A method of treating a subterranean formation comprises forming a storable aqueous suspension comprising a carrier fluid, a superabsorbent polymer, a proppant the proppant being suspended in the carrier fluid as a substantially perfectly supported particulate; diluting the storable aqueous suspension in-line to a desired concentration; and introducing the diluted storable aqueous suspension into the subterranean formation. A sand control method is also disclosed.

A resin-clay composition includes a first mixture including an epoxy resin and a nano-clay; and a curing agent added to the first mixture to produce a second mixture, wherein a presence of the nano-clay causes a change in curing time of the epoxy resin. The second mixture may be added into a hydrocarbon well for aggregating particulate matter. A percentage of the epoxy resin in the second mixture may include a range of about 10 to about 90 percent. A percentage of the clay in the second mixture may include a range of about 0 to about 20 percent, and wherein a percentage of the curing agent in the second mixture may include a range of about 10 to about 90 percent. The epoxy resin may include Diglycidyl ether of Bisphenol A epoxy resin.

Methods of preventing or minimizing communication between adjacent wells are described. The methods include providing a pre-pad fluid, pad fluid, and/or slurry including a material, introducing the pre-pad fluid, pad fluid, and/or slurry and material into a first well adjacent a second well, allowing the material to block fractures in the first well to prevent or minimize communication between the first well and the second well, stimulating the second well after blocking the fractures, and recovering a formation fluid from the first well, the second well, or both. The material includes one or more of a conformance chemical, diverting agent, or a combination thereof.

Provided are consolidation treatment methods and systems. A consolidation treatment method may comprise introducing a permeability modifier into a subterranean formation comprising zones of heterogeneous permeability; introducing a treatment fluid into the subterranean formation subsequent to the permeability modifier, wherein the permeability modifier at least partially diverts the treatment fluid in the subterranean formation such that treatment of the subterranean formation with the treatment fluid is more uniform, and wherein the permeability modifier has a higher viscosity than the treatment fluid; and consolidating one or more zones of the subterranean formation.

Methods including introducing a low-polymer loading treatment fluid (LPLTF) into a subterranean formation for performing a subterranean formation operation at a target interval. The LPLTF comprises an aqueous-based fluid, a guar-based gelling agent in an amount of less than about 2.4 grams/liter of the liquid portion of the LPLTF, and a dual crosslinking additive comprising a metal crosslinker and a multifunctional boronic acid crosslinker in a ratio in the range of about 1:100 to about 100:1.

A method of treating a subterranean formation including combining a long chain hydrocarbon viscosifier, an ene curing agent, and a thiol crosslinking agent to form a resin compound; coating the resin compound onto at least a portion of proppant particles to create resin-coated proppant particles; and placing the coated proppant particles into the subterranean formation zone, wherein the resin compound does not substantially cure prior to placing the resin coated proppant particles into the subterranean formation zone.

Consolidation compositions comprising a multipodal silane coupling agent comprising at least two silane groups and at least one amino group; a curable resin; and a resin hardening agent. The curable resin is selected from the group consisting of an epoxy resin, an aliphatic epoxy resin, a glycidylamine epoxy resin, and combinations thereof.

A method of drilling a wellbore in a subterranean formation comprises circulating a water-based or oil-based drilling fluid in the subterranean formation; the water-based or oil-based drilling fluid comprising a carrier, and a superabsorbent polymer present in an amount effective to reduce fluid leakoff during the drilling operation, the superabsorbent polymer comprising crosslinks formed before the superabsorbent polymer is combined with the carrier.

Aggregating composition including oligomers and/or polymeric comprising amine containing repeat units, non-amine containing groups units, ammonium containing repeat units, amine oxide containing repeat units, or mixtures and combinations thereof, where relative amounts of the amine containing repeat units, the non-amine containing groups units, the ammonium containing repeat units, and the amine oxide containing repeat units and/or the relative amount of the oligomers and/or polymers are tailored to the exact requirements of the formation, zone, particles and/or structure to be treated and where the composition forms partial, substantially complete, and/or complete coatings on the particles, surfaces and/or materials altering their self-aggregating properties and/or aggregation propensities and/or zeta potentials and methods for making and using the compositions.

Treating fluid compositions for use in hydrocarbon recovery operations from subterranean formations are described, as well as methods for their preparation and use. In particular, treating fluid compositions are described which comprise a liquid, a crosslinkable organic polymer material that is at least partially soluble in the liquid, a crosslinking agent that is capable of increasing the viscosity of the treating fluid by crosslinking the organic polymer material in the liquid, and a crosslinking modifier additive which can delay or accelerate the crosslinking of the treating fluid composition. Such compositions may be used in a variety of hydrocarbon recovery operations including fracturing operations, drilling operations, gravel packing operations, water control operations, and the like.