This disclosure relates to a method of fabricating a multivalent iron bio-inhibitor from waste bauxite residue and methods of controlling reservoir souring using the multivalent iron bio-inhibitor.

This invention relates to a composition comprising 1.) a metal carboxylate, wherein the metal M is selected from the group consisting of Ag, Cn, Hg, Pb, Sn, Ni, Co, Ca, Fe, Zn and Mn, those metals being present as ions in a +2 or +3 charge state, and wherein the carboxylate anion is derived from a hydrocarbyl monocarboxylic acid having 5 to 20 carbon atoms, or a mixture of such acids, 2.) a solvent selected from the group consisting of water, glycol ethers having from 4 to 15 carbon atoms, alkyl alcohols having from 1 to 10 carbons, and aromatic hydrocarbon solvents having from 6 to 30 carbons, and 3.) an emulsion breaker which is a polymeric nonionic surfactant.

The present invention provides compositions and methods for reducing hydrogen sulfide and/or mercaptans in oil and/or natural gas as well as for reducing microbial induced corrosion (“MIC”) in oil and gas production environments. In particular, the subject invention provides environmentally-friendly compositions and methods for reducing hydrogen sulfide in oil and natural gas environments by controlling biocorrosive bacteria, such as SRB, therein.

Amorphous Dithiazine Dissolution Formulation and Method for using the Same The invention relates a use of an aqueous composition comprising at least one organic peroxide to dissolve amorphous dithiazine.

A polymer composition may include one or more monomeric units, with an internal crosslinker, internal breaker, scale control additive or a combination thereof.

Dissolving iron sulfide on the carbon steel tubing to yield chelated iron is achieved by treating the carbon steel tubing with a composition including an iron chelant and an additive. The additive includes at least one of an oxidizing agent and a base. A weight ratio of the iron chelant to the additive is in a weight range of 50:1 to 5:1.

According to one aspect of the invention, a method of converting an oxy halide salt into a halide dioxide in a reaction zone under certain conditions is provided. More specifically, the method includes generating chlorine dioxide from a stable composition comprising an oxy halide salt by introducing said composition to a reducing agent and minimum temperature within the reaction zone. According to another aspect of the invention, a composition for a stable chlorine dioxide precursor comprising an oxy halide salt is provided.

Ceramic foundry media is provided. The ceramic foundry media have a size of about 80 mesh to about 10 mesh, an average largest pore size of less than about 20 microns, and a surface roughness of less than about 4 microns. The ceramic foundry media are formed by drip casting. A slurry of finely divided particles is flowed through nozzles and formed into droplets under the influence of vibration. Uniform sized, smooth surface, spherical green particles are formed. The green particles are dried and sintered to form the foundry media.

Proppant compositions and methods for using same are disclosed herein. In particular, a proppant composition for use in hydraulic fracturing is disclosed herein. The proppant composition can contain a plurality of particulates and at least one particulate of the plurality of particulates containing a chemical treatment agent. The at least one particulate having a long term permeability measured in accordance with ISO 13503-5 at 7,500 psi of at least about 10 D. The at least one chemical treatment agent can separate from the at least one particulate when located inside a fracture of a subterranean formation after a period of time.

Methods of acidizing a subterranean formation penetrated by a wellbore that include the steps of (a) injecting into the wellbore at a pressure below subterranean formation fracturing pressure a treatment fluid having a first viscosity and including an aqueous acid and a gelling agent selected from the group consisting of Formulas I-XI and combinations thereof; (b) forming at least one void in the subterranean formation with the treatment fluid; and (c) allowing the treatment fluid to attain a second viscosity that is greater than the first viscosity.