The disclosure relates to a method of delaying viscosification of a well treatment fluid within a well or within a subterranean formation penetrated by a well by introducing into the well a hydratable viscosifying agent of particulates having a minimum of 40% retention on a 60 mesh screen and a minimum of 1% retention on a 20 mesh screen.

A composite particle that incorporates a material and is designed to undergo a reaction and/or mechanical or chemical change with the environment to increase in volume. The composite particle can be combined with a constraining matrix to create an expandable particle upon reaction. These particles can be used in stimulating wells, including oil and gas reservoirs.

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.

The present disclosure is directed to surfactants (in particular olefin sulfonates), surfactant packages, compositions derived thereof, and uses thereof in hydrocarbon recovery. Methods of making olefin sulfonate surfactants are also described.

Release of hydrochloric acid, hydrofluoric acid and fluoroboric acid into a well may be controlled by introducing into the well an aqueous fluid containing ammonium chloride, ammonium bifluoride, ammonium fluoroborate, ammonium tetrafluoroborate or a mixture thereof and a breaker. After being introduced into the well, the ammonium salt reacts with the breaker and the acid is released into the well.

Various embodiments disclosed relate to demulsifier compositions for treatment of subterranean formations or produced petroleum comprising an emulsion. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a demulsifier composition. The demulsifier composition includes an alkanolamide surfactant that is a (C.sub.1-C.sub.50)hydrocarbyl amide having groups R.sup.1 and R.sup.2 substituted on the amide nitrogen, wherein R.sup.1 and R.sup.2 are each independently selected from the group consisting of —H, —(C.sub.1-C.sub.50)hydrocarbyl, and —(C.sub.1-C.sub.50)hydrocarbylene-OH, wherein at least one of R.sup.1 and R.sup.2 is —(C.sub.1-C.sub.50)hydrocarbylene-OH. The demulsifier composition includes an alkoxylated alcohol surfactant that is a (C.sub.1-C.sub.50)hydrocarbyl-OH having a —((C.sub.2-C.sub.3)alkylene-O).sub.n—H group on the —OH group, wherein n is about 1 to about 100. The demulsifier composition also includes an amine-oxide surfactant. At each occurrence the (C.sub.1-C.sub.50)hydrocarbyl and (C.sub.1-C.sub.50)hydrocarbylene are substituted or unsubstituted and are independently selected.

Various embodiments disclosed relate to demulsifier compositions for treatment of subterranean formations or produced petroleum comprising an emulsion. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a demulsifier composition. The demulsifier composition includes an alkanolamide surfactant that is a (C.sub.1-C.sub.50)hydrocarbyl amide having groups R.sup.1 and R.sup.2 substituted on the amide nitrogen, wherein R.sup.1 and R.sup.2 are each independently selected from the group consisting of —H, —(C.sub.1-C.sub.50)hydrocarbyl, and —(C.sub.1-C.sub.50)hydrocarbylene-OH, wherein at least one of R.sup.1 and R.sup.2 is —(C.sub.1-C.sub.50)hydrocarbylene-OH. The demulsifier composition includes an alkoxylated alcohol surfactant that is a (C.sub.1-C.sub.50)hydrocarbyl-OH having a —((C.sub.2-C.sub.3)alkylene-O).sub.n—H group on the —OH group, wherein n is about 1 to about 100. The demulsifier composition also includes an amine-oxide surfactant. At each occurrence the (C.sub.1-C.sub.50)hydrocarbyl and (C.sub.1-C.sub.50)hydrocarbylene are substituted or unsubstituted and are independently selected.

Proppant particles formed from slurry droplets and methods of use are disclosed herein. The proppant particles can include a sintered ceramic material and can have a size of about 80 mesh to about 10 mesh and an average largest pore size of less than about 20 microns. The methods of use can include injecting a hydraulic fluid into a subterranean formation at a rate and pressure sufficient to open a fracture therein and injecting a fluid containing a proppant particle into the fracture, the proppant particle including a sintered ceramic material, a size of about 80 mesh to about 10 mesh, and an average largest pore size of less than about 20 microns.

Proppant particles formed from slurry droplets and methods of use are disclosed herein. The proppant particles can include a sintered ceramic material and can have a size of about 80 mesh to about 10 mesh and an average largest pore size of less than about 20 microns. The methods of use can include injecting a hydraulic fluid into a subterranean formation at a rate and pressure sufficient to open a fracture therein and injecting a fluid containing a proppant particle into the fracture, the proppant particle including a sintered ceramic material, a size of about 80 mesh to about 10 mesh, and an average largest pore size of less than about 20 microns.