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.

Methods and treatments fluids for treating a wellbore. One example method introduces the treatment fluid into the wellbore. The treatment fluid comprises an aqueous fluid, an aminopolycarboxylic acid, a nanoparticle dispersed, and an organic solvent. The treatment fluid has a pH in a range between about 5 to about 9. The method further includes contacting a rock surface in the subterranean formation; wherein at least a portion of the rock surface is coated with a hydrocarbon. The treatment fluid removes a portion of the hydrocarbon from the rock surface and alters the rock surface to be water-wet.

The present disclosure relates to a composite fluid including an electrically insulating foundation fluid having a dielectric constant and a dielectric strength, and an additive combined with the foundation fluid that results in a composite fluid having a dielectric constant and a dielectric strength greater than the dielectric constant and the dielectric strength of the foundation fluid.

The present disclosure relates to biocide compositions, formulations and methods for using formulations. In particular the present disclosure relates to biocide compositions and their use in effecting biocidal activity in subterranean oil and gas wells being drilled, completed, worked over or produced.

The embodiments described herein generally relate to methods and chemical compositions for use with wellbore treatment processes. In one embodiment, a composition is provided comprising a cementitious material, a drilling fluid, or combinations thereof, and an additive composition comprising one or more components selected from the group of an aqueous insoluble lignin, a coke fine, a random tetracopolymer having the formula styrene-butadiene-acrylic-fumaric acid, a polyvinyl acetate, a surfactant composition, and combinations thereof.

A collection of compressible particles. The compressible particles are intended to be used for attenuating pressure build-up within a confined volume such as a trapped annulus in a wellbore. Each of the compressible particles is fabricated to collapse in response to fluid pressure within the confined volume, and comprises carbon. Particularly, each of the particles comprises a plurality of peripheral openings, permitting an ingress of wellbore fluids in response to an increase in pressure within a trapped annulus. The collection of compressible particles together has a reversible volumetric expansion/contraction of ≥10% and up to 25% at pressures up to 10,000 psi. A method of attenuating annular pressure buildup within a wellbore using the collection of compressible particles is also provided.

A method for reducing lost circulation in a subterranean formation. The method includes providing a treatment fluid comprising a base fluid and a lost circulation material comprising cane ash. The treatment fluid is introduced into a wellbore within the subterranean formation such that at least a portion of the cane ash bridges openings in the subterranean formation to reduce loss of fluid circulation into the subterranean formation.

A method for reducing lost circulation in a subterranean formation. The method includes providing a treatment fluid comprising a base fluid and a lost circulation material comprising brown mud. The treatment fluid is introduced into a wellbore within the subterranean formation such that at least a portion of the brown mud bridges openings in the subterranean formation to reduce loss of fluid circulation into the subterranean formation.

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.

Utilizing multiple rock cores samples obtained while drilling a well to determine the mechanical properties of the rock constituting the wellbore and formation zones within the wellbore. A geomechanical model is created from the samples by nanoindentation testing to provide the raw data from which the geomechanical model is then created.