Methods for treating a formation may include introducing components of a treatment solution into a wellbore such that the treatment solution contacts the formation to be treated, where the treatment solution may include urea, urease, a calcium ion source, one or more polysaccharides, a casein protein, a protease, an ionic compound, and a sugar, where the formation may have an amount of sand production before treatment and may be in fluid contact with the wellbore, and where an amount of sand production after treatment may be less than the amount of sand production before treatment. Consolidated sand structure compositions may include previously unconsolidated sand interlinked by inter-particle cementitious bonds comprising deposited calcium carbonate crystals, where the consolidated sand has a structural strength and the consolidated sand structure is porous to permit fluid flow through the composition.

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 water blocking and silt migration of the unconsolidated siltstone gas reservoir, and then closing a well for a preset time before exploitation.

Release of hydrochloric acid, hydrofluoric acid and fluoroboric acid into a well may be controlled by introducing into the well an aqueous fluid containing ammonium chloride, ammonium bifluoride, ammonium fluoroborate, ammonium tetrafluoroborate or a mixture thereof and a breaker. After being introduced into the well, the ammonium salt reacts with the breaker and the acid is released into the well.

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.

The embodiments described herein generally relate to methods and chemical compositions for coating substrates with a composition. In one embodiment, an adhesive composition is provided comprising a reaction product of a polyacid selected from the group consisting of an aromatic polyacid, an aliphatic polyacid, an aliphatic polyacid with an aromatic group, and combinations thereof, or a diglycidyl ether; and a polyamine; and one or more compounds selected from the group consisting of a branched aliphatic acid, a cyclic aliphatic acid with a cyclic aliphatic group, a linear aliphatic, and combinations thereof. The adhesive composition may be used to cover a substrate.

Methods including providing a silane composition selected from the group consisting of a dipodal silane, a long-chain silane, and any combination thereof, wherein the dipodal silane includes at least two carbon chains having between about 2 and about 36 carbon atoms, and wherein the long-chain silane includes at least one carbon chain having between about 2 and about 36 carbon atoms; coating proppant particulates with the silane composition, thereby forming silane composition coated proppant particulates; and introducing the silane composition coated proppant particulates into at least one fracture in a subterranean formation, thereby stabilizing loose particulates therein.

A method of breaking the viscosity of a treatment fluid comprises: adding hydrophobic nanoparticles to a treatment fluid comprising a base fluid and a viscoelastic surfactant gelling agent, the hydrophobic nanoparticles comprising metallic nanoparticles that are surface modified with C.sub.6-30 aliphatic groups, wherein the hydrophobic nanoparticles are added in an amount effective to decrease the viscosity of the treatment fluid as compared to a treatment fluid absent the hydrophobic nanoparticles.

A solids-control fluid for controlling flow of solids in a subterranean formation is disclosed herein. The solids-control fluid can include a diluent and a curable resin. The diluent can include a mutual solvent and an ethylene glycol. The curable resin can be dispersed within the diluent for controlling flow of solids in the subterranean formation.

Well fluids and methods are provided that can be used for stabilizing a shale formation, especially during drilling of a well into or through a shale formation. The well fluids include: (i) a continuous water phase; (ii) a viscosity-increasing agent, wherein the viscosity-increasing agent comprises water-soluble hydrophilic polymer; (iii) a fluid loss control agent; and (iv) a cyclodextrin-based compound. The methods of drilling include the steps of: (A) introducing the well fluid into a zone of a subterranean formation; and (b) drilling the zone.

A method of treating a subterranean formation including providing a treatment fluid comprising a hardenable acid curable resin and a hydrolysable strong acid ester. The treatment fluid is combined with a diluent fluid and is introduced into a subterranean formation. Upon the hydrolyzing of the ester in the formation and the contacting of unconsolidated proppants, the treatment method produces consolidated proppants.