The invention relates to synthetic nanocompounds in the form of microparticles that allow major deformations before breaking and are especially useful for preparing low-density synthetic propping agents to be used in non-conventional oil and gas extraction processes (fracking). The invention also describes the process for obtaining said nanocompounds, propping agents and fracturing fluids for oil and gas extraction processes.

A synthetic acid composition for use in oil industry activities, said composition comprising: urea and hydrogen chloride in a molar ratio of not less than 0.1:1; cinnamaldehyde or a derivative thereof; optionally, it may further comprise a phosphonic acid derivative; as well as a metal iodide or iodate; and an alcohol or derivative thereof.

A treatment composition for use in treating production fluids in or from a subterranean formation is provided. The treatment composition can be used for viscosity control in subsea umbilical fluid delivery applications, wherein the treatment composition exhibits desirable viscosity, flash point and/or pour point values.

We disclose the use of an aliphatic tertiary amino functional compound to suppress H.sub.2S formation of a sulfur-based corrosion inhibitor during storage of the sulfur-based corrosion inhibitor in a substantially enclosed container. Thus, disclosed herein is a stabilized corrosion inhibitor composition comprising a sulfur-based corrosion inhibitor and an aliphatic tertiary amino functional compound. Also disclosed herein is a method of storing a corrosion inhibitor composition by combining a sulfur-based corrosion inhibitor and an aliphatic tertiary amino functional compound to form a stabilized corrosion inhibitor composition; and storing the stabilized corrosion inhibitor composition in a substantially enclosed container for a storage period, wherein substantially no H.sub.2S is formed within the container during the storage period.

Disclosed are methods for inhibiting the corrosion of metal containments such as carbon-steel pipes used in oil recovery processes, the methods comprising adding urine and/or compositions comprising urine to water sources to form corrosion inhibitor compositions, and contacting metal containments with the corrosion inhibitor compositions. The water sources are for example aqueous solutions that are corrosive to metal containments such as carbon-steel pipes. Compositions comprising urine that provide reduced corrosion or corrosion inhibition are also described. Metal containment assemblages comprising corrosion inhibitor compositions and a metal containment are also described.

Preparation of an aqueous chlorine dioxide solution that reaches a first chlorine dioxide concentration during a first time period, and reaches a terminal concentration thereafter. A dilute solution of aqueous sodium chlorite or chlorate with predetermined concentration is produced, which yields the terminal chlorine dioxide concentration once an acid activator is added. The dilute solution is transferred through a conduit into a sanitization zone. The acid activator is injected into the conduit at a rate and concentration selected to reach the first chlorine dioxide concentration at the end of the first time period, with a flow rate such that the activated dilute solution of aqueous sodium chlorite has passed through the conduit prior to reaching the first chlorine dioxide concentration, which thereby limits exposure of the conduit to levels less than the first chlorine dioxide concentration.

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.

Certain metal surfaces are often unable to be effectively contacted with fluids containing hydrofluoric acid due to significant corrosion issues. Titanium and titanium alloy surfaces represent but one example. Corrosion inhibitor compositions comprising boric acid and an N-(phosphonoalkyl)iminodiacetic acid or any salt thereof can be used to suppress metal corrosion, including that taking place on titanium and titanium alloy surfaces. Methods for suppressing corrosion of a metal surface can comprise: contacting a metal surface with a corrosive environment, the metal surface comprising titanium or a titanium alloy and the corrosive environment comprising hydrofluoric acid; introducing a corrosion inhibitor composition to the corrosive environment, the corrosion inhibitor composition comprising boric acid and an N-(phosphonoalkyl)iminodiacetic acid or any salt thereof; contacting the metal surface with the corrosion inhibitor composition; and allowing the corrosion inhibitor composition to suppress corrosion of the metal surface by the corrosive environment.

A composition including a coated nanoparticle and an ion, wherein the coated nanoparticle includes a nanoparticle, a linker, and a stabilizing group; methods of making and using the composition; and systems including the composition. The linker includes an anchoring group, a spacer, and a terminal group. The anchoring group is covalently bound to the nanoparticle and at least one of the terminal groups is covalently bound to at least one stabilizing group. A composition including a crosslinked-coated nanoparticle and an ion, wherein the crosslinked-coated nanoparticle includes a nanoparticle and a coating that includes a linker, a crosslinker, and a stabilizing group; methods of making and using the composition; and systems including the composition.

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.