A non-aqueous slurry contains a non-aqueous liquid immiscible in water (such as a hydrocarbon based oil) having dispersed therein a crosslinking agent (such as a borate crosslinking agent) and an oil-wetting surface active material. The non-aqueous slurry further contains an organophilic clay. The non-aqueous slurry, when used in an aqueous fracturing fluid, provides crosslinking delay between the crosslinking agent and a hydratable polymer, such as guar or guar derivatives. The aqueous fracturing fluid provides an enhanced fracture network after being pumped into a well.

A non-aqueous slurry contains a non-aqueous liquid immiscible in water (such as a hydrocarbon based oil) having dispersed therein a crosslinking agent (such as a borate crosslinking agent) and an oil-wetting surface active material. The non-aqueous slurry further contains an organophilic clay. The non-aqueous slurry, when used in an aqueous fracturing fluid, provides crosslinking delay between the crosslinking agent and a hydratable polymer, such as guar or guar derivatives. The aqueous fracturing fluid provides an enhanced fracture network after being pumped into a well.

Methods and systems for performing injection treatments in subterranean formations stimulated by the ignition of propellants are provided. In some embodiments, the methods comprise: igniting a propellant in one or more secondary boreholes in a subterranean formation to at least partially rupture at least a region of the subterranean formation near the secondary boreholes; introducing a fracturing fluid into a first production well bore in the subterranean formation in or near the ruptured region of the subterranean formation at or above a pressure sufficient to create or enhance at least a primary fracture in the subterranean formation that extends into at least a portion of the ruptured region of the subterranean formation; and introducing a displacement fluid into one or more of the secondary boreholes or an injection well bore in the subterranean formation that comprises one or more fractures penetrating the ruptured region of the subterranean formation.

A method for using a surfactant formulation in chemical enhanced oil recovery, wherein said surfactant formulation comprises at least: (i) an anionic salt of an alkyl alkoxylated sulfate, wherein said alkyl alkoxylated sulfate has a molecular structure as shown in (I), wherein R is a linear, branched or mixture of linear and branched alkyl group having from 10 to 20 carbon atoms, n=4 −15, m=0-10, M+ is an alkali metal ion, an alkanolamine ion, an alkyl amine ion or an ammonium ion; and (ii) a non-ionic alcohol O ethoxylate, wherein said alcohol ethoxylate has a molecular structure as shown in (II), wherein R.sub.1 is a linear, branched or mixture of linear and branched alkyl group having from 8 to 24 carbon atoms, y=20-100. ##STR00001##

A method for using a surfactant formulation in chemical enhanced oil recovery, wherein said surfactant formulation comprises at least: (i) an anionic salt of an alkyl alkoxylated sulfate, wherein said alkyl alkoxylated sulfate has a molecular structure as shown in (I), wherein R is a linear, branched or mixture of linear and branched alkyl group having from 10 to 20 carbon atoms, n=4 −15, m=0-10, M+ is an alkali metal ion, an alkanolamine ion, an alkyl amine ion or an ammonium ion; and (ii) a non-ionic alcohol O ethoxylate, wherein said alcohol ethoxylate has a molecular structure as shown in (II), wherein R.sub.1 is a linear, branched or mixture of linear and branched alkyl group having from 8 to 24 carbon atoms, y=20-100. ##STR00001##

A method of pretreating a pipeline or apparatus is carried out by selecting a colloidal particle dispersion having inorganic nanoparticles with an average particle size of from 500 nm or less that exhibit properties of Brownian motion. Surfaces of a pipeline or apparatus are contacted with a treatment composition comprising the colloidal particle dispersion. The colloidal particles of the treatment composition are allowed to adhere the surfaces of the pipeline or apparatus to facilitate a reduction in friction of the surfaces of the pipeline or apparatus and/or lower the pressure drop of fluid flowing over the surfaces of the pipeline or apparatus and/or to reduce the formation of surface deposits on the surfaces of the pipeline or apparatus.

A method of pretreating a pipeline or apparatus is carried out by selecting a colloidal particle dispersion having inorganic nanoparticles with an average particle size of from 500 nm or less that exhibit properties of Brownian motion. Surfaces of a pipeline or apparatus are contacted with a treatment composition comprising the colloidal particle dispersion. The colloidal particles of the treatment composition are allowed to adhere the surfaces of the pipeline or apparatus to facilitate a reduction in friction of the surfaces of the pipeline or apparatus and/or lower the pressure drop of fluid flowing over the surfaces of the pipeline or apparatus and/or to reduce the formation of surface deposits on the surfaces of the pipeline or apparatus.

Surfactants for use in formulations and processes suitable for hydrocarbon recovery. These formulations, include formulations suitable for fracking, enhancing oil and or gas recovery, and the recovery and or production of bio-based oils.

Surfactants for use in formulations and processes suitable for hydrocarbon recovery. These formulations, include formulations suitable for fracking, enhancing oil and or gas recovery, and the recovery and or production of bio-based oils.

This present invention relates to compositions and methods of enhancing the dispersion of nanoparticles. In certain embodiments, the compositions and methods can be used for enhancing the performance and/or longevity of primers using biochemical-producing microbes and/or byproducts synthesized by the microbes. In certain embodiments, the addition of biosurfactants can enhance the dispersion of pigments and/or other nanoparticles, as well as inhibition of stain or color bleeding through the primer.