Abstract: A method may include: circulating an oil-based drilling fluid though a drill string to extend a wellbore through a subterranean formation, wherein the oil-based drilling fluid comprises an invert emulsion; separating at least a portion of the oil-based drilling fluid from the circulated oil-based drilling fluid to form a separated portion of oil-based drilling fluid; mixing a metal salt and a metal oxide into the separated portion of the oil-based drilling fluid to form a chemical sealing pill; introducing the chemical sealing pill into the drill string and flowing the chemical sealing pill into a lost circulation zone in the subterranean formation; allowing at least a portion of the chemical sealing pill to set in the lost circulation zone to form a set plug, wherein the set plug seals the lost circulation zone and reduces loss of fluid into the lost circulation zone from subsequently introduced fluids; and preventing loss of fluid into the lost circulation zone from subsequently introduced fluids with the s

Abstract: A treatment fluid can include a base fluid and a lost-circulation package. The lost-circulation package can include plurality of particles of a first, second, and third lost-circulation material. The plurality of particles can be cellulose, sized calcium carbonate, and fibers. The particle size distribution of the plurality of particles can be selected such that the particles enter permeable areas of a subterranean formation to help prevent loss of the base fluid into the formation and allow most of the particles to pass through the screen of a shale shaker. The plurality of particles can have a particle size distribution of a d10 value in the range of 30 to 55 microns, a d50 value in the range of 60 to 100 microns, and a d90 value in the range of 130 to 190 microns. The treatment fluid can be used in an oil and gas operation.

Abstract: A treatment fluid can include a base fluid and a stabilizing additive. The stabilizing additive can include a plurality of environmentally acceptable nanoparticles. The particle size distribution of the plurality of nanoparticles can be selected such that the nanoparticles stabilize a wellbore wall of a subterranean formation or form a filtercake to inhibit or prevent fluid loss into permeable areas of the formation. The plurality of nanoparticles can have a particle size distribution of a d10 value in the range of 20 to 45 nanometers, a d50 value in the range of 40 to 80 nanometers, and a d90 value in the range of 80 to 140 nanometers. The plurality of nanoparticles can also be coated with a polymeric shell. The treatment fluid can be used in an oil and gas operation.

Abstract: A wellbore cleaning composition comprising (i) a surfactant consisting essentially of a sorbitan ester or a derivative thereof and, (ii) a base fluid. A wellbore treatment fluid comprising (1) (i) a surfactant consisting essentially of a sorbitan ester or a derivative thereof and, (ii) a base fluid and (2) an additional bulk fluid. A method of serving a wellbore disposed within a subterranean formation comprising circulating an oil-based drilling mud through an interior of a drill string and an annulus; and placing within the wellbore a wash pill comprising (1) a wellbore cleaning composition comprising (i) a surfactant consisting essentially of a polyethoxylated sorbitan ester or a derivative thereof and (ii) a base fluid and (2) a brine under conditions suitable for the conversion of one or more surfaces of the wellbore from oil-wet to water-wet.

Abstract: A lubricant composition, comprising (i) a vegetable oil; (ii) a surfactant; and (iii) a lime soap dispersing agent, wherein a mixture of the lubricant composition and a brine forms less than about 1 wt. % insoluble particulates based on a total weight of the mixture. A wellbore servicing fluid comprising (i) a lubricant composition comprising (a) a vegetable oil; (b) a surfactant; and (c) a lime soap dispersing agent; and (ii) a drilling mud comprising a base fluid wherein the base fluid comprises a brine. A method of servicing a wellbore comprising placing into a wellbore disposed in a subterranean formation a wellbore servicing fluid comprising a lubricant composition comprising (a) a vegetable oil; (b) a surfactant; and (c) a lime soap dispersing agent; a base fluid; and (iv) a brine.

Abstract: A treatment fluid can include a base fluid and a lost-circulation package. The lost-circulation package can include plurality of pieces of a first lost-circulation material and a second lost-circulation material. The plurality of pieces can be an open-cell, natural or biodegradable material, for example natural sponges such as loofah. The plurality of pieces can enter permeable areas of a subterranean formation and form a mesh-like matrix that the second lost-circulation material can be retained within. The second lost-circulation material can be insoluble particles such as ground walnut shells or include ingredients that form a cementitious substance. The first and second lost-circulation materials can form a plug and provide adequate fluid loss control. The treatment fluid can be used in an oil and gas operation.

Abstract: Methods and compositions for using lubricants in subterranean formations, and specifically lubricants that comprise certain oils, surfactants and solvents, and methods for their use, are provided. In one embodiment, the methods include introducing a treatment fluid that includes a base fluid and a lubricant including at least one vegetable oil, at least one nonionic surfactant, and at least one cosolvent into at least a portion of a subterranean formation.

Abstract: Methods and compositions for using lubricants in subterranean formations, and specifically lubricants that comprise certain oils, surfactants and solvents, and methods for their use, are provided. In one embodiment, the methods include introducing a treatment fluid that includes a base fluid and a lubricant including at least one vegetable oil, at least one nonionic surfactant, and at least one cosolvent into at least a portion of a subterranean formation.

Abstract: A method may include: introducing a treatment fluid into a production fluid disposed in a surface well system, the treatment fluid comprising: a base fluid; and a supramolecular host guest product comprising: a treatment fluid additive comprising a surfactant; and a supramolecular host molecule, wherein the supramolecular host molecule is not covalently bonded to the treatment fluid additive; introducing the production fluid containing the treatment fluid into a production facility separator; and separating, in the production facility separator, at least a portion of the production fluid to form a water stream.

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: Methods and compositions comprising nanoparticle additives for use in drilling and treatment fluid compositions are provided. In some embodiments the present disclosure includes providing a treatment fluid including an aqueous base fluid, a nanoparticle additive, and a viscosifier; introducing the treatment fluid into at least a portion of a subterranean formation to contact at least a portion of the subterranean formation; and allowing the treatment fluid to reduce fluid loss into the subterranean formation.

Abstract: A method may include: introducing a treatment fluid into a stream, the treatment fluid comprising: a base fluid and a supramolecular host guest product, wherein the supramolecular host guest product comprises a treatment fluid additive and a supramolecular host molecule, wherein the supramolecular host molecule is not covalently bonded to the treatment fluid additive.

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.