Various embodiments disclosed relate to proppant including a swellable coating thereon for treatment of subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a proppant including a coating thereon. The coating is swellable with aqueous medium in response to a trigger including acidic pH, CO.sub.2, H.sub.2S, or a combination thereof.

Various embodiments disclosed relate to proppant including a swellable coating thereon for treatment of subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in the subterranean formation a proppant including a coating thereon. The coating is swellable with aqueous medium in response to a trigger including acidic pH, CO.sub.2, H.sub.2S, or a combination thereof.

A method may comprise: mixing a water having hardness at about 300 ppm or greater with a plurality of particulates, a swellable clay, a chelating agent at about 0.01% to about 5% by weight of the water (BWOW), and an alkali metal base at about 0.01% to about 5% BWOW to produce a treatment fluid; and introducing the treatment fluid into a wellbore penetrating a subterranean formation.

Methods including preparing a treatment fluid comprising a bulk amount of anhydrous ammonia, wherein the anhydrous ammonia is present in an amount greater than about 10% by weight of a liquid portion of the treatment fluid, and wherein the anhydrous ammonia is in a phase selected from the group consisting of a liquid phase, a gaseous phase, supercritical phase, and any combination thereof; and introducing the treatment fluid into a subterranean formation.

A method of fracturing a subterranean formation may comprise: pumping a fracturing fluid into the subterranean formation, through a wellbore, at or above a fracture gradient of the subterranean formation, wherein the fracturing fluid comprises halloysite nanotubes.

A composition for use as a pressure-tolerant dual-crosslinker gel in a fracturing fluid that comprises polymer, the polymer operable to increase the viscosity of a fluid; boron-containing crosslinker, the boron-containing crosslinker operable to crosslink the polymer; and a transition metal oxide additive, the transition metal oxide additive operable to crosslink the polymer.

A directional drilling system includes a rotary steerable tool. The rotary steerable tool includes an extendable member configured to extend outwardly from the rotary steerable tool upon actuation, and a geolocation electronics device configured to track a position of the rotary steerable tool and the extendable member and control actuation of the extendable member. The geolocation electronics device and extendable member are configured to rotate with the rotary steerable tool.

In an embodiment, the present disclosure relates generally to a method for well stimulation. In some embodiments, the method includes pumping a treatment fluid into a well. In some embodiments, the treatment fluid includes carbon dioxide (CO.sub.2) and a breaker, and the method further includes treating at least one of a reservoir and a wellbore of the well with the treatment fluid. In some embodiments, the breaker is a solution of stabilized chlorine dioxide (ClO.sub.2). In some embodiments, the method further includes commingling the CO.sub.2 with water and forming, as a result of the commingling, carbonic acid. In some embodiments, the method includes activating the stabilized ClO.sub.2 to form activated ClO.sub.2. In some embodiments, the activated ClO.sub.2 is formed as a result of a lowering of pH in the treatment fluid by the carbonic acid.

A brine resistant silica sol is described and claimed. This brine resistant silica sol comprises an aqueous colloidal silica mixture that has been surface functionalized with at least one moiety selected from the group consisting of a monomeric hydrophilic organosilane, a mixture of monomeric hydrophilic organosilane(s) and monomeric hydrophobic organosilane(s), or a polysiloxane oligomer, wherein the surface functionalized brine resistant aqueous colloidal silica sol passes at least two of three of these brine resistant tests: API Brine Visual, 24 Hour Seawater Visual and API Turbidity Meter.

Application of polyaminated fatty acid-based oil compositions to additive particles to control dusting. A method reducing an amount of dust produced during transfer of additive particles in well operations may comprise providing treated additive particles comprising additive particles and a polyaminated fatty acid-based oil composition disposed on a surface of at least portion of the particles, wherein the polyaminated fatty acid-based oil composition comprises a polyaminated fatty acid and an organic solvent. The method may further comprise mixing components comprising the treated additive particles and a base fluid to provide a treatment fluid. The method may further comprise introducing the treatment fluid into a subterranean formation.