Abstract: A stabilized water-dispersible latex additive useful in both freshwater-based and brine-based drilling fluids, may be formed by mixing an effective amount of a compound containing at least one pyrrolidone ring, such as, polyvinylpyrrolidone, a vinylpyrrolidone-vinyl acetate copolymer, poly(1-vinylpyrrolidone-co-2-dimethylaminoethyl methacrylate), a vinylpyrrolidone-acrylic acid copolymer, and combinations thereof, with the water-dispersible latex additive before or after the water-dispersible latex additive is introduced to the drilling fluid.

Abstract: A stabilized water-dispersible latex additive useful in both freshwater-based and brine-based drilling fluids, may be formed by mixing an effective amount of a compound containing at least one pyrrolidone ring, such as, polyvinylpyrrolidone, a vinylpyrrolidone-vinyl acetate copolymer, poly(1-vinylpyrrolidone-co-2-dimethylami-noethyl methacrylate), a vinylpyrrolidone-acrylic acid copolymer, and combinations thereof, with the water-dispersible latex additive before or after the water-dispersible latex additive is introduced to the drilling fluid.

Abstract: A method for introducing an organic drilling fluid additive into an aqueous drilling fluid in a subterranean formation, where the method includes introducing loaded microparticles into an aqueous drilling fluid. The loaded microparticles are made by absorbing at least one organic drilling fluid additive onto hybrid calcium carbonate microparticles to form loaded microparticles. The method further includes delivering the drilling fluid into a subterranean formation, and optionally shearing the loaded microparticles to release the absorbed drilling fluid additive(s) into the drilling fluid, such as by shearing them at the drill bit.

Abstract: Capped carbon-based nanoparticles may be added to an oil-based fluid to improve the electrical conductivity of the oil-based fluid. The oil-based fluid may be a drilling fluid, a completion fluid, a drill-in fluid, a stimulation fluid, a servicing fluid, and combinations thereof. In a non-limiting embodiment, the oil-based fluid composition may be circulated in a subterranean reservoir wellbore.

Abstract: Capped nanoparticles may be added to an oil-based fluid to improve the electrical conductivity of the oil-based fluid. The oil-based fluid may be a drilling fluid, a completion fluid, a drill-in fluid, a stimulation fluid, a servicing fluid, and combinations thereof. In a non-limiting embodiment, the oil-based fluid composition may be circulated in a subterranean reservoir wellbore.

Abstract: Polymer-modified asphalt is used in drilling fluids for filtration control, lost circulation control, drill string differential sticking prevention, or wellbore stabilization. The latex modified asphalt provides a mixture of latex-asphalt complex, asphalt, and latex particles that help maintain wellbore stability while drilling into shale formations. The polymer-modified latex is effective for controlling laminated and microfractured shale. Polymers may be functionalized to react with the asphalt to create copolymer modifications of the asphalt for improved performance as drilling fluid additives. The drilling fluids may be water-based or oil-based, or based on an emulsion of oil and water.

Abstract: Polymer-modified asphalt is used in drilling fluids for filtration control, lost circulation control, drill string differential sticking prevention, or wellbore stabilization. The latex modified asphalt provides a mixture of latex-asphalt complex, asphalt, and latex particles that help maintain wellbore stability while drilling into shale formations. The polymer-modified latex is effective for controlling laminated and microfractured shale. Polymers may be functionalized to react with the asphalt to create copolymer modifications of the asphalt for improved performance as drilling fluid additives. The drilling fluids may be water-based or oil-based, or based on an emulsion of oil and water.

Abstract: A method for introducing an organic drilling fluid additive into an aqueous drilling fluid in a subterranean formation, where the method includes introducing loaded microparticles into an aqueous drilling fluid. The loaded microparticles are made by absorbing at least one organic drilling fluid additive onto hybrid calcium carbonate microparticles to form loaded microparticles. The method further includes delivering the drilling fluid into a subterranean formation, and optionally shearing the loaded microparticles to release the absorbed drilling fluid additive(s) into the drilling fluid, such as by shearing them at the drill bit.

Abstract: Carbon black particles and/or optional additional particle(s) may be introduced into fluids, such as drilling fluids, completion fluids, production fluids, stimulation fluids, and combinations thereof. The carbon black particles and/or optional additional particle(s) may increase the electrical and/or thermal conductivity, enhance the stability of an emulsion, improve wellbore strength, improve drag reduction properties, decrease corrosion, and the like. In a non-limiting embodiment, the base fluid may include a brine having at least one multivalent cation.

Abstract: Capped nanoparticles may be added to an oil-based fluid to improve the electrical conductivity of the oil-based fluid. The oil-based fluid may be a drilling fluid, a completion fluid, a drill-in fluid, a stimulation fluid, a servicing fluid, and combinations thereof. In a non-limiting embodiment, the oil-based fluid composition may be circulated in a subterranean reservoir wellbore.

Abstract: Adding a lubricant having a metal stearate and polytetrafluoroethylene (PTFE) to a downhole fluid may lubricate a first surface once the downhole fluid has been circulated within a subterranean reservoir wellbore. Friction, torque, and/or drag may be reduced when the lubricated first surface contacts a second surface. The first surface may be or include, but is not limited to a wellbore casing, a drill string, a pipe, a formation, a drill bit, a metal surface within a mud motor, formation evaluation tool, at least one drilling tool, and combinations thereof. One or both of the first and second surfaces may be metal. The downhole fluid may be or include, but is not limited to, a drilling fluid, a completion fluid, a fracturing fluid, a drill-in fluid, a workover fluid, and combinations thereof.

Abstract: A method for estimating a depth from which cuttings have been recovered from a well may include varying a parameter of one or more marking agents added into a drilling fluid circulated into the well and recovering the cuttings from the well. The depth may be estimated by estimating a value associated with the marking agent that marks the cuttings. A system for estimating a depth from which cuttings have been recovered from a well includes at least one marking agent configured to mark the cuttings and a marking agent dispensing device configured to add the at least one marking agent into a drilling fluid circulated into the well. The marking agent dispensing device may be further configured to vary a parameter of the at least one marking agent.

Abstract: Adding a lubricant having a metal stearate and polytetrafluoroethylene (PTFE) to a downhole fluid may lubricate a first surface once the downhole fluid has been circulated within a subterranean reservoir wellbore. Friction, torque, and/or drag may be reduced when the lubricated first surface contacts a second surface. The first surface may be or include, but is not limited to a wellbore casing, a drill string, a pipe, a formation, a drill bit, a metal surface within a mud motor, formation evaluation tool, at least one drilling tool, and combinations thereof. One or both of the first and second surfaces may be metal. The downhole fluid may be or include, but is not limited to, a drilling fluid, a completion fluid, a fracturing fluid, a drill-in fluid, a workover fluid, and combinations thereof.

Abstract: A method for estimating a depth from which cuttings have been recovered from a well may include varying a parameter of one or more marking agents added into a drilling fluid circulated into the well and recovering the cuttings from the well. The depth may be estimated by estimating a value associated with the marking agent that marks the cuttings. A system for estimating a depth from which cuttings have been recovered from a well includes at least one marking agent configured to mark the cuttings and a marking agent dispensing device configured to add the at least one marking agent into a drilling fluid circulated into the well. The marking agent dispensing device may be further configured to vary a parameter of the at least one marking agent.

Abstract: Lubricants and drilling fluid systems comprising lubricants which form a coherent lubricating film on metal equipment, thereby prolonging equipment life even under a wide variety of conditions, including high temperature and/or high pressure conditions.

Abstract: A drilling fluid has a redispersible polymer powder introduced as a water dispersion that is capable of providing a deformable latex film on at least a portion of a subterranean sand formation and which inhibits or controls fluid loss and acts as a sealing agent when used to drill in sand formations for hydrocarbon recovery operations. The redispersible polymer powder may be made by drying the emulsion in which they are formed and then grinding into a powder or by spray drying. The polymer particles of suitable size precipitate or collect or assemble onto the pores of a subterranean sand formation to at least partial seal the formation with a deformable polymer film.

Abstract: A drilling fluid has a redispersible polymer powder introduced as a water dispersion that is capable of providing a deformable latex film on at least a portion of a subterranean sand formation and which inhibits or controls fluid loss and acts as a sealing agent when used to drill in sand formations for hydrocarbon recovery operations. The redispersible polymer powder may be made by drying the emulsion in which they are formed and then grinding into a powder or by spray drying. The polymer particles of suitable size precipitate or collect or assemble onto the pores of a subterranean sand formation to at least partial seal the formation with a deformable polymer film.

Abstract: Latex additives, methods for treating latex additives, drilling fluid systems, and lost circulation pills comprising the latex additives, the latex additive comprising latex particles having a particle size distribution before aging comprising an average particle diameter of about 1 micron or less; and a quantity of one or more water soluble oxygenated organic molecules comprising two or more oxygen atoms effective to maintain substantially the same particle size distribution before and after freezing the latex additive.

Abstract: A water-based drilling fluid having a polymer latex capable of providing a deformable latex film on at least a portion of a subterranean formation has been discovered to provide reduced drilling fluid pressure invasion when used to drill in shale formations for hydrocarbon recovery operations. A precipitating agent such as a silicate or an aluminum complex (e.g. sodium aluminate) is preferably used in conjunction with the polymer. Typically, the water present contains a salt to form a brine, often to saturation, although the invention may be practiced with fresh water. If a salt is employed, it is often helpful to additionally employ a surfactant, such as a betaine, for example.

Abstract: An oil-based drilling fluid having a polymer latex capable of providing a deformable latex film on at least a portion of a subterranean sand formation has been discovered to inhibit or control fluid loss and act as a sealing agent when used to drill in sand formations for hydrocarbon recovery operations. Typically, the polymer latex is an aqueous suspension of particles formed by emulsion polymerization that is in turn emulsified into a hydrocarbon base fluid. The polymer particles of suitable size precipitate onto the pores of a subterranean sand formation to at least partial seal the formation with a deformable polymer film.