Lost circulation materials may include pluralities of ceramic spheres having a size distribution in a range of from about 5 mm to about 25 mm and such that the lost circulation materials are porous and permeable. Methods of eliminating or reducing lost circulation from a well having a loss zone may include introducing the porous and permeable lost circulation materials into the well such that a porous and permeable flow barrier is created in the loss zone, wherein the porous and permeable flow barrier may prevent whole mud loss while drilling and allows hydrocarbon production after completion of the well. Carrier fluids may include water, viscosifiers, fluid loss additives, weighting agents, lost circulation materials containing pluralities of ceramic spheres having a size distribution in a range of from about 5 mm to about 25 mm.

Provided is a loss circulation material that may consist essentially of an acidic nanosilica dispersion and an activator. The acidic nanosilica dispersion may consist of acidic silica nanoparticles, stabilizer, and water, and may have a pH in a range of 3 to 6. The activator may be one or more from the group consisting of sodium bicarbonate, sodium chloride, or an amine salt. A method is provided for controlling lost circulation in a lost circulation zone in a wellbore comprising introducing the loss circulation material and forming a gelled solid from the loss circulation material in the lost circulation zone.

Disclosed herein is a method of servicing a wellbore penetrating a subterranean formation with a thixotropic cement composition. The thixotropic cement composition comprises a cementitious material, maltodextrin, and an aqueous fluid, has a 10-minute gel strength of from about 30 lbf/100 ft.sup.2 to about 300 lbf/100 ft.sup.2, and can be used to reduce lost circulation in the wellbore. By incorporating maltodextrin into the thixotropic cement composition as disclosed herein, the thixotropic cement composition can have a similar 10-minute gel strength and an increased thickening time when compared to a reference composition.

A system and method for treating lost circulation, including providing a treatment fluid including a polymer and a nitrogen-generating compound through a wellbore into a lost circulation zone in a subterranean formation, generating nitrogen gas in the lost circulation zone by a reaction of the nitrogen-generating compound, generating foam from the nitrogen gas and the treatment fluid in the lost circulation zone to give foamed polymer in the lost circulation zone, and plugging the lost circulation zone with the foamed polymer.

Systems and methods for detecting or monitoring treatment fluids in subterranean formations are provided. In certain embodiments, the methods comprise: providing an enhanced treatment fluid that comprises at least a base fluid and one or more contrast enhancement agents selected from the group consisting of: a magnetic material; a dispersive material; and any combination thereof, wherein the enhanced cementing fluid comprises one or more micro-electro-mechanical system (MEMS) sensors; and introducing the enhanced treatment fluid into at least a portion of a well bore penetrating a portion of a subterranean formation.

Systems and methods for detecting or monitoring treatment fluids in subterranean formations are provided. In certain embodiments, the methods comprise: providing an enhanced treatment fluid that comprises at least a base fluid and one or more contrast enhancement agents selected from the group consisting of: a magnetic material; a dispersive material; and any combination thereof, wherein the enhanced cementing fluid comprises one or more micro-electro-mechanical system (MEMS) sensors; and introducing the enhanced treatment fluid into at least a portion of a well bore penetrating a portion of a subterranean formation.

A method of treating a carbonate formation includes introducing a stimulation fluid into the carbonate formation at a pressure greater than a fracture pressure of the formation and creating openings in the carbonate formation via the stimulation fluid. Then, a fluoride salt solution, optionally including a proppant, may be introduced into the carbonate formation such that it at least partially penetrates into the openings. The fluoride salt may then be reacted with a carbonate surface in the carbonate formation to form fluorite on a surface of the formation thereby increasing a hardness of the carbonate formation.

Wellbore fluids may contain an aqueous base fluid comprising a monovalent brine, a modified starch, and a metal oxide. Methods of using wellbore fluids may include drilling a subterranean well while circulating a wellbore fluid into the subterranean well, wherein the wellbore fluid contains an aqueous base fluid comprising a monovalent brine, a modified starch, and a metal oxide.

A drilling fluid containing a liquid phase, a weighting agent (e.g. barite, calcite, ilmenite), and perlite is described. The drilling fluid may further contain one or more additives including a defoamer, a fluid-loss control agent, a viscosifier, an antiscalant, a deflocculant, a lubricant, a clay stabilizer, a bridging agent, and a surfactant. A process of drilling a subterranean geological formation utilizing the drilling fluid is also specified. The introduction of perlite to the drilling fluid is effective in reducing the thickness and permeability of filter cakes formed during the drilling process.

A well treatment composition for use in a hydrocarbon-bearing reservoir comprising a reversible aminal gel composition. The reversible aminal gel composition includes a liquid precursor composition. The liquid precursor composition is operable to remain in a liquid state at about room temperature. The liquid precursor composition comprises an organic amine composition; an aldehyde composition; and a polar aprotic organic solvent. The liquid precursor composition transitions from the liquid state to a gel state responsive to an increase in temperature in the hydrocarbon-bearing reservoir. The gel state is stable in the hydrocarbon-bearing reservoir at a temperature similar to a temperature of the hydrocarbon-bearing reservoir, and the gel state is operable to return to the liquid state responsive to a change in the hydrocarbon-bearing reservoir selected from the group consisting of: a decrease in pH in the hydrocarbon-bearing reservoir and an addition of excess metal salt composition in the hydrocarbon-bearing reservoir.