Non-aqueous drilling fluids may be removed from a wellbore or tubing nor casing within the wellbore by introducing into the well a biodegradable aqueous fluid comprising banana.

Compositions and methods for using those compositions to at least partially stabilize subterranean formations are provided. In one embodiment, the methods include providing a treatment fluid including an aqueous base fluid and an additive including a low molecular mass organic gelator; introducing the treatment fluid into at least a portion of a subterranean formation to contact at least a portion of the subterranean formation that includes shale; and allowing the additive to interact with the shale to at least partially stabilize the shale.

A completion/stimulation/production fluid and injection mixture blend is disclosed. The blend may include an aqueous fluid, a polymer system and an injection mixture that includes a polyol, a natural sugar, an artificial sugar, or a combination thereof.

A completion/stimulation/production fluid and injection mixture blend is disclosed. The blend may include an aqueous fluid, a polymer system and an injection mixture that includes a polyol, a natural sugar, an artificial sugar, or a combination thereof.

Cement slurries are prepared that comprise water, a hydraulic cement, particles of an oil-absorbent particles and non-swellable hydrophobic particles. The particles are present in an amount sufficient to alter a property of a non-aqueous drilling fluid. The cement slurry is placed in a subterranean well, whereupon the slurry contacts residual drilling fluid on casing and formation surfaces. The oil-absorbent particles and hydrophobic particles in the cement slurry may reduce the mobility of the drilling fluid, thereby improving zonal isolation.

A breaker composition comprising (i) an acid precursor, (ii) an accelerating agent wherein the accelerating agent comprises a Lewis acid and (iii) an aqueous fluid wherein the effective operating temperature of the breaker composition ranges from about 15° C. to about 120° C. A wellbore servicing system comprising (a) an aqueous-based drilling fluid, wherein the aqueous-based drilling fluid forms water-wet solids in the wellbore; and (b) a breaker composition comprising (i) an acid, (ii) an accelerating agent and (iii) an aqueous fluid. A method of dissolving a filtercake comprising contacting the filtercake with a breaker solution comprising (i) an acid precursor, (ii) an accelerating agent and (iii) an aqueous fluid wherein the filtercake comprises calcium carbonate.

A breaker composition comprising (i) an acid precursor, (ii) an accelerating agent wherein the accelerating agent comprises a Lewis acid and (iii) an aqueous fluid wherein the effective operating temperature of the breaker composition ranges from about 15° C. to about 120° C. A wellbore servicing system comprising (a) an aqueous-based drilling fluid, wherein the aqueous-based drilling fluid forms water-wet solids in the wellbore; and (b) a breaker composition comprising (i) an acid, (ii) an accelerating agent and (iii) an aqueous fluid. A method of dissolving a filtercake comprising contacting the filtercake with a breaker solution comprising (i) an acid precursor, (ii) an accelerating agent and (iii) an aqueous fluid wherein the filtercake comprises calcium carbonate.

A solid surfactant composition includes a water-wetting surfactant and a plant fiber carrying agent. A process includes forming a solid surfactant composition comprising a water-wetting surfactant and a plant fiber carrying agent and injecting the solid surfactant composition into a wellbore.

Disclosed herein is a wellbore servicing fluid comprising a scale inhibitor, a surfactant, and an aqueous fluid comprising sulfate in an amount of from about 100 ppm to about 10,000 ppm based on the total weight of the aqueous fluid. The wellbore servicing fluid can be used as a fracturing fluid in a method of servicing a wellbore penetrating a subterranean formation. The wellbore servicing fluid can mitigate the formation of scales, prevent water blockage, and increase hydrocarbon production.

Disclosed herein is a wellbore servicing fluid comprising a scale inhibitor, a surfactant, and an aqueous fluid comprising sulfate in an amount of from about 100 ppm to about 10,000 ppm based on the total weight of the aqueous fluid. The wellbore servicing fluid can be used as a fracturing fluid in a method of servicing a wellbore penetrating a subterranean formation. The wellbore servicing fluid can mitigate the formation of scales, prevent water blockage, and increase hydrocarbon production.