A dispersion of capsules in critical or supercritical carbon dioxide is provided. The capsules include an aqueous solution encapsulated by covalent organic framework particles. Also provided is a method of making a dispersion of aqueous solution capsules. The method includes providing a medium of critical or supercritical carbon dioxide, introducing the aqueous solution into the critical or supercritical carbon dioxide medium, and introducing a covalent organic framework particle into the critical or supercritical carbon dioxide medium. Associated methods of using the disclosed dispersions in hydrocarbon-bearing formations are also provided.

A dispersion of capsules in critical or supercritical carbon dioxide is provided. The capsules include an aqueous solution encapsulated by magnetic covalent organic framework particles. Also provided is a method of making a dispersion of aqueous solution capsules. The method includes providing a medium of critical or supercritical carbon dioxide, introducing the aqueous solution into the critical or supercritical carbon dioxide medium, and introducing a magnetic covalent organic framework particle into the critical or supercritical carbon dioxide medium. Associated methods of using the disclosed dispersions in hydrocarbon-bearing formations are also provided.

Methods of stimulating a well comprising providing a stimulation fluid comprising at least one surfactant and submicron particles, the submicron particles having a particle size between about 200 nm and about 800 nm and a specific surface area greater than about 5 square meters per gram; and introducing the stimulation fluid into a wellbore. Additional methods to enhance oil recovery from subterranean reservoirs accessible via a well are described.

Various embodiments disclosed relate to compositions including mycelium and methods of treatment of subterranean formations with the same. In various embodiments, the present invention provides a method of treating a subterranean formation including placing in the subterranean formation a composition including a mycelium.

A nanosilica containing fluid system for shale stabilization in a shale formation. The nanosilica containing fluid system comprising a functionalized nanosilica composition operable to react with shale at the surface of the shale formation to form a barrier on the shale formation. The functionalized nanosilica composition comprising a nanosilica particle, the nanosilica particle having a mean diameter, and a functionalization compound, the functionalization compound appended to the surface of the nanosilica particle. And an aqueous-based fluid, the aqueous-based fluid operable to carry the functionalized nanosilica composition into the shale formation. The functionalization compound is an amino silane. The aqueous-based fluid is selected from the group consisting of water, deionized water, sea water, brine, and combinations thereof.

Nano-sized clay minerals enhance the viscosity of aqueous fluids that have increased viscosity due to the presence of viscoelastic surfactants (VESs). In one non-limiting theory, the nano-sized phyllosilicate mineral viscosity enhancers associate, link, connect, or relate the VES elongated micelles into associations thereby increasing the viscosity of the fluid, possibly by mechanisms involving chemisorption or surface charge attractions. The nano-sized phyllosilicate mineral particles, also called clay mineral nanoparticles, may have irregular surface charges. The higher fluid viscosity is beneficial to crack the formation rock during a fracturing operation, to reduce fluid leakoff, and to carry high loading proppants to maintain the high conductivity of fractures.

Colloid and/or micelle nano-sizing compositions including a nano-sizing solvent system comprising one or more sesquiterpene solvents, and a nano-sizing activator system comprising one or more dibasic esters, surfactant systems containing colloid and/or micelle nano-sizing compositions, treating/fracturing/completion fluids containing the colloid and/or micelle nano-sizing compositions and methods for making and using same.

A method of treating a subterranean shale formation includes placing a first treatment fluid comprising a fracturing fluid in the formation; forming fractures; placing a second fluid including a sloughing agent or eroding agent in the formation; allowing gaps in the fracture faces to form; placing a third fluid including a formation stabilizer and an agglomerating agent into the fractures; and allowing the third fluid to absorb into the formation, thereby stabilizing the shale formation fracture faces and transforming the solid shale particulates into proppant clusters.

Method for increasing lubricity of a wellbore fluid comprising the following steps: i) preparing a water in oil microemulsion that contains insoluble particles of metal hydroxides and/or metal oxides in the inner aqueous phase, the insoluble particles being synthesized from their salt precursors in the water droplets of the microemulsion; ii) adding to the wellbore fluid the water in oil microemulsion; iii) injecting the wellbore fluid into a subterranean formation and iv) performing the drilling, completion or coiled tubing operations in the subterranean formation.

The present invention relates to a method for increasing oil recovery from an oil-bearing formation including the following successive stages of treating the formation: injecting an invert emulsion in a volume of 3-5 m.sup.3/m of perforated interval thickness followed by squeezing down an acidic composition or a composition containing a nonionic surfactant in a volume of 2-3 m.sup.3/m of perforated interval thickness to the formation, injecting a highly stable direct emulsion containing a colloidal solution of silicon dioxide nanoparticles in a volume of 3-7 m.sup.3/m of perforated interval thickness followed by squeezing down a liquid from a reservoir pressure maintenance system to the formation.