Abstract: A method includes placing a weighted fluid in the subterranean formation. The weighted fluid includes calcium bromide. The weighted fluid includes one or more secondary salts that are each independently an inorganic bromide salt other than calcium bromide. The weighted fluid also includes water. The weighted fluid has a density at standard temperature and pressure of at least about 1.7 g/cm3.

Abstract: The present disclosure may be directed to defoaming methods and compositions. A method of treating a subterranean formation may comprise providing a defoaming composition, wherein the defoaming composition comprises a tall-oil-derived surfactant. The method may further comprise mixing the defoaming composition with an aqueous fluid to form a treatment fluid such that foaming in the treatment fluid is reduced, wherein the treatment fluid is a water-based fluid. The method may further comprise placing the treatment fluid into the subterranean formation.

Abstract: The present disclosure may be directed to defoaming methods and compositions. A method of treating a subterranean formation may comprise providing a defoaming composition, wherein the defoaming composition comprises a tall-oil-derived surfactant. The method may further comprise mixing the defoaming composition with an aqueous fluid to form a treatment fluid such that foaming in the treatment fluid is reduced, wherein the treatment fluid is a water-based fluid. The method may further comprise placing the treatment fluid into the subterranean formation.

Abstract: Embodiments relate to removing residue from a well bore and well bore equipment with a treatment fluid composition, and in some embodiments, to treatment fluid compositions that comprise nanoparticles. An embodiment provides a method of removing drilling fluid residue from the surfaces of well equipment. The method comprising: applying a solid nanoparticle film to at least a portion of the surfaces of the well equipment with a treatment fluid comprising solid nanoparticles; and allowing the solid nanoparticles to interact with the surfaces of the well equipment and the drilling fluid residue adhered to the surfaces of the well equipment to remove at least a portion of the drilling fluid residue from the surfaces of the well equipment.

Abstract: A disclosed embodiment of a downhole tool includes a pump that is powered by rotation of the drill string to increase fluid pressure during downhole circulation.

Abstract: Embodiments relate to removing residue from a well bore and well bore equipment with a treatment fluid composition, and in some embodiments, to treatment fluid compositions that comprise nanoparticles. An embodiment provides a method of removing drilling fluid residue from the surfaces of well equipment. The method comprising: applying a solid nanoparticle film to at least a portion of the surfaces of the well equipment with a treatment fluid comprising solid nanoparticles; and allowing the solid nanoparticles to interact with the surfaces of the well equipment and the drilling fluid residue adhered to the surfaces of the well equipment to remove at least a portion of the drilling fluid residue from the surfaces of the well equipment.

Abstract: Various embodiments disclosed relate to weighted fluids for treatment of subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing a weighted fluid in the subterranean formation. The weighted fluid includes calcium bromide. The weighted fluid includes one or more secondary salts that are each independently an inorganic bromide salt other than calcium bromide. The weighted fluid also includes water. The weighted fluid has a density at standard temperature and pressure of at least about 1.7 g/cm3.

Abstract: Embodiments relate to removing residue from a well bore and well bore equipment with a treatment fluid composition, and in some embodiments, to treatment fluid compositions that comprise nanoparticles. An embodiment provides a method of removing drilling fluid residue from the surfaces of well equipment. The method comprising: applying a solid nanoparticle film to at least a portion of the surfaces of the well equipment with a treatment fluid comprising solid nanoparticles; and allowing the solid nanoparticles to interact with the surfaces of the well equipment and the drilling fluid residue adhered to the surfaces of the well equipment to remove at least a portion of the drilling fluid residue from the surfaces of the well equipment.

Abstract: A disclosed embodiment of a downhole tool includes a pump that is powered by rotation of the drill string to increase fluid pressure during downhole circulation.

Abstract: Embodiments relate to removing residue from a well bore and well bore equipment with a treatment fluid composition, and in some embodiments, to treatment fluid compositions that comprise nanoparticles. An embodiment provides a method of removing drilling fluid residue from the surfaces of well equipment. The method comprising: applying a solid nanoparticle film to at least a portion of the surfaces of the well equipment with a treatment fluid comprising solid nanoparticles; and allowing the solid nanoparticles to interact with the surfaces of the well equipment and the drilling fluid residue adhered to the surfaces of the well equipment to remove at least a portion of the drilling fluid residue from the surfaces of the well equipment.