The present disclosure relates to a system for removing a pollutant from a power generation cycle that utilizes a high pressure circulating fluid. The system includes a first direct contact cooling tower configured to cool the high pressure circulating fluid and condense a fluid stream that removes SO.sub.2 from the circulating fluid. A first recirculating pump fluidly communicates with the first direct contact cooling tower. The first tower includes an outlet configured to circulate a cooled CO.sub.2 product stream, and a second direct contact cooling tower is configured to receive at least a portion of the cooled CO.sub.2 product stream from the outlet. The second direct contact cooling tower is configured to cool the CO.sub.2 product stream and condense a fluid stream that removes NO.sub.x from the CO.sub.2 product stream. A second recirculating pump fluidly communicates with the second tower. An associated method is provided.

A flue-gas purification system includes a flue-gas cycling system, a reactor, and an absorbent adding system having at least a catalytic absorbent, wherein the catalytic absorbent is being gasified for reacting with the flue-gas in the reactor in a homogenous gas-gas phase reacting manner. Therefore, the purification system has fast reaction rate between the pollutants of the flue-gas and the catalytic absorbent, which is preferably ammonia, to efficiently remove pollutants, so as to effectively purify the flue-gas.

Integrated exhaust gas systems, methods, and processes are disclosed that includes pretreatment, treatment and post-treatment processes arranged in a variety of reaction environments to address varied application requirements and end product requirements is described in this disclosure. In addition, a contemplated ballast water treatment systemthat can be used in combination with the integrated exhaust gas systems can treat seawater and return it to storage within the vessel or send treated water back to the sea. This system can be sized to treat the seawater as it is leaving the ship without prior treatment, while the seawater is aboard or treat the seawater that is within the ship and add any additional treatment to the water, as the seawater leaves the ship. This system is not involved with pumping the seawater into the ship or filtering the water prior to storage as ballast water.

One aspect of the invention relates to a method comprising a single-stage conversion of an atmospheric pollutant, such as NO, NO.sub.2 and/or SO.sub.x in a first stream to one or more mineral acids and/or salts thereof by reacting with nonionic gas phase chlorine dioxide (ClO.sub.2.sup.0 ), wherein the reaction is carried out in the gas phase. Another aspect of the invention relates to a method comprising first adjusting the atmospheric pollutant concentrations in a first stream to a molar ratio of about 1:1, and then reacting with an aqueous metal hydroxide solution (MOH). Another aspect of the invention relates to an apparatus that can be used to carry out the methods disclosed herein. The methods disclosed herein are unexpectedly efficient and cost effective, and can be applied to a stream comprising high concentration and large volume of atmospheric pollutants.

An oxidizing composition for removing hydrogen sulfide (H.sub.2S) from a gaseous or liquid stream includes mixture products of water, sodium hypochlorite, a chelating agent, and a transition metal compound. The chelating agent can be etidronic acid; the transition metal compound can be an iron (III) compound, such as ferric sulfate. The oxidizing composition is formed by (i) combining water, chelating agent, and transition metal compound to form an activator composition and (ii) mixing the activator composition with a sodium hypochlorite solution to adjust the pH, such as for a particular use. Some embodiments include various apparatuses and methods for treating different treatment sites with the oxidizing compositions disclosed herein. Examples of suitable treatment sites include, without limitation, natural gas pipelines, bubble towers, oil wells, gas wells, sewer wet wells, air scrubbers, saltwater disposal pipelines, and saltwater disposal wells.

A plasma abatement process for abating effluent containing compounds from a processing chamber is described. A plasma abatement process takes gaseous foreline effluent from a processing chamber, such as a deposition chamber, and reacts the effluent within a plasma chamber placed in the foreline path. The plasma dissociates the compounds within the effluent, converting the effluent into more benign compounds. Abating reagents may assist in the abating of the compounds. The abatement process may be a volatizing or a condensing abatement process. Representative volatilizing abating reagents include, for example, CH.sub.4, H.sub.2O, H.sub.2, NF.sub.3, SF.sub.6, F.sub.2, HCl, HF, Cl.sub.2, and HBr. Representative condensing abating reagents include, for example, H.sub.2, H.sub.2O, O.sub.2, N.sub.2, O.sub.3, CO, CO.sub.2, NH.sub.3, N.sub.2O, CH.sub.4, and combinations thereof.

Certain exemplary embodiments can provide a system, machine, device, manufacture, circuit, composition of matter, and/or user interface adapted for and/or resulting from, and/or a method and/or machine-readable medium comprising machine-implementable instructions for, activities that can comprise and/or relate to, reacting reactants comprising a ferric/ferrous chelate and a sour gas stream.

A plasma abatement process for abating effluent containing compounds from a processing chamber is described. A plasma abatement process takes gaseous foreline effluent from a processing chamber, such as a deposition chamber, and reacts the effluent within a plasma chamber placed in the foreline path. The plasma dissociates the compounds within the effluent, converting the effluent into more benign compounds. Abating reagents may assist in the abating of the compounds. The abatement process may be a volatizing or a condensing abatement process. Representative volatilizing abating reagents include, for example, CH.sub.4, H.sub.2O, H.sub.2, NF.sub.3, SF.sub.6, F.sub.2, HCl, HF, Cl.sub.2, and HBr. Representative condensing abating reagents include, for example, H.sub.2, H.sub.2O, O.sub.2, N.sub.2, O.sub.3, CO, CO.sub.2, NH.sub.3, N.sub.2O, CH.sub.4, and combinations thereof.

The present disclosure relates to a system for removing a pollutant from a power generation cycle that utilizes a high pressure circulating fluid. The system includes a first direct contact cooling tower configured to cool the high pressure circulating fluid and condense a fluid stream that removes SO.sub.2 from the circulating fluid. A first recirculating pump fluidly communicates with the first direct contact cooling tower. The first tower includes an outlet configured to circulate a cooled CO.sub.2 product stream, and a second direct contact cooling tower is configured to receive at least a portion of the cooled CO.sub.2 product stream from the outlet. The second direct contact cooling tower is configured to cool the CO.sub.2 product stream and condense a fluid stream that removes NO.sub.x from the CO.sub.2 product stream. A second recirculating pump fluidly communicates with the second tower. An associated method is provided.

A method for treating sulfur contaminants is provided. The method comprises introducing a methylmorpholine-N-oxide solution to a vessel, wherein the vessel comprises a water layer and a gas layer, wherein the water layer and the gas layer comprise the hydrogen sulfide; introducing methylmorpholine-N-oxide into the water layer; and treating the water layer by allowing the methylmorpholine-N-oxide to react with the hydrogen sulfide.