Compositions and methods comprising certain microemulsions and certain clay control additives for enhancing clay swelling protection and persistency in treating swelling clay of a subterranean formation of oil and/or gas wells are generally provided. The combination of certain microemulsions and certain clay control additives exhibit synergistic effects by enhancing clay swelling protection and persistency in treating swelling clay. The well treatment composition may use up to four times less concentration of clay control additive compared to using the same clay control additive alone, while still providing the same, similar, or higher degree of clay swelling protection and enhanced persistency. The microemulsion and the clay control additive may be added to a carrier fluid to form the well treatment composition, which is injected into the subterranean formation to provide enhanced clay swelling protection and persistency of continuing to provide clay swelling protection for a longer period of time during flowback.

A process for forming a particle carrier system includes supplying a particle carrier, the particle carrier having a surface and modifying the particle carrier surface to include a first ionic functional group. The process also includes chemically binding the first ionic functional group on the particle carrier surface to a first ionic molecule.

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.

Provided are compositions and methods of using a liquid suspension of hollow particles comprising a plurality of hollow particles, water, a suspending aid, and a stabilizer selected from the group consisting of a non-ionic surfactant, a latex, an oleaginous fluid, porous silica, and combinations thereof. The liquid suspension is homogenous. An example method includes statically storing the liquid suspension in a container for at least one week; wherein the liquid suspension maintains a difference in density from the top of the container to the bottom of the container of less than one pound per gallon while stored. The method further includes adding the liquid suspension to a treatment fluid; wherein the liquid suspension reduces the density of the treatment fluid; and introducing the treatment fluid into a wellbore penetrating a subterranean formation.

A wellbore fluid including a first surfactant, a second surfactant, an activator and an aqueous base fluid is provided. The first surfactant has a structure represented by Formula (I):

##STR00001##

where Y.sub.1, Y.sub.2, Y.sub.3, Y.sub.4 are each, independently, a sulfonate, a carboxylate, an ester or a hydroxyl group, m is an integer ranging from 2 to 3, and n, o, and k are each, independently, integers ranging from 2 to 10. The second surfactant has a structure represented by Formula (III):

##STR00002##

where R.sub.2 is a C.sub.15-C.sub.27 hydrocarbon group or a C.sub.15-C.sub.29 substituted hydrocarbon group, R.sub.3 is a C.sub.1-C.sub.10 hydrocarbon group, and p and q are each, independently, an integer ranging from 1 to 4. A method of using the wellbore fluid for treating a hydrocarbon-containing formation is also provided.

Disclosed herein are compositions and methods for increasing recovery, or flowback, of hydrocarbon compounds from hydrocarbon-containing subterranean fractured rock formations (tight shale reservoirs). The flowback compositions include an anionic dimer surfactant, an anionic monomer surfactant, and a demulsifier. The flowback compositions convert oil-wet rocks to water-wet, yet exhibit a low tendency of composition components to sorb to the rock. The flowback compositions do not cause formation of emulsions with hydrocarbon compounds within the subterranean fractured rock formations. The flowback composition are useful for increasing the yield of hydrocarbons recovered from tight shale reservoirs.

Among the methods provided is a method comprising: providing a fracturing fluid that comprises a base fluid and an additive having a high dielectric constant; and introducing the fracturing fluid into least a portion of a subterranean formation.

A binary mixture system for lower oil viscosity and increased oil flow. The binary mixture composition may be useful for introduction into a functioning oil reservoir for cleaning and stimulation. The binary mixture composition is made of a first-chemical composition, a second-chemical composition, and a third-chemical composition. The first-chemical composition may be ammonium nitrate-water. The first-chemical composition may have a ratio of 1.0 to the second-chemical composition and the third-chemical composition. The first-chemical composition may be heated to a temperature of sixty degrees celsius. The second-chemical composition is made of the sodium nitrite-water. The second-chemical composition may have a ratio of 1.56 to the first-chemical composition and the third-chemical composition. The second-chemical composition may also be heated to a temperature of sixty degrees celsius. The third-chemical composition is made of phosphoric acid-water. The third-chemical composition may have a ratio of 0.2 to the first-chemical composition and the second-chemical composition.

A method of treating a bottom hole region of a formation (BRF) with an estimated frequency for performing the stages, wherein the second and each stage is carried out when the factor and/or the daily crude oil flow rate of a well has decreased by 25% or more over the preceding 6 months of well operation. In the first and second stages, the BRF is treated with an emulsion system containing silicon dioxide nanoparticles, an acid composition, and an aqueous solution of potassium or calcium chloride. In the third stages, the BRF is treated with an emulsion system containing silicon dioxide nanoparticles, a composition of surfactants and alcohols, and an aqueous solution of potassium chloride or calcium chloride. The thermal stability of the emulsion system, increase the rate of development of an oil and gas bearing layer, increase the duration of a positive effect and enhance oil production.

Disclosed herein is a nanoparticle modified fluid that includes nanoparticles that are surface modified to increase a viscosity of the nanoparticle modified fluid and that have at least one dimension that is less than or equal to about 50 nanometers; nanoparticles that are surface modified to increase a viscosity of the nanoparticle modified fluid and that have at least one dimension that is less than or equal to about 70 nanometers; and a liquid carrier; wherein the nanoparticle modified fluid exhibits a viscosity above that of a comparative nanoparticle modified fluid that contains the same nanoparticles but whose surfaces are not modified, when both nanoparticle modified fluids are tested at the same shear rate and temperature.