Abstract: Systems and methods to determine concentrations of certain polymer encapsulators in drilling fluids based on light scattering, turbidity analysis and other analysis techniques. The method generally includes disposing a sample of drilling fluid within a vessel. A precipitant is added to form a precipitate with the desired polymer resulting in turbidity which is then measured in a variety of ways to determine the amount of polymer in the drilling fluid.

Abstract: Sand consolidation for a subterranean formation can be achieved by adding a curable resin to a drilling fluid. The curable resin can be a furan- or epoxy- or silane-based resin. The drilling fluid can form a filtercake on a wellbore wall. A filtercake-removal fluid can provide a dual function to remove the filtercake and cure the curable resin, which consolidates formation particles. A curing agent can also be included in the filtercake-removal fluid. Sand consolidation can also be achieved by adding the curable resin to the filtercake-removal fluid. The resin can penetrate into the formation as the filtercake is being removed and then cure.

Abstract: A variety of methods, systems, and compositions are disclosed, including, in one embodiment, a method of servicing a borehole including providing a borehole servicing fluid in a borehole penetrating a subterranean formation, wherein the borehole servicing fluid includes a nucleophilic organic molecule and an electrophile. The method further may include reacting the nucleophilic organic molecule and the electrophile to generate at least an acidic species. The method further may include contacting an acid-soluble component in the subterranean formation with the acidic species such that the acidic species degrades the acid-soluble component.

Abstract: Compositions and methods involving polyvalent cation reactive polymers for use as lost circulation materials in subterranean treatment operations are provided. In some embodiments, the methods include forming a treatment fluid including a base fluid, a source of a polyvalent cation, a polyvalent cation reactive polymer, and an acid precursor; introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation; and allowing the treatment fluid to at least partially set.

Abstract: Compositions and methods involving polyvalent cation reactive polymers for use as lost circulation materials in subterranean treatment operations are provided. In some embodiments, the methods include forming a treatment fluid including a base fluid, a source of a polyvalent cation, a polyvalent cation reactive polymer, and an acid precursor; introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation; and allowing the treatment fluid to at least partially set.

Abstract: Compositions and methods for use in subterranean treatment fluids involving thermoassociative polymers are provided. In some embodiments, the methods include providing a treatment fluid that includes an aqueous base fluid, one or more thermoassociative polymers that include a water soluble polymeric backbone having one or more hydrophobic moieties attached to the polymer backbone, wherein the thermoassociative polymer exhibits thermoassociation at a first temperature Tassoc, and one or more tuning additives that changes the temperature at which at least one of the thermoassociative polymers exhibits thermoassociation from Tassoc to a second temperature Tassoc?; and introducing the treatment fluid into a portion of a subterranean formation.

Abstract: Compositions and methods involving polyvalent cation reactive polymers for use as lost circulation materials in subterranean treatment operations are provided. In some embodiments, the methods include forming a treatment fluid including a base fluid, a source of a polyvalent cation, a polyvalent cation reactive polymer, and an acid precursor; introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation; and allowing the treatment fluid to at least partially set.

Abstract: Compositions and methods for use in subterranean treatment fluids involving thermoassociative polymers are provided. In some embodiments, the methods include providing a treatment fluid that includes an aqueous base fluid, one or more thermoassociative polymers that include a water soluble polymeric backbone having one or more hydrophobic moieties attached to the polymer backbone, wherein the thermoassociative polymer exhibits thermoassociation at a first temperature Tassoc, and one or more tuning additives that changes the temperature at which at least one of the thermoassociative polymers exhibits thermoassociation from Tassoc to a second temperature Tassoc?; and introducing the treatment fluid into a portion of a subterranean formation.

Abstract: Mineral particles may provide for wellbore fluids with tailorable properties and capabilities. Methods of using mineral particles may include circulating a wellbore fluid with a first density of about 7 ppg to about 50 ppg in a wellbore penetrating a subterranean formation, the wellbore fluid comprising a base fluid, a plurality of first mineral particles, and a plurality of second mineral particles such that the first mineral particles and the second mineral particles are present in a first relative ratio, and the first mineral particles and the second mineral particles having a multiparticle specific gravity of about 3 to about 20; and changing the first relative ratio to a second relative ratio on-the-fly so as to yield the wellbore fluid with a second density.

Abstract: Mineral particles may provide for wellbore fluids with tailorable properties and capabilities, and methods relating thereto. Mineral particles may be utilized in methods that include introducing a wellbore fluid having a density of about 7 ppg to about 50 ppg into a wellbore penetrating a subterranean formation, the wellbore fluid comprising a base fluid and a plurality of mineral particles, and the wellbore fluid having a first viscosity; contacting at least some of the mineral particles with a linking agent so as to link the at least some of the mineral particles, thereby increasing the first viscosity to a second viscosity.

Abstract: Mineral particles may provide for wellbore fluids with tailorable properties and capabilities. In some instances, a dry wellbore additive may comprise a plurality of first mineral particles having a specific gravity of about 2.6 to about 20; a plurality of second mineral particles having a specific gravity of about 5.5 to about 20; a plurality of lubricant particles having a specific gravity of about 2.6 to about 20; wherein the first mineral particles, the second mineral particles, and the lubricant particles are different; and wherein the first mineral particles, the second mineral particles, and the lubricant particles have a multiparticle specific gravity of about 3 to about 20.

