Resin coatings are frequently formed in conjunction with performing a subterranean treatment operation. However, poor thermal conductivity and mechanical strength of resin coatings can be problematic in a downhole environment and eventually lead to their breakdown. Methods for enhancing a resin coating in a downhole environment can comprise: introducing a treatment fluid comprising a curable resin and a carbon nanomaterial into a wellbore penetrating a subterranean formation; forming a coating of the curable resin on a surface in the wellbore, the carbon nanomaterial being dispersed throughout the coating; and curing the curable resin to form a cured resin coating.

A ternary water control and gas recovery method suitable for an unconsolidated siltstone gas reservoir is provided. It includes the following steps: first, running a silt control screen pipe manufactured by an interface hydrophobic modification into a wellbore to realize wellbore water control and silt control; second, filling a surface hydrophobic modified gravel in an annular space between the silt control screen pipe and the wellbore to form a hydrophobic gravel packing layer for water control and silt control; third, injecting a wetting agent aqueous solution into a stratum, and performing a hydrophobic modification on a gas reservoir seepage channel surface to realize in-situ waterblocking and silt migration of the unconsolidated siltstone gas reservoir, and then closing a well for a preset time before exploitation.

A process for chemically removing cured resin product from subterranean formations in case of inappropriate consolidation, plugging of screens or tubing, and equipment damage. A chemical solvent is introduced to a wellbore where a resin has cured. The resin is contacted with the chemical solvent until the resin at least partially dissolves. The dissolved resin is then removed from the wellbore. The process may also be used to remove consolidated packs consisting of cured resin and particulate materials.

Methods of treating a subterranean formation are disclosed that include introducing a treatment fluid including thermally shrinkable fibers and a particulate material into a subterranean formation via a wellbore, adjusting at least one parameter of the treatment fluid to trigger the association of the thermally shrinkable fibers, and forming a porous pack including a network of shrunken fibers by applying heat sufficient to raise the temperature of the thermally shrinkable fibers to a temperature at or above a shrinking initiation temperature of the thermally shrinkable fibers.

An object of the present invention is to provide a salt water thickener that uniformly (favorably) disperses ultrafine cellulose fibers even in a liquid containing a salt (electrolyte). The salt water thickener comprises ultrafine cellulose fibers and a water-soluble polymer and can thereby uniformly disperse the ultrafine cellulose fibers even in a liquid containing a salt. The salt water thickener of the present invention is uniformly dispersed even in a liquid containing a salt and therefore exerts a high viscosity. The salt water thickener of the present invention can also be used as an additive for a fluid. The salt water thickener of the present invention can be used for purposes, for example, subterranean formation processing.

The present invention relates to compositions and methods for reducing or preventing the loss of drilling fluids and other well servicing fluids into a subterranean formation during drilling or construction of boreholes in said formation. Specifically, this invention comprises a curable thermosetting composition comprising a polyfunctional (meth)acrylate, a polyfunctional (meth)acrylamide, or mixture thereof, one or more epoxy resin, and one or more (cyclo)aliphatic polyamine.

A wellbore servicing composition comprising a base fluid, the base fluid comprising a substantially aqueous fluid, a brine, an emulsion, an invert emulsion, an oleaginous fluid, or combinations thereof, a quantity of template assisted crystallization beads, and a wellbore servicing fluid component, the wellbore servicing fluid component comprising a quantity of proppant, a quantity of gravel, or combinations thereof. A wellbore servicing system comprising a flowpath, the flowpath comprising at least one component of wellbore servicing equipment, and a conduit extending from the at least one component of wellbore servicing equipment to a wellbore, and a wellbore servicing fluid disposed within the flowpath, wherein the wellbore servicing fluid comprises a plurality of template assisted crystallization beads. A wellbore servicing method comprising forming a wellbore servicing fluid comprising a quantity of template assisted crystallization beads, and introducing the wellbore servicing fluid into a wellbore, a subterranean formation, or combinations thereof.

A method of treating a subterranean shale formation includes placing a first treatment fluid comprising a fracturing fluid in the formation; forming fractures; placing a second fluid including a sloughing agent or eroding agent in the formation; allowing gaps in the fracture faces to form; placing a third fluid including a formation stabilizer and an agglomerating agent into the fractures; and allowing the third fluid to absorb into the formation, thereby stabilizing the shale formation fracture faces and transforming the solid shale particulates into proppant clusters.

A method of servicing a wellbore in a subterranean formation comprising placing in the wellbore and/or subterranean formation a pad fluid and forming a fracture in the subterranean formation. Next, a first slurry fluid may be placed into the fracture in the subterranean formation. The first slurry fluid may comprise a reducible material and a first particulate material. Next, a second slurry fluid and a spacer fluid may be placed into the fracture in the subterranean formation in an alternating sequence. The second slurry fluid may comprise a second particulate material. Then, the fracture is allowed to close and the fluids are allowed to break. Finally, the reducible materials degrade, to form a particulate-laden proppant pack (PLPP).

The stability of subterranean, laminated, carbonate-containing formations that have strongly hydrophilic-wet surfaces is improved by introducing into the formation an aqueous fluid having dispersed therein relative permeability modifiers (RPMs). The RPMs are designed to enter the fractures and gaps between the layers in the formation and alter their surface wettability to inhibit water from further entering into the shale rock, thereby improving stability.