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: Methods of providing fluid loss control in a portion of a subterranean formation comprising: providing a treatment fluid comprising a base fluid and a plurality of seeds; introducing the treatment fluid into a portion of a subterranean formation penetrated by a well bore such that the seeds block openings in the subterranean formation to provide fluid loss control; and degrading the seeds over time within the subterranean formation. In some methods, the seeds are present in the treatment fluid in an amount of at least about 5 pounds per barrel. In addition, in some methods the seeds are preferably degradable.

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: Methods of treatment subterranean formations including providing a treatment fluid comprising a base fluid and a lubricating agent, wherein the lubricating agent is selected from the group consisting of bismuth dialkyl dithiophosphate; tungsten disulfide; a mixture of micronized graphite and micronized metal disulfide; and any combination thereof; and introducing the treatment fluid into a wellbore in the subterranean formation.

Abstract: Methods of providing fluid loss control in a portion of a subterranean formation comprising: providing a treatment fluid comprising a base fluid and a plurality of seeds; introducing the treatment fluid into a portion of a subterranean formation penetrated by a well bore such that the seeds block openings in the subterranean formation to provide fluid loss control; and degrading the seeds over time within the subterranean formation. In some methods, the seeds are present in the treatment fluid in an amount of at least about 5 pounds per barrel. In addition, in some methods the seeds are preferably degradable.

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: 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: 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. 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.

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: Precipitated 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 has a density of about 7 ppg to about 50 ppg and comprises 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. Such mineral particles 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 has a density of about 7 ppg to about 50 ppg and comprises a base fluid, a plurality of linkable mineral particles, and optionally a linking agent.

Abstract: The invention pertains to the use of a class of acetylenic surfactants to resolve or break water and oil emulsions. The surfactants are of particular advantage in resolving crude oil emulsions of the type encountered in desalter and similar apparatus designed to extract brines from the crude as they partition to the aqueous phase in the desalter. Also, the surfactants may be used to separate oil from oil sands and similar oil/solids matrices.