Chevron Research Company

Baker Hughes Corporation

Engelhard Corporation

Robert L Flanders

William A Blanton, Jr

David B Bartholic

Michael J Zetlmeisl

George G Duggan

Roy W Greenlee

The present invention, therefore, is directed to a novel method for improving conversion in a fluidized catalytic cracking unit feed stream containing vanadium. According to the method, an effective amount of a composition comprising at least one overbase complex of a magnesium or aluminum salt or a mixture thereof and an organic acid complexing agent is incorporated into the feed stream.

Methods for improving conversion in fluidized catalytic cracking units

A process for upgrading a petroleum charge of crude oil or residual fractions thereof, in which the charge is dispersed into a descending curtain of heated, substantially inert contact material. This contact material preferably has a conversion rate not substantially greater than 10% in the CAT D test. The vapors generated on contact of the charge with the curtain are collected on the side of the curtain opposite from where the charge is dispersed. The recovered product has a substantially reduced metals content and Conradson Carbon number and is suitable for catalytic cracking or use as heavy fuel or a heavy fuel precursor.

Process for upgrading crude oil and residual fractions thereof by

Sulfur oxides are removed from flue gas in a catalyst regenerator in a fluid catalyst cracking system while liquid-hydrocarbon product yield from the system is maintained at a high level by heating a nonzeolitic, silica-containing catalyst to 800.degree.-1500.degree. F.; impregnating 0.1 to 25 weight percent aluminum onto the catalyst particles; and cycling the resulting particles through the cracking reactor and catalyst regenerator in the cracking system, the impregnated catalyst being particularly adaptable for cracking heavy, metals-containing feeds such as residua.

Process for controlling sulfur oxides using an alumina-impregnated

Removal of sulfur oxides from cracking catalyst regenerator flue gas using particulate alumina is enhanced by employing a zeolitic cracking catalyst containing little or no silica in the catalyst matrix.

Restricting silