A treatment fluid comprises: a liquid fluorinated compound; and at least one additive, wherein the additive: (A) comprises carbon and at least one fluorine functional group; and (B) is soluble or dispersible in the liquid fluorinated compound. A method of treating a portion of a well comprises: forming the treatment fluid; and introducing the treatment fluid into the well.

Producing proppants with nanoparticle proppant coatings includes reacting nanoparticles with at least one of an alkoxysilane solution or a halosilane solution to form functionalized nanoparticles and coating proppant particles with unfunctionalized organic resin, a strengthening agent, and the functionalized nanoparticles to produce the nanoparticle coated proppant. The functionalized nanoparticles include nanoparticles having at least one attached omniphobic moiety including at least a fluoroalkyl-containing group including 1H, 1H, 2H, 2H-perfluorooctylsilane. The strengthening agent comprises at least one of carbon nanotubes, silica, alumina, mica, nanoclay, graphene, boron nitride nanotubes, vanadium pentoxide, zinc oxide, calcium carbonate, or zirconium oxide. Additionally, increasing a rate of hydrocarbon production from a subsurface formation through the use of the nanoparticle coated proppant includes producing a first rate of production of hydrocarbons from the subsurface formation, introducing a hydraulic fracturing fluid into the subsurface formation, and increasing hydrocarbon production by producing a second rate of production of hydrocarbons.

The present invention relates to the well drilling field in petroleum industry, in particular to an additive composition suitable for viscosity reduction of oil-based drilling fluids, an oil-based drilling fluid and use thereof. The double-block copolymer mainly consists of a block A and a block B, wherein, the block A is composed of structural units represented by formula (1), the block B is composed of structural units represented by formula (2), and the number-average molecular weight of the block A is 1,500-10,000. The double-block copolymer provided in the present invention can be used as a viscosity reducer in oil-based drilling fluids, especially can be used as a viscosity reducer in high-density clay-free oil-based drilling fluids, and can greatly decrease the apparent viscosity and plastic viscosity of oil-based drilling fluids in high-temperature and high-pressure reservoir while maintaining appropriate shearing force, so as to increase the drilling rate and reduce drilling difficulties. ##STR00001##

A method for performing a coiled-tubing process, the method having the steps: performing a coiled-tubing process using a fluid-lubricant composition that includes a sulfur-containing compound, and introducing the fluid-lubricant composition into a subterranean wellbore casing.

A drilling mud composition including Aloe vera particles with a largest dimension of 75-600 μm, an aqueous base fluid, and a viscosifier, where the Aloe vera particles are present in the drilling mud composition at a concentration of less than 150 ppm, relative to the total weight of the drilling mud composition. A process for fracking a geological formation, whereby the drilling mud composition is injected into the geological formation through a well bore at a pressure of at least 5,000 psi to fracture the geological formation.

A method and composition for reducing a coefficient of friction are disclosed. In an embodiment, a method for reducing a coefficient of friction between two surfaces in a borehole includes preparing a mixture comprising a primary lubricating agent, a primary surfactant, a spreading agent, and an aqueous fluid. The method also includes pumping the mixture into the borehole such that the mixture contacts the two surfaces and reduces the coefficient of friction for the two surfaces.

Drilling fluid compositions and methods for using drilling fluid compositions are provided with enhanced anti-bit balling properties that include an aqueous-based fluid, one or more drilling fluid additives, and an anti-bit balling additive. The anti-bit balling additive may be an epoxidized α-olefin and the drilling fluid may include the anti-bit balling additive in an amount ranging from about 0.5 ppb to about 20 ppb. Methods for using the drilling fluid compositions may further include 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 epoxidized α-olefin and the drilling fluid may include the anti-bit balling additive in an amount ranging from about 0.5 ppb to about 20 ppb, and introducing the drilling fluid to a subterranean formation.

Terpene-based spotting fluid compositions and processes for freeing differentially stuck pipe are provided. A spotting fluid composition includes a terpene and an acid, such that the acid initiates an exothermic polymerization reaction of the terpene. Another spotting fluid composition includes an invert emulsion having a terpene external phase and a non-miscible organic hygroscopic fluid internal phase. The terpene emulsion spotting fluid composition may be introduced downhole in the vicinity of a portion of a differentially stuck pipe such that the spotting fluid composition contacts a filter cake surrounding the portion of the differentially stuck pipe. An acid may be introduced downhole in the vicinity of a portion of a differentially stuck pipe such that the acid initiates an exothermic polymerization reaction of the terpene of the terpene emulsion spotting fluid composition.

Treatment fluids including a base fluid; and fly ash microspheres, wherein the fly ash microspheres are of a material selected from the group consisting of Class C fly ash, Class F fly ash, and any combination thereof, wherein the fly ash microspheres have a diameter in the range of from about 0.1 μηη to about 150 μηη, and wherein the fly ash microspheres are present in the treatment fluid in an amount in the range of from about 0.001 ppg to about 1 ppg of the treatment fluid.

Biodegradable additive concentrate with pour point according to standard ASTM D 97 below −5° C., improving the lubricity of water-based muds, comprising at least one compound selected from the group consisting of: the diglycerol mono- and diesters, the acids and the ester derivatives of monocarboxylic fatty acids comprising from 16 to 22 carbon atoms per chain, the acids and the ester derivatives of resin acids, the monoesters of polyol comprising more than 4 hydroxylated groups and of carboxylic fatty acids comprising from 6 to 12 carbon atoms, saturated and unsaturated by at least one unsaturation, and the mono- and polyalkoxylated esters of saturated and unsaturated dicarboxylic acids comprising from 6 to 12 carbon atoms. The use of this concentrate in a water-based mud and the water-based mud containing said concentrate that can be used for drilling.