Wellbore strengthening compositions may include a base fluid; and a solid gum rosin additive, wherein the solid gum rosin additive has an average particle size of 1 m to 15 mm. Methods may include emplacing a wellbore fluid containing a solid gum rosin additive into a wellbore, wherein the solid gum rosin additive has an average particle size of 1 m to 15 mm.

Wellbore strengthening compositions may include a base fluid; and a solid gum rosin additive, wherein the solid gum rosin additive has an average particle size of 1 m to 15 mm. Methods may include emplacing a wellbore fluid containing a solid gum rosin additive into a wellbore, wherein the solid gum rosin additive has an average particle size of 1 m to 15 mm.

Treatment method for a rock formation against sand infiltration during production of fluid from this rock formation via a well drilled through said rock formation, comprising at least one step of injecting a geopolymer cement grout into said rock formation, in particular around the edges of said well and/or through said well.

A well treatment composition for use in a hydrocarbon-bearing reservoir comprising a reversible aminal gel composition. The reversible aminal gel composition includes a liquid precursor composition. The liquid precursor composition is operable to remain in a liquid state at about room temperature. The liquid precursor composition comprises an organic amine composition; an aldehyde composition; a polar aprotic organic solvent; and a metal salt composition with valence 3, 4, or 5. The liquid precursor composition transitions from the liquid state to a gel state responsive to an increase in temperature in the hydrocarbon-bearing reservoir. The gel state is stable in the hydrocarbon-bearing reservoir at a temperature similar to a temperature of the hydrocarbon-bearing reservoir, and the gel state is operable to return to the liquid state responsive to a change in the hydrocarbon-bearing reservoir selected from the group consisting of: a decrease in pH in the hydrocarbon-bearing reservoir and an addition of excess metal salt composition in the hydrocarbon-bearing reservoir.

A method including providing a drilling fluid that comprises a base fluid, a weighting agent, and a sag stability enhancer, wherein the sag stability enhancer comprises polyethylene glycol (PEG) having a molecular weight of greater than or equal to about 200 g/mol; and placing the drilling fluid in a subterranean formation via a wellbore penetrating the subterranean formation. A method including forming a fluid comprising a base fluid, a weighting agent, and from about 0.5 ppb (1.4 kg/m.sup.3) to about 30 ppb (85.5 kg/m.sup.3) of a sag stability enhancer, wherein the sag stability enhancer comprises a glycol; and introducing the fluid into at least a portion of a well. A drilling fluid containing a base fluid, a weighting agent, and a sag stability enhancer comprising polyethylene glycol (PEG) having a molecular weight of greater than or equal to about 200 g/mol.

A method for plugging and sealing subsurface formations using alkaline nanosilica dispersion and a delayed activation chemistry is disclosed. In accordance with one embodiment of the present disclosure, the method includes introducing a mixture with a first pH into the subsurface formation. The mixture comprises an aqueous solution, an alkaline nanosilica dispersion and a water-insoluble hydrolyzable compound. The method further includes allowing the water-insoluble hydrolyzable compound to hydrolyze in the subsurface formation to form an acid at 70 C. or greater, thereby acidizing the mixture to a reduced second pH and causing the alkaline nanosilica dispersion to gel into a solid and seal the subsurface formation. A composition for sealing a subsurface formation is also disclosed. The composition includes an aqueous mixture including water, an alkaline nanosilica dispersion, and a water-insoluble hydrolyzable compound.

Of the methods provided herein, is a method comprising: providing a treatment fluid comprising an aqueous base fluid, an inorganic oxidizer and an activator selected from the group consisting of N-acyl caprolactam based activators, substitutes benzoyl caprolactam based activators and mixtures thereof are provided; and preparing the treatment fluid for use in a down-hole operation, where the down-hole operation is either a gel breaking operation or a formation conditioning operation.

Of the methods provided herein, is a method comprising: providing a treatment fluid comprising an aqueous base fluid, an inorganic oxidizer and an activator selected from the group consisting of N-acyl caprolactam based activators, substitutes benzoyl caprolactam based activators and mixtures thereof are provided; and preparing the treatment fluid for use in a down-hole operation, where the down-hole operation is either a gel breaking operation or a formation conditioning operation.

Systems and methods for treating fracture faces and/or unconsolidated portions of a subterranean formation are provided. In some embodiments, the methods comprise: providing an aqueous alkali solution; introducing the aqueous alkali solution into at least a portion of a subterranean formation that comprises one or more fractures; contacting an aluminum component and a silicate component with the aqueous alkali solution to form a geopolymer on one or more fracture faces in the fractures; and placing a plurality of proppant particulates in the fractures.

An oil recovery composition having a brine, a hydrolyzable polymer, and a monovalent cations to divalent cations ration in the range of about 2.5:1 to 3:1 is provided. An oil recovery composition may be formed from a brine recovered from production water and a polymer. A monovalent salt may be added to the brine recovered from production water to form a modified brine and achieve a modified monovalent cations to divalent cations ratio in the range of about 2.5:1 to 3:1. Processes for forming the oil recovery composition and enhanced oil recovery using the oil recovery composition are provided.