include oxidizers. The oxidizers can include inorganic oxidizers or organic oxidizers, for example an oxidizer including an organic cation and an oxidizing anion. Additional additives such as polymers, crosslinkers, clay inhibitors, scale inhibitors and corrosion inhibitors can further enhance the efficiency of the kerogen-treating carbon dioxide or emulsion.

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.

Provided herein are compositions and methods for degrading polymer systems. These compositions and methods can be used to effectively degrade a range of polymers commonly used in oil and gas operations, including polymers with carbon-carbon backbones such as polyacrylamides. Further, these compositions and methods can simultaneously degrade other organic molecules and pollutants associated with oil and gas operations. The compositions and methods described herein employ reactants that are more environmentally-friendly than conventional methods and components used in, for example, polymer breaking processes.

A method and apparatus for acidizing and perforating simultaneously.

A degradation agent for viscous fluids to be used in hydraulic fracturing methods is provided according to one aspect of the present invention, the degradation agent comprising a persulfate and an iron salt serving as an activator for the persulfate, wherein the persulfate and the iron salt have been coated and the ratio of the coating-film thickness (Y) in the iron salt to the coating-film thickness (X) in the persulfate, Y/X, is in the range of 0.35 to 1.0. The degradation agent for viscous fluids has properties suitable for use in hydraulic fracturing methods.

Disclosed herein are breaking additives and methods for use with synthetic polymer-type fracturing fluids. Compared with polysaccharide-type gelling agents, such as guar and guar derivatives, synthetic-polymers such as polyacrylamide-type gelling agents are more difficult to break using common oxidizing breakers because their backbones are composed of strong carbon-carbon bonds.

Provided herein are methods and compositions for delayed in-situ generation of acids.