The present disclosure relates to a well treatment fluid comprising finger millet, a breaker package, and a continuous aqueous phase. The present disclosure also relates to a method for treating at least a portion of a subterranean well comprising forming an aqueous treatment fluid comprising (i) finger millet, (ii) a breaker package comprising at least one breaker, and (iii) a continuous aqueous phase; and introducing the treatment fluid into at least a portion of the subterranean well.

Various embodiments disclosed relate to compositions including a glycerol ester including at least two epoxides for treatment of subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in a subterranean formation a composition including a glycerol ester that includes at least two epoxides. The composition also includes a hardening agent.

The methods disclosed herein allow for the recovery of at least 55% of residual heavy oil from porous structures. In the disclosed methods, porous structures are contacted with emulsions having an aqueous continuous phase and an organic dispersed phase. The organic dispersed phase includes organic compounds having five or fewer carbon atoms (such as natural gas), which are typically difficult to emulsify because they are unstable at ambient conditions. To solve that problem, the emulsions disclosed herein are stabilized by nanoparticles having hydrophilic exterior surfaces. The nanoparticles make up at least 0.1% of the emulsion by weight. The use of hydrophilic nanoparticles as stabilizers combines the utility of natural gas liquids in enhanced oil recovery (due to their high solubility in residual oil and attendant viscosity reduction) with the utility of emulsions (delivery of viscosity-reducing agents along with an immiscible phase to push out the trapped oil).

The methods disclosed herein allow for the recovery of at least 55% of residual heavy oil from porous structures. In the disclosed methods, porous structures are contacted with emulsions having an aqueous continuous phase and an organic dispersed phase. The organic dispersed phase includes organic compounds having five or fewer carbon atoms (such as natural gas), which are typically difficult to emulsify because they are unstable at ambient conditions. To solve that problem, the emulsions disclosed herein are stabilized by nanoparticles having hydrophilic exterior surfaces. The nanoparticles make up at least 0.1% of the emulsion by weight. The use of hydrophilic nanoparticles as stabilizers combines the utility of natural gas liquids in enhanced oil recovery (due to their high solubility in residual oil and attendant viscosity reduction) with the utility of emulsions (delivery of viscosity-reducing agents along with an immiscible phase to push out the trapped oil).

Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include nitrogen generating compounds, which upon activation, react to generate heat and nitrogen gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, heat and nitrogen gas are generated. Upon the generation of nitrogen gas and heat within the formation, microfractures are produced within the formation and the hydrostatic pressure within the reservoir is reduced to less than the reservoir fluid pressure, such that the rate of production of hydrocarbons from the formation is increased.

Provided is a method and composition for the in-situ generation of synthetic sweet spots in tight-gas formations. The composition can include nitrogen generating compounds, which upon activation, react to generate heat and nitrogen gas. The method of using the composition includes injecting the composition into a tight-gas formation such that upon activation, heat and nitrogen gas are generated. Upon the generation of nitrogen gas and heat within the formation, microfractures are produced within the formation and the hydrostatic pressure within the reservoir is reduced to less than the reservoir fluid pressure, such that the rate of production of hydrocarbons from the formation is increased.

A method for forming rod-shaped particles includes reducing a length of rods derived from a slurry made up of particles and a reactant, wherein the rods are in a stabilized state in which the reactant has been at least partially reacted with a coagulant, but the rods have not been sintered, and subsequently sintering the reduced length stabilized rods. The reducing the length of the stabilized rods includes subjecting the stabilized rods to mechanical vibration applied by a device, or feeding the stabilized rods through a device having a rotating cutting mechanism.

A method for forming rod-shaped particles includes reducing a length of rods derived from a slurry made up of particles and a reactant, wherein the rods are in a stabilized state in which the reactant has been at least partially reacted with a coagulant, but the rods have not been sintered, and subsequently sintering the reduced length stabilized rods. The reducing the length of the stabilized rods includes subjecting the stabilized rods to mechanical vibration applied by a device, or feeding the stabilized rods through a device having a rotating cutting mechanism.

A drilling mud composition including Aloe vera particles with a largest dimension of 75-600 μm, an aqueous base fluid, and a viscosifier, where the Aloe vera particles are present in the drilling mud composition at a concentration of less than 150 ppm, relative to the total weight of the drilling mud composition. A process for fracking a geological formation, whereby the drilling mud composition is injected into the geological formation through a well bore at a pressure of at least 5,000 psi to fracture the geological formation.

Methods of treating a subterranean formation are disclosed that include introducing a treatment fluid including thermally shrinkable fibers and a particulate material into a subterranean formation via a wellbore, adjusting at least one parameter of the treatment fluid to trigger the association of the thermally shrinkable fibers, and forming a porous pack including a network of shrunken fibers by applying heat sufficient to raise the temperature of the thermally shrinkable fibers to a temperature at or above a shrinking initiation temperature of the thermally shrinkable fibers.