This invention relates to the field of techniques for treating subterranean formations with gels during an oil or gas exploration or production operation, i.e., during drilling, completion, or hydraulic fracking processes. The invention relates in particular to a system making it possible to limit or even inhibit the phenomena known as loss of fluids (wager and/or gas) in an underground formation, particularly in a zone where the temperature is high.

More particularly, the invention relates to a suspension (S) comprising: an aqueous phase containing salts; and within said aqueous phase, particles (p) based on associative polymers (P).

A method may include: introducing a treatment fluid into a production fluid disposed in a surface well system, the treatment fluid comprising: a base fluid; and a supramolecular host guest product comprising: a treatment fluid additive comprising a surfactant; and a supramolecular host molecule, wherein the supramolecular host molecule is not covalently bonded to the treatment fluid additive; introducing the production fluid containing the treatment fluid into a production facility separator; and separating, in the production facility separator, at least a portion of the production fluid to form a water stream.

A reversible gel composition including nanosilica and polyethylene oxide, the nanosilica and polyethylene oxide present at concentrations operable to allow for the reversible gel composition to be a flowable liquid at pH greater than about 8 and operable to allow for the reversible gel composition to be a substantially solid gel at pH less than about 8.

A method, wellbore, and pill for treating a region of a subterranean formation adjacent a wellbore zone of the wellbore, including injecting a gellable treatment composition (e.g., as the pill) through the wellbore zone into the region of the subterranean formation adjacent the wellbore zone, allowing the gellable treatment composition to form nanoparticles in-situ in the region and gel in the region via heat provided by the region to prevent or reduce flow of an unwanted fluid from the region into the wellbore zone. The gellable treatment composition may include a zwitterionic gemini surfactant (ZGS).

A lost circulation material (LCM) composition for sealing lost circulation zones in wellbores may include 50 weight percent to 97 weight percent epoxy resin, 2 weight percent to 30 weight percent curing agent, 0.1 weight percent to 40 weight percent weighting material, and 0.1 weight percent to 20 weight percent amide accelerator. The LCM composition may have a density of greater than or equal to 1121 kilograms per cubic meter and may be capable of being injected through a drill bit of a drill string into the lost circulation zone. The amide accelerator may enable the viscosity of the LCM composition to be reduced while providing a reduced cure time. The LCM compositions are suitable for treating high-injectivity lost circulation zones.

Degradable particulate materials are provided that may be utilized in various wellbore treatment fluids, such as hydraulic fracturing fluids. In particular, the degradable particulate materials can be formed from a cellulosic polymer, a polyester polymer, a polyvinyl alcohol, or a guar gum ester that are capable of effectively degrading at specific rates when exposed to the aqueous environments in low temperature wellbores (50° C. to 100° C.).

The present disclosure provides polymeric systems that exhibit enhanced viscosity and proppant transport properties while providing enhanced particle dispersion capabilities.

Embodiments disclosed relate to a composition and a method of treating a formation. The method includes introducing a loss circulation material system through a wellbore into a formation, where the loss circulation material system is comprised of an esterified derivative of an epoxidized organic material and a curing agent. The esterified derivative of an epoxidized organic material has a formula of:

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where R′ comprises H, a substituted or an unsubstituted (C1-C12) hydrocarbyl group; and where R″ comprises a substituted or an unsubstituted (C2-C30) hydrocarbyl group, including where at least one oxygen atom is attached to two different adjacent carbon atoms of the (C2-C30) hydrocarbyl group. The method also includes maintaining wellbore conditions such that the loss circulation material system cures into a loss circulation material in the formation. The cured loss circulation material may withstand a pressure differential up to about 20,000 psid.

Disclosed are particulate compositions comprising particles of a blend of one or more polyvinyl alcohol polymers with one or more aliphatic polyester polymers, wherein such particulate compositions are useful, for example, as plugging agents for treatments applied to a subterranean formation traversed by the borehole of an oil or gas well.

Polymer-monodispersed nano-microspheres for deep profile control and flooding. The polymer-monodispersed nano-microspheres comprise (% wt.): 0.05 to 2.5% of macromolecules A, 0.05 to 2.5% of macromolecules B, 0.002 to 0.05% of an oxygen scavenger, and mineralized water. Macromolecules A comprise a straight-chain water-soluble polymer with an ethyl ether or propyl ether structure. Macromolecules B comprise a water-soluble polymer with a hydroxyl or polyphenolic structure. Macromolecules A and macromolecules B are intermolecularly assembled under the drive of extremely strong hydrogen bonds in aqueous solutions to rapidly construct monodispersed nano-microsphere dispersion glue with a controllable size. The monodispersed nano-microspheres have a good seepage in a porous medium and excellent deep profile control and flooding capabilities.