The present disclosure relates to systems and methods for using aldehydes as a catalyst for oxidative breakers. An embodiment of the present disclosure is a method comprising: providing a treatment fluid that comprises: an aqueous base fluid, a polymeric gelling agent, a breaker that comprises an oxidative salt, and a catalyst that comprises an aldehyde; allowing the breaker to interact with the polymeric gelling agent; and allowing the viscosity of the treatment fluid to reduce.

Compositions for stimulating hydrocarbon production from a subterranean formation are generally disclosed. In some embodiments, such compositions include olefinic ester compounds, such as alkyl esters of C10-18 unsaturated fatty acids. In some embodiments, the olefinic ester compounds are derived from a natural oil or a natural oil derivative, for example, by catalytic olefin metathesis. Uses of such compounds, such as in oil- and gas-production methods are also generally disclosed.

Compositions for stimulating hydrocarbon production from a subterranean formation are generally disclosed. In some embodiments, such compositions include olefinic ester compounds, such as alkyl esters of C10-18 unsaturated fatty acids. In some embodiments, the olefinic ester compounds are derived from a natural oil or a natural oil derivative, for example, by catalytic olefin metathesis. Uses of such compounds, such as in oil- and gas-production methods are also generally disclosed.

Polyacrylamide (PAM)-coated nanosand that may be a relative permeability modifier (RPM) and that is applied to treat a wellbore in a subterranean formation. The treatment may be for excess water production. The PAM-coated nanosand is PAM-hydrogel-coated nanosand. The PAM-coated nanosand os nanosand coated with PAM hydrogel. The PAM hydrogel includes crosslinked PAM in water. Application of the PAM-coated nanosand may reduce water production from the subterranean formation into the wellbore. The PAM hydrogel of the PAM-coated nanosand may expand in a water zone of the subterranean formation to restrict water flow into the wellbore. The PAM hydrogel of the PAM-coated nanosand may contract in an oil zone of the subterranean formation so not to significantly restrict crude oil flow into the wellbore.

Polyacrylamide (PAM)-coated nanosand that may be a relative permeability modifier (RPM) and that is applied to treat a wellbore in a subterranean formation. The treatment may be for excess water production. The PAM-coated nanosand is PAM-hydrogel-coated nanosand. The PAM-coated nanosand os nanosand coated with PAM hydrogel. The PAM hydrogel includes crosslinked PAM in water. Application of the PAM-coated nanosand may reduce water production from the subterranean formation into the wellbore. The PAM hydrogel of the PAM-coated nanosand may expand in a water zone of the subterranean formation to restrict water flow into the wellbore. The PAM hydrogel of the PAM-coated nanosand may contract in an oil zone of the subterranean formation so not to significantly restrict crude oil flow into the wellbore.

Disclosed herein is a nanoparticle modified fluid that includes nanoparticles that are surface modified to increase a viscosity of the nanoparticle modified fluid and that have at least one dimension that is less than or equal to about 50 nanometers; nanoparticles that are surface modified to increase a viscosity of the nanoparticle modified fluid and that have at least one dimension that is less than or equal to about 70 nanometers; and a liquid carrier; wherein the nanoparticle modified fluid exhibits a viscosity above that of a comparative nanoparticle modified fluid that contains the same nanoparticles but whose surfaces are not modified, when both nanoparticle modified fluids are tested at the same shear rate and temperature.

The instant invention relates to a method for sealing a subterranean environment, wherein a polyurethane encapsulated polyamine is injected into the subterranean environment and is released in situ in the presence of a reactive species able to form a gel or a precipitate by a physical association and/or a chemical reaction with the released polyamine.

A hydraulic fracturing composition includes: a superabsorbent polymer in an expanded state; a plurality of proppant particles disposed in the superabsorbent polymer; a well treatment agent, and a fluid to expand the superabsorbent polymer into the expanded state. A process for treating a well with well treatment agent includes disposing a hydraulic fracturing composition comprising the well treatment agent in a well. The well treatment agent can be a scale inhibitor, tracer, pH buffering agent, or a combination thereof.

A hydraulic fracturing composition includes: a superabsorbent polymer in an expanded state; a plurality of proppant particles disposed in the superabsorbent polymer; a well treatment agent, and a fluid to expand the superabsorbent polymer into the expanded state. A process for treating a well with well treatment agent includes disposing a hydraulic fracturing composition comprising the well treatment agent in a well. The well treatment agent can be a scale inhibitor, tracer, pH buffering agent, or a combination thereof.

A system for slowly releasing an oil-soluble well treatment agent into a well or a subterranean formation includes a composite of the oil-soluble well treatment agent associated with a second component. The amount of the oil-soluble well treatment agent in the composite is from 20 to 35 weight percent and the average particle size of the oil-soluble well treatment agent in the composite is less than or equal to 1 micrometer. The composite may further contain a water-soluble well treatment agent.