A well stimulation method based on a self-dispersible and non-surface functionalized dispersion fluid to recover hydrocarbons from subterranean formation in conventional and non-conventional mode is described and claimed. The method includes introducing a self-dispersible, non-functionalized, three-dimensional (3D) crumpled graphene balls/structures into a water slug, a gas slug, a liquefied gas slug, a natural gas liquid slug, or a diesel slug. The resulting fluid containing self-dispersible, 3D crumpled structures is introduced into the subterranean hydrocarbon bearing formation. The said self-dispersion fluid may also contain a cocktail based on varying degree of hydrophilicity and hydrophobicity of 3D crumpled graphene balls, where the role of 3D hydrophilic crumpled graphene balls is to keep dispersion stable whereas, the role of hydrophobic 3D crumpled graphene balls is to interact with hydrocarbons and thus stimulating their dislodging or desorption from the rocks of subterranean hydrocarbon formation. The recovery fluid containing self-dispersible, non-functionalized stimulating agent is inserted into the underground formation containing hydrocarbons before, during or after the introduction of water, gas, liquefied gas, vaporized gas. This self-dispersible, and non-functionalized dispersion fluid provides a lower-cost, higher efficiency, environmentally friendly method for EOR and IOR.

A well stimulation method based on a self-dispersible and non-surface functionalized dispersion fluid to recover hydrocarbons from subterranean formation in conventional and non-conventional mode is described and claimed. The method includes introducing a self-dispersible, non-functionalized, three-dimensional (3D) crumpled graphene balls/structures into a water slug, a gas slug, a liquefied gas slug, a natural gas liquid slug, or a diesel slug. The resulting fluid containing self-dispersible, 3D crumpled structures is introduced into the subterranean hydrocarbon bearing formation. The said self-dispersion fluid may also contain a cocktail based on varying degree of hydrophilicity and hydrophobicity of 3D crumpled graphene balls, where the role of 3D hydrophilic crumpled graphene balls is to keep dispersion stable whereas, the role of hydrophobic 3D crumpled graphene balls is to interact with hydrocarbons and thus stimulating their dislodging or desorption from the rocks of subterranean hydrocarbon formation. The recovery fluid containing self-dispersible, non-functionalized stimulating agent is inserted into the underground formation containing hydrocarbons before, during or after the introduction of water, gas, liquefied gas, vaporized gas. This self-dispersible, and non-functionalized dispersion fluid provides a lower-cost, higher efficiency, environmentally friendly method for EOR and IOR.

A multicomponent nanocapsule composition comprising a core particle, an oil phase encapsulating the core particle, and an aqueous phase in which the encapsulated core particle is suspended is provided. The porous particle includes a cationic surfactant encapsulated in a porous particle. The oil phase includes an anionic surfactant and a zwitterionic surfactant. A method of making a multicomponent nanocapsule composition is also provided. A method of treating a hydrocarbon-bearing formation with the multicomponent nanocapsule composition is provided. The method may include providing a multicomponent nanocapsule composition, introducing the multicomponent nanocapsule composition into the hydrocarbon-bearing formation, displacing hydrocarbons from the hydrocarbon-bearing formation by contacting the multicomponent nanocapsule composition with the hydrocarbons, and recovering the hydrocarbons.

A multicomponent nanocapsule composition comprising a core particle, an oil phase encapsulating the core particle, and an aqueous phase in which the encapsulated core particle is suspended is provided. The porous particle includes a cationic surfactant encapsulated in a porous particle. The oil phase includes an anionic surfactant and a zwitterionic surfactant. A method of making a multicomponent nanocapsule composition is also provided. A method of treating a hydrocarbon-bearing formation with the multicomponent nanocapsule composition is provided. The method may include providing a multicomponent nanocapsule composition, introducing the multicomponent nanocapsule composition into the hydrocarbon-bearing formation, displacing hydrocarbons from the hydrocarbon-bearing formation by contacting the multicomponent nanocapsule composition with the hydrocarbons, and recovering the hydrocarbons.

Well treatment operation comprises introducing nanosized particulates into a formation. The nanosized particulates are synthesized by combining PMIDA, a calcium source, a pH adjusting agent, and an aqueous medium. This combination results in a degradable (i.e., dissolvable) solid that can be used in heterogeneous formations like shale type rock reservoirs, as well as sedimentary rock formations like clastic, siliclastic, sandstone, limestone, calcite, dolomite, and chalk formations, and formations where there is large fluid leak-off due to stimulation treatments. The disclosed particulates may also be used for acidizing treatments in mature fields and deep water formations commonly characterized by high permeability matrices. The solubility of the particulates advantageously allows the material to act as a temporary agent having a lifespan that is a function of temperature, water flux, and pH, making it adaptable to various reservoir conditions with minimal to no risk of adverse effects on the reservoir.

Well treatment fluids may include solid particles comprising one or more components selected from the group consisting of urea, ammonium nitrate, ammonium chloride, barium hydroxide, and ammonium thiocyanate. These well treatment fluids may also include a carrier fluid, which may be an aqueous polymeric fluid, an oil, or combinations thereof. The aqueous polymeric fluid may include a polymer selected from the group consisting of guar gum, hydroxypropyl guar, carboxymethyl hydroxypropyl guar, cellulose, or polyacrylamide. The oil may include a material selected from the group consisting of diesel, mineral oil, and wax. Methods for reducing an acid carbonate reaction in a carbonate formation may include pumping a composition of solid particles into a formation; releasing the solid particles from the capsules or emulsion within the formation; and injecting an acid following the releasing step or during pumping, wherein the acid carbonate reaction is carried out at a reduced reaction rate.

Well treatment fluids may include solid particles comprising one or more components selected from the group consisting of urea, ammonium nitrate, ammonium chloride, barium hydroxide, and ammonium thiocyanate. These well treatment fluids may also include a carrier fluid, which may be an aqueous polymeric fluid, an oil, or combinations thereof. The aqueous polymeric fluid may include a polymer selected from the group consisting of guar gum, hydroxypropyl guar, carboxymethyl hydroxypropyl guar, cellulose, or polyacrylamide. The oil may include a material selected from the group consisting of diesel, mineral oil, and wax. Methods for reducing an acid carbonate reaction in a carbonate formation may include pumping a composition of solid particles into a formation; releasing the solid particles from the capsules or emulsion within the formation; and injecting an acid following the releasing step or during pumping, wherein the acid carbonate reaction is carried out at a reduced reaction rate.

The flow of well treatment fluids may be diverted from a high permeability zone to a low permeability zone within a fracture network within a subterranean formation by use of a mixture comprising a dissolvable diverter and a proppant. At least a portion of the high permeability zone is propped open with the proppant of the mixture and at least a portion of the high permeability zone is blocked with the diverter. A fluid is then pumped into the subterranean formation and into a lower permeability zone of the formation farther from the wellbore. The diverter in the high permeability zones may then be dissolved at in-situ reservoir conditions and hydrocarbons produced from the high permeability propped zones of the fracture network. The mixture has particular applicability in the enhancement of production or hydrocarbons from high permeability zones in a fracture network located near the wellbore.

The flow of well treatment fluids may be diverted from a high permeability zone to a low permeability zone within a fracture network within a subterranean formation by use of a mixture comprising a dissolvable diverter and a proppant. At least a portion of the high permeability zone is propped open with the proppant of the mixture and at least a portion of the high permeability zone is blocked with the diverter. A fluid is then pumped into the subterranean formation and into a lower permeability zone of the formation farther from the wellbore. The diverter in the high permeability zones may then be dissolved at in-situ reservoir conditions and hydrocarbons produced from the high permeability propped zones of the fracture network. The mixture has particular applicability in the enhancement of production or hydrocarbons from high permeability zones in a fracture network located near the wellbore.

Systems and methods for controlling geysering in mining operations.