Abstract: A method of using precipitated particles in a wellbore may comprise circulating a wellbore fluid in a wellbore penetrating a subterranean formation, the wellbore fluid having a density of about 7 ppg to about 50 ppg and comprising a base fluid and a plurality of precipitated particles having a shape selected from the group consisting of ovular, substantially ovular, discus, platelet, flake, toroidal, dendritic, acicular, spiked with a substantially spherical or ovular shape, spiked with a discus or platelet shape, rod-like, fibrous, polygonal, faceted, star shaped, and any hybrid thereof.

Abstract: Mineral particles may provide for wellbore fluids with tailorable properties and capabilities. Such wellbore fluids may be included as a portion of a wellbore drilling assembly that includes a pump in fluid communication with a wellbore via a feed pipe; and a wellbore fluid disposed in at least one selected from the group consisting of the pump, the feed pipe, the wellbore, and any combination thereof, wherein the wellbore fluid comprises a base fluid and a plurality of mineral particles, for example, mineral particles that comprise at least one selected from the group consisting of manganese carbonate, NixFe (x=2-3), copper oxide, and any combination thereof, the mineral particles having a median diameter between about 5 nm and about 5000 microns.

Abstract: Mineral particles may provide for wellbore fluids with tailorable properties and capabilities, and methods relating thereto. Mineral particles may be utilized in methods that include introducing a wellbore fluid having a density of about 7 ppg to about 50 ppg into a wellbore penetrating a subterranean formation, the wellbore fluid comprising a base fluid and a plurality of mineral particles, and the wellbore fluid having a first viscosity; contacting at least some of the mineral particles with a linking agent so as to link the at least some of the mineral particles, thereby increasing the first viscosity to a second viscosity.

Abstract: Mineral particles may provide for wellbore fluids with tailorable properties and capabilities. In some instances, a dry wellbore additive may comprise a plurality of first mineral particles having a specific gravity of about 2.6 to about 20; a plurality of second mineral particles having a specific gravity of about 5.5 to about 20; a plurality of lubricant particles having a specific gravity of about 2.6 to about 20; wherein the first mineral particles, the second mineral particles, and the lubricant particles are different; and wherein the first mineral particles, the second mineral particles, and the lubricant particles have a multiparticle specific gravity of about 3 to about 20.

Abstract: A wellbore drilling assembly may include a pump in fluid communication with a wellbore via a feed pipe; and a wellbore fluid disposed in at least one selected from the group consisting of the pump, the feed pipe, the wellbore, and any combination thereof, wherein the wellbore fluid comprises a base fluid and a wellbore additive. In some instances, a wellbore additive may include first mineral particles having a specific gravity of about 2.6 to about 20; second mineral particles having a specific gravity of about 5.5 to about 20; lubricant particles having a specific gravity of about 2.6 to about 20; wherein the first mineral particles, the second mineral particles, and the lubricant particles are different; and wherein the first mineral particles, the second mineral particles, and the lubricant particles have a multiparticle specific gravity of about 3 to about 20.

Abstract: Mineral particles may provide for wellbore fluids with tailorable properties and capabilities, and methods relating thereto. Mineral particles may be utilized in methods that include introducing a wellbore fluid having a density of about 7 ppg to about 50 ppg into a wellbore penetrating a subterranean formation, the wellbore fluid comprising a base fluid and a plurality of mineral particles, and the wellbore fluid having a first viscosity; contacting at least some of the mineral particles with a linking agent so as to link the at least some of the mineral particles, thereby increasing the first viscosity to a second viscosity.

Abstract: Mineral particles may provide for wellbore fluids with tailorable properties and capabilities. Such wellbore fluids may be included in systems that comprise a pump in fluid communication with a wellbore via a feed pipe; and a wellbore fluid disposed in at least one selected from the group consisting of the pump, the feed pipe, the wellbore, and any combination thereof, wherein the wellbore fluid comprises a base fluid, a plurality of first mineral particles, and a plurality of second mineral particles such that the first mineral particles and the second mineral particles having a multiparticle specific gravity of about 3 to about 20.

Abstract: Mineral particles may provide for wellbore fluids with tailorable properties and capabilities, and methods relating thereto. Mineral particles may be utilized in a method that comprises introducing a wellbore fluid into a wellbore penetrating a subterranean formation, the wellbore fluid comprising a base fluid and a plurality of mineral particles that comprise at least one selected from the group consisting of manganese carbonate, NixFe (x=2-3), copper oxide, and any combination thereof, the mineral particles having a median diameter between about 5 nm and about 5000 microns.

Abstract: Mineral particles may provide for wellbore fluids with tailorable properties and capabilities. Methods of using mineral particles may include circulating a wellbore fluid with a first density of about 7 ppg to about 50 ppg in a wellbore penetrating a subterranean formation, the wellbore fluid comprising a base fluid, a plurality of first mineral particles, and a plurality of second mineral particles such that the first mineral particles and the second mineral particles are present in a first relative ratio, and the first mineral particles and the second mineral particles having a multiparticle specific gravity of about 3 to about 20; and changing the first relative ratio to a second relative ratio on-the-fly so as to yield the wellbore fluid with a second density.