A system for transferring additive particles comprising: the additive particles; a storage container; and a surface modification agent, wherein at least some of the additive particles are treated with the surface modification agent, and wherein the surface modification agent reduces an amount of dust that is produced during transfer of the additive particles into the storage container, from the storage container, or into and from the storage container. A method of reducing an amount of dust produced during transfer of additive particles comprising: treating at least some of the additive particles with a surface modification agent; storing the additive particles; and transferring the additive particles prior to and after storage, wherein the surface modification agent reduces the amount of dust produced during at least one of the transfers of the additive particles.

Precipitated particles may be formed under conditions that provide a particle morphology suitable for conveying a desired set of properties to a wellbore circulation fluid. Methods for using precipitated particles in a wellbore may comprise: selecting precipitation conditions for producing precipitated particles that are substantially non-spherical in shape, are about 1 micron or under in size, or any combination thereof; forming the precipitated particles from a reaction mixture under the precipitation conditions without using a polymeric dispersant; and introducing a wellbore circulation fluid comprising a plurality of the precipitated particles into a wellbore penetrating a subterranean formation. The precipitation conditions may include one or more of modulating various reaction conditions, applying an electric field to the reaction mixture, or including a carbohydrate-based material in the reaction mixture.

Some embodiments of the present disclosure are directed to synthetic functionalized additives, which may comprise a layered magnesium silicate. The present disclosure is also directed to drilling fluids that may comprise an aqueous base fluid and a synthetic functionalized additive. The present disclosure is further directed to methods for producing drilling fluids.

A soluble abrasive cutting tool is configured to perform a cutting operation in a wellbore. The cutting operation comprising directing a pressurized stream of an abrasive fluid containing abrasive particles at a surface in the wellbore. For example, a stream of abrasive particles can be directed via a nozzle on the cutting tool at casing in the wellbore to perforate the casing. The abrasive particles are selected to dissolve in the wellbore fluid after the cutting operations have been completed. Once dissolved, the wellbore fluid can be removed from the area of the cutting operations without clogging tubing or pumps used to remove the wellbore fluid.

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.

Embodiments of treating fluid comprising hydrocarbons, water, and polymer being produced from a hydrocarbon-bearing formation are provided. One embodiment comprises adding a concentration of a viscosity reducer to the fluid to degrade the polymer present in the fluid and adding a concentration of a neutralizer to the fluid to neutralize the viscosity reducer in the fluid. The viscosity reducer is buffered at a pH of 7 or less (e.g., at a pH of from 2 to 7, such as at a pH of from 3.5 to 7, or at a pH of from 5 to 7). The addition of the concentration of the viscosity reducer is in a sufficient quantity to allow for complete chemical degradation of the polymer prior to the addition of the concentration of the neutralizer in the fluid such that excess viscosity reducer is present in the fluid. The addition of the concentration of the neutralizer is sufficiently upstream of any surface fluid processing equipment to allow for complete neutralization of the excess viscosity reducer such that excess neutralizer is present in the fluid prior to the fluid reaching any of the surface fluid processing equipment.

Excessive water production from oil reservoirs is a main challenge facing the oil and gas industry nowadays. Polymeric gelants have been widely applied to seal the water production zones leading to a more feasible production operation. This disclosure introduces a new inorganic crosslinker that can potentially replace the conventional chromium acetate as crosslinkers for polyacrylamide in low-temperature reservoirs. The developed formulation has the advantage of being more environment-friendly compared to the known-to-be toxic chromium acetate. The formulation has been tested through the whole pH range examining the rheological behavior of the mature gels in the temperature range between 25 to 100° C. While chromium acetate was proven to be sensitive to the presence of sour gases, namely CO.sub.2 and H.sub.2S, due to the inability to produce a stable gel at the acidic conditions, the proposed crosslinkers are more tolerable towards the high acidity. Unlike the conventional crosslinkers, the gelation rate in the proposed system was found to decrease with the increase in pH. The system has a controllable gelation time at pH conditions between 3.5 and 8.5 and is the most stable in the temperature range between 25 to 100° C.

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.

A lubricant including a fluid medium and at least one intercalation compound of a metal chalcogenide having molecular formula MX.sub.2, where M is a metallic element such as tungsten (W), and X is a chalcogen element such as sulfur (S), wherein the intercalation compound has a fullerene-like hollow structure or tubular-like structure.

Drilling fluid compositions and methods for using drilling fluid compositions are provided with enhanced anti-bit balling properties that includes an aqueous base fluid, one or more drilling fluid additives, and an anti-bit balling additive where the anti-bit balling additive comprises a C.sub.15-C.sub.18 alkene or a mixture of two or more C.sub.15-C.sub.18 alkenes. Methods for using the drilling fluid compositions may further include mixing the mixing an aqueous base fluid with one or more drilling fluid additives and an anti-bit balling additive, wherein the anti-bit balling additive includes a C.sub.15-C.sub.18 alkene or a mixture of two or more C.sub.15-C.sub.18 alkenes, and introducing the drilling fluid to a subterranean formation.