A completion/stimulation/production fluid and injection mixture blend is disclosed. The blend may include an aqueous fluid, a polymer system and an injection mixture that includes a polyol, a natural sugar, an artificial sugar, or a combination thereof.

A slickwater fracturing fluid that includes a brine with dissolved solids, an anionic friction reducing additive, a polysaccharide, and a nanomaterial that includes nanoparticles with an average particle size between about 1 nm and about 500 nm. The polysaccharide and the anionic friction reducing additive synergistically reduce friction of the slickwater fracturing fluid so as to increase an injection rate of the slickwater fracturing fluid. Also, the polysaccharide, the anionic friction reducing additive, and the nanomaterial synergistically provide viscosity to the slickwater fracturing fluid so as to increase proppant transport capability. Also described is a method of fracturing a subterranean formation by pumping the slickwater fracturing fluid into a borehole and fracturing the subterranean formation with the slickwater fracturing fluid.

A drag reducing composition, methods of forming a drag reducing composition, and methods of using a drag reducing composition to reduce the pressure drop of a liquid hydrocarbon through a conduit are provided. The drag reducing composition includes a latex polymer, a cationic surfactant, optionally a nonionic surfactant, and a continuous phase. The cationic surfactant is selected from quaternary ammonium-based cationic surfactants, imidazolium-based cationic surfactants, pyridinium-based cationic surfactants, or a combination thereof.

A composition of an invert emulsion oil-based drilling fluid is provided. The composition may include an oil phase and an aqueous phase. The oil phase may include an oleaginous fluid, an organophilic clay-based solid viscosifier, and a liquid viscosifier including a POSS. Further provided is a method of introducing the composition including the POSS into a wellbore. After introduction of the composition into the wellbore, the method includes maintaining wellbore conditions to provide a stable rheological property for a period up to about 96 hours in an HPHT section of a wellbore.

The present invention relates to a method of inhibiting or control wax formation during stimulation treatment of a well. More specifically, the present invention proposes the use of aqueous polymer dispersions suitable as wax inhibitor compositions which are compatible with aqueous fracturing fluids.

The present application concerns a water-in-oil inverse emulsion comprising: oil; water; at least one water-soluble anionic polymer of average molecular weight higher than 3 million daltons, containing between 4 and 14 mol % of sulfonated anionic monomers, between 0 and 17 mol % of carboxylated anionic monomers and between 69 and 94 mol of nonionic monomers; at least one inverting agent and at least one emulsifying agent, the weight ratio R between the total amount of inverting agent and the total amount of emulsifying agent being higher than 1.8; the inverting agent being selected from among an ethoxylated nonylphenol preferably having between 4 and 10 ethoxylations; an ethoxylated/propoxylated alcohol preferably having ethoxylations/propoxylations to obtain a total number of carbons of between C12 and C25, an ethoxylated tridecylic alcohol and an ethoxylated/propoxylated fatty alcohol; the emulsifying agent being selected from among sorbitan monooleate, polyethoxylated sorbitan esters or the diethanolamide of tall oil fatty acids, polyethoxylated fatty acids, and use thereof for hydraulic fracturing.

Compositions and methods for fracturing a subterranean formation are presented. Also provided are compositions and methods for reducing friction-related losses in a well treatment fluid. In general, the compositions include a copolymer that includes one or more vinylphosphonic acid (“VPA”) monomers.

A method may include: introducing a treatment fluid into a stream, the treatment fluid comprising: a base fluid and a supramolecular host guest product, wherein the supramolecular host guest product comprises a treatment fluid additive and a supramolecular host molecule, wherein the supramolecular host molecule is not covalently bonded to the treatment fluid additive.

The present invention provides a multi-functional hybrid fracturing fluid system, comprising slick water and high viscosity sand carrying fluid, wherein the slick water contains 0.02%˜0.15% of friction-reducing agent by mass percentage, the high viscosity sand carrying fluid contains 0.2%˜0.75% of thickener by mass percentage; the friction-reducing agent and the thickener are the same associative polymer which is a modified natural associative polymer and/or an organic synthetic associative polymer.

Emulsions, treatment fluids and methods for treating subterranean formations are provided, wherein the emulsions comprise water, a water-immiscible liquid, one or more polymers, one or more ethoxylated amine compounds and optionally, one or more organic or inorganic salts. The emulsions are particularly suitable for use in harsh brine conditions.