A method of sealing a formation that includes drilling a wellbore through the formation while pumping a non-aqueous based wellbore fluid comprising a first sealing component into the wellbore, wherein the non-aqueous based wellbore fluid filters into the formation as a filtrate and substantially thickens is disclosed. The substantially thickening may result from adding a second sealing component to the wellbore fluid, whereby the first sealing component initiates a reaction of the second sealing component.

A nonvolatile cold modified asphalt binder and a nonvolatile cold recycled asphalt mixture using the same are manufactured by optimally mixing a petroleum asphalt, a native asphalt, a polymer modifier, process oil, and an adhesive strength enhancer. The nonvolatile cold modified asphalt binder includes at least one petroleum asphalt selected from a straight asphalt or a blown asphalt; at least one native asphalt selected from gilsonite, glance pitch, and grahamite; a rubber-modified-compound (RMC) polymer modifier which is a vinyl aromatic hydrocarbon-conjugated diene block copolymer including at least one of a styrene-butadiene block copolymer (SBS), a styrene-isoprene block copolymer (SIS), and a styrene-ethylene-butylene block copolymer (SEBS); at least one process oil selected from paraffin oil, naphthenic oil, aromatic oil, natural oil, and mineral oil; and at least one adhesive strength enhancer selected from rosin esters, modified acryls, modified silicones, polyvinyl esters, and silicone resins.

A nonvolatile cold modified asphalt binder and a nonvolatile cold recycled asphalt mixture using the same are manufactured by optimally mixing a petroleum asphalt, a native asphalt, a polymer modifier, process oil, and an adhesive strength enhancer. The nonvolatile cold modified asphalt binder includes at least one petroleum asphalt selected from a straight asphalt or a blown asphalt; at least one native asphalt selected from gilsonite, glance pitch, and grahamite; a rubber-modified-compound (RMC) polymer modifier which is a vinyl aromatic hydrocarbon-conjugated diene block copolymer including at least one of a styrene-butadiene block copolymer (SBS), a styrene-isoprene block copolymer (SIS), and a styrene-ethylene-butylene block copolymer (SEBS); at least one process oil selected from paraffin oil, naphthenic oil, aromatic oil, natural oil, and mineral oil; and at least one adhesive strength enhancer selected from rosin esters, modified acryls, modified silicones, polyvinyl esters, and silicone resins.

A fines-fixing agent that has improved compatibility with organic complexed borate fracturing fluids is disclosed. Existing fines fixing agents have a high concentration of unreacted caustic that results in a product pH of approximately 12. This high pH affects the crosslinker and the overall fracturing fluid system stability, promoting precipitation of the organic crosslinker. These effects can be mitigated by neutralizing the fines fixing agents with an acid such as hydrochloric or acetic acid to a pH of 6 or lower.

A fines-fixing agent that has improved compatibility with organic complexed borate fracturing fluids is disclosed. Existing fines fixing agents have a high concentration of unreacted caustic that results in a product pH of approximately 12. This high pH affects the crosslinker and the overall fracturing fluid system stability, promoting precipitation of the organic crosslinker. These effects can be mitigated by neutralizing the fines fixing agents with an acid such as hydrochloric or acetic acid to a pH of 6 or lower.

A composite for controlling the release of a well treatment agent or for inhibiting or preventing the formation of contaminants into a fluid or a surface within a reservoir contains a well treatment agent immobilized on a surface of the support or into the pores of a porous support. The composite is at least partially coated with an organic polymer or inorganic material. The composite exhibits sufficient strength for the composite to be used as a proppant or in conjunction with a proppant.

A polymerizable chemical system for consolidating particulates in a subterranean formation including a liquid resin, a curing agent, and a permeability enhancing additive. The chemical system is a homogenous composition that polymerizes to forms a solid upon heating at a temperature greater than 60 C. Consolidating particulates in a subterranean formation includes providing a polymerizable chemical system comprising a liquid resin, a curing agent, and a permeability enhancing additive to a subterranean formation, and polymerizing the polymerizable chemical system to consolidate particulates in the formation to yield a porous consolidated particulates pack.

A polymerizable chemical system for consolidating particulates in a subterranean formation including a liquid resin, a curing agent, and a permeability enhancing additive. The chemical system is a homogenous composition that polymerizes to forms a solid upon heating at a temperature greater than 60 C. Consolidating particulates in a subterranean formation includes providing a polymerizable chemical system comprising a liquid resin, a curing agent, and a permeability enhancing additive to a subterranean formation, and polymerizing the polymerizable chemical system to consolidate particulates in the formation to yield a porous consolidated particulates pack.

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 well treatment composition for use in a hydrocarbon-bearing reservoir comprising a reversible aminal gel composition is disclosed. The reversible aminal gel composition includes a liquid precursor composition. The liquid precursor composition is operable to remain in a liquid state at about room temperature. The liquid precursor composition comprises an organic amine composition; an aldehyde composition; and a polar aprotic organic solvent. The liquid precursor composition transitions from the liquid state to a gel state responsive to an increase in temperature in the hydrocarbon-bearing reservoir. The gel state is stable in the hydrocarbon-bearing reservoir at a temperature similar to a temperature of the hydrocarbon-bearing reservoir, and the gel state is operable to return to the liquid state responsive to a change in the hydrocarbon-bearing reservoir selected from the group consisting of: a decrease in pH in the hydrocarbon-bearing reservoir and an addition of excess metal salt composition in the hydrocarbon-bearing reservoir.