Fluor Technologies Corporation

Fluor Corporation

Floor Corporation

Jeffrey Scherffius

Satish Reddy

Peter Condorelli

Ray Won

Carl L Mariz

Mukund Bhakta

Sunil Vyas

Valerie Francuz

John Gilmartin

Stefano Freguia

Contemplated configurations and methods for flue gas treatment comprise a quench section and a scrubbing section that are configured and operated to avoid net condensation of water from the quenched flue gas in the scrubbing section. Consequently, the active agent in the scrubbing medium can be maintained at high concentration and will so allow continuous removal of SOX and NOX to very low concentrations. Moreover, as the scrubbing medium is not diluted by condensate, loss of active agent can be substantially reduced. Especially preferred systems will reduce SO2 concentrations in flue gas to less than 5 ppm, and more typically less than 3 ppm while substantially reducing water and reagent consumption.

Two-stage quench scrubber

Low-pressure steam for a steam consuming device, and particularly a steam reboiler, is generated at the steam consumption pressure to maximize the heat recovery from a utility fuel and/or waste heat source. Most preferably, steam is generated at the lowest possible pressure by fluidly coupling the steam generator to the steam consuming device (e.g., by integrating the condensate drum with the steam drum). Therefore, it should be appreciated that the steam generator pressure in such configurations and methods will ride on the reboiler pressure.

Configurations and methods of generating low-pressure steam

A synthesis plant (A) includes a compression device (A) that increases a pressure differential between the bottom product pressure of a cryogenic separator (A) and the delivery pressure of the bottom product to a downstream plant component. Such increased pressure differential is employed to increase cooling in the separator (A) to thereby significantly reduce the volume of excess air. In most preferred aspects, at least part of the energy required for the compression device is provided by expansion (A) of the separator feed.

Ammonia plant

An IGCC plant has a precombustion decarbonization unit in which acid gas is removed from a combustion gas before the combustion gas enters a combustion turbine. In one preferred configuration, a sulfur removal unit removes hydrogen sulfide from a feed gas before the desulfurized feed gas enters an autorefrigeration unit in which carbon dioxide is removed. In another preferred configuration, hydrogen sulfide is converted to carbonyl sulfide in a dryer, and the carbonyl sulfide is absorbed in the liquid carbon dioxide that is prepared from the feed gas using autorefrigeration.

Configurations and methods of carbon capture

An acid gas removal plant includes an absorber that provides a rich solvent to two regenerators that independently generate a lean and a semi-lean solvent, wherein the semi-lean solvent is produced in one of the regenerators using heat and/or steam derived from the other regenerator. Further heat integration is particularly contemplated with power plants in which the power plant provides high-level heat to the acid gas removal plant and wherein the power plant receives low-level heat from the acid gas removal plant.

Split flow process and apparatus

A recovery plant for recovery of a gaseous component from a process gas has an absorber employing a lean solvent and a semi-lean solvent that absorb the gaseous component from the process gas, thereby producing a rich solvent, a semi-rich solvent, and a lean process gas. A regenerator extracts the gaseous component from the rich solvent, thereby regenerating the lean solvent and the semi-lean solvent. A solvent flow control element combines at least part of the semi-rich solvent and the semi-lean solvent to form a mixed solvent, and a cooler cools the mixed solvent that is subsequently fed into the absorber. In a method of removing a gaseous component from a process gas, a stream of lean solvent and a stream of semi-lean solvent are provided. In another step, the stream of lean solvent and the stream of semi-lean solvent contact the process gas in an absorber to produce a stream of semi-rich solvent and rich solvent. In a further step, at least part of the stream of semi-rich solvent and semi-lean solvent are combined to form a mixed solvent stream, and a cooler cools the mixed solvent stream, which is introduced into the absorber to absorb the gaseous component.

Split-flow process and apparatus

A recovery plant for recovery of a gaseous component, such as carbon dioxide, from a process gas, such as the exhaust from a combustion turbine, has an absorber ( ) employing a lean solvent ( ) in an upper section of the absorber and a semi-lean solvent ( ) in a lower section of the absorber. A regenerator ( ) extracts the gaseous component from the rich solvent ( ) thereby producing a regenerated lean solvent ( ) and a semi-lean solvent ( ). A solvent flow control element ( ) combines at least a part of the semi-rich solvent ( ) from the upper section of the absorber with the semi-lean solvent ( ) from the regenerator to form a mixed solvent ( ), and a cooler ( ) cools the mixed solvent that is subsequently fed into the lower section of the absorber ( ). By cooling the mixed solvent prior to entry into the absorber, the thermal energy required to remove the carbon dioxide from the exhaust gas can be reduced.

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Aliso Viejo, CA, United States of America

Jeffrey Scherffius