Treatment fluids for acid diversion during acid stimulation of a subterranean formation may include at least an acidizing fluid, a nanoparticle dispersion, and an activator. The treatment fluid may include from 40 weight percent to 70 weight percent acidizing fluid based on the total weight of the treatment fluid. The treatment fluid may include from 20 weight percent to 40 weight percent nanoparticle dispersion based on the total weight of the treatment fluid. The treatment fluid may include from 5 weight percent to 15 percent activator based on the total weight of the treatment fluid. Methods of treating a subterranean formation with the treatment fluids are also disclosed.

Methods of acidizing a subterranean formation penetrated by a wellbore that include the steps of (a) injecting into the wellbore at a pressure below subterranean formation fracturing pressure a treatment fluid having a first viscosity and including an aqueous acid and a gelling agent selected from the group consisting of Formulas I-XI and combinations thereof; (b) forming at least one void in the subterranean formation with the treatment fluid; and (c) allowing the treatment fluid to attain a second viscosity that is greater than the first viscosity.

Methods of acidizing a subterranean formation penetrated by a wellbore that include the steps of (a) injecting into the wellbore at a pressure below subterranean formation fracturing pressure a treatment fluid having a first viscosity and including an aqueous acid and a gelling agent selected from the group consisting of Formulas I-XI and combinations thereof; (b) forming at least one void in the subterranean formation with the treatment fluid; and (c) allowing the treatment fluid to attain a second viscosity that is greater than the first viscosity.

Methods of acidizing a subterranean formation penetrated by a wellbore that include the steps of (a) injecting into the wellbore at a pressure below subterranean formation fracturing pressure a treatment fluid having a first viscosity and including an aqueous acid and a gelling agent selected from the group consisting of Formulas I-XI and combinations thereof; (b) forming at least one void in the subterranean formation with the treatment fluid; and (c) allowing the treatment fluid to attain a second viscosity that is greater than the first viscosity.

Methods of acidizing a subterranean formation penetrated by a wellbore that include the steps of (a) injecting into the wellbore at a pressure below subterranean formation fracturing pressure a treatment fluid having a first viscosity and including an aqueous acid and a gelling agent selected from the group consisting of Formulas I-XI and combinations thereof; (b) forming at least one void in the subterranean formation with the treatment fluid; and (c) allowing the treatment fluid to attain a second viscosity that is greater than the first viscosity.

Reducing leak-off during acid stimulation with dissolvable material sized to preferentially block crevices and wormholes, thus allowing the acid to travel further down the fractures, etching deeper into the reservoir than a similar process not using such dissolvable materials. After stimulation, the materials dissolve and production can proceed and will be improved over what is possible without such dissolvable materials.

Reducing leak-off during acid stimulation with dissolvable material sized to preferentially block crevices and wormholes, thus allowing the acid to travel further down the fractures, etching deeper into the reservoir than a similar process not using such dissolvable materials. After stimulation, the materials dissolve and production can proceed and will be improved over what is possible without such dissolvable materials.

Certain foamed gel treatment fluids and methods of using the treatment fluids in wellbores penetrating subterranean formations are provided. In one embodiment, the treatment fluids comprise: an aqueous base fluid, a gas, a plurality of particulates, and a plurality of swellable particles each comprising a material having a first monomer, a second monomer, and a third monomer comprising a foamable surfactant. In one embodiment, the methods comprise: preparing a treatment fluid comprising an aqueous base fluid and a swellable particle that comprises a material having a first monomer, a second monomer, and a third monomer comprising a foamable surfactant; introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation; and blending the treatment fluid while in the wellbore to form a foamed gel.

Disclosed herein arc compositions and methods for reducing fluid loss in a well bore. This invention relates to methods for wellbore strengthening and increasing the integrity of the borehole of an oil or gas well. In particular, the invention relates to methods for artificially increasing the temperature of a subsurface formation in the wellbore to increase the apparent wellbore strength. The mechanism for accomplishing this revolves around increasing fracture propagation pressure by actively manipulating thermal wellbore stresses.

Disclosed herein arc compositions and methods for reducing fluid loss in a well bore. This invention relates to methods for wellbore strengthening and increasing the integrity of the borehole of an oil or gas well. In particular, the invention relates to methods for artificially increasing the temperature of a subsurface formation in the wellbore to increase the apparent wellbore strength. The mechanism for accomplishing this revolves around increasing fracture propagation pressure by actively manipulating thermal wellbore stresses.