A method for reducing lost circulation in a subterranean formation. The method includes providing a treatment fluid comprising a base fluid and a lost circulation material comprising cane ash. The treatment fluid is introduced into a wellbore within the subterranean formation such that at least a portion of the cane ash bridges openings in the subterranean formation to reduce loss of fluid circulation into the subterranean formation.

A method for reducing lost circulation in a subterranean formation. The method includes providing a treatment fluid comprising a base fluid and a lost circulation material comprising brown mud. The treatment fluid is introduced into a wellbore within the subterranean formation such that at least a portion of the brown mud bridges openings in the subterranean formation to reduce loss of fluid circulation into the subterranean formation.

A method of using a wellbore isolation device comprises: introducing the wellbore isolation device into the wellbore, wherein the isolation device comprises: (A) a matrix, wherein the matrix has a phase transition temperature less than or equal to the bottomhole temperature of the wellbore; and (B) at least one reinforcement area, wherein the reinforcement area: (i) comprises at least a first material, wherein the first material undergoes galvanic corrosion; and (ii) has a greater tensile strength and/or shear strength than the matrix.

Methods may include defining operational parameters for an initial composition design; generating an initial composition design from the defined operational parameters; predicting the performance of the initial composition design using a statistical model; comparing the performance of the initial composition design with the operational parameters; optimizing the initial composition design according to the defined operational parameters; and outputting a final composition design. Methods may also include defining operational parameters for an initial composition design for a wellbore fluid; generating an initial composition design from the defined operational parameters; predicting the performance of the initial composition design using a statistical model; comparing the performance of the initial composition design with the operational parameters; optimizing the initial composition design according to the defined operational parameters; and outputting a final composition design.

Embodiments relate to use of graphite nanoplatelets (GnP) to enhance the mechanical and durability characteristics of cement that may be used as cement sheaths in wellbores of oil and gas wells. Generally, undesired permeability of cement is caused by diffusion of trapped oil and/or natural gas through the cementitious matrix of the cement, leading to material degradation of the cement. Methods disclosed involve using modified GnPs (having physically modified surfaces or chemically modified surfaces energies) to generate a cementitious nanocomposite with uniformly dispersed GnPs, which can effectively arrest the undesired diffusion mechanism. Modified GnPs can also increase the strength of interfacial adhesion (e.g., interfacial bonds and interfacial energies) between the GnP and the cement matrix (e.g., hydrations of the cement). Physical modification of GnP can involve non-covalent treatment techniques. Chemical modification of GnP can involve covalent treatment techniques.

Provided is a frac plug or the like capable of being inserted into a borehole to seal the borehole with high strength, and then quickly disassembled and removed, thereby efficiently producing petroleum. A frac plug according to the present embodiment has a member made of a magnesium (Mg) alloy. The member has a multi-phase structure including a first phase, which is a matrix phase, and a second phase present in the first phase. In the multi-phase structure, the second phase is distributed in a substantially striped pattern in the first phase in a first cross section perpendicular to a second direction of the frac plug, and distributed in a substantially mesh-like pattern in the first phase in a second cross section perpendicular to a first direction of the frac plug.

Gelled fluids include a gellable organic solvent, an aluminum crosslinking compound, and a mutual solvent. The gelled fluids may be prepared by combining an aluminum crosslinking compound and a first volume of a gellable organic solvent to form a pre-solvation mixture; gelling the pre-solvation mixture to form a pre-solvated gel; combining the pre-solvated gel with a formulation fluid to form a gellable mixture, the formulation fluid comprising a second volume of the gellable organic solvent; and gelling the gellable mixture to form the gelled fluid.

The effectiveness of expansive cement systems may be diluted when, during a well cementing operation, commingling takes place between the cement slurry and a spacer fluid, a drilling fluid, or both. Incorporating expansive agents in the spacer fluid or drilling fluid may reduce or negate the loss of expansion at the cement slurry/spacer interface or the cement slurry/drilling fluid interface, thereby promoting zonal isolation throughout the cemented interval.

A method for plugging a lost-circulation zone in a subsurface formation includes introducing a drillstem including a drilling stabilizer into a wellbore during drilling operations, the drilling stabilizer including at least stabilizer blades and a pressure sensor. Each stabilizer blade includes at least an inner chamber, a light source, and a window. The method further includes injecting a lost-circulation fluid, including a plurality of lost-circulation particles, into the wellbore. Each lost-circulation particle includes a lost-circulation additive encapsulated by a photo-sensitive coating. The method further includes measuring a pressure differential with the pressure sensor and providing a pressure signal to the light source of each stabilizer blade, thereby actuating the light source to produce a light beam, which allows the light beam to contact the photo-sensitive coatings of the lost-circulation particles to release the lost-circulation additives. The method further includes allowing the lost-circulation fluid to plug the lost-circulation zone.

A method of treating a formation, a wellbore, or equipment in a wellbore is disclosed herein. The method includes introducing a soluble abrasive material into a wellbore for various oil and gas operations. The method also includes introducing an acidic solution into the wellbore to dissolve at least a portion of the soluble abrasive material to allow for more efficient removal of the soluble abrasive material from the wellbore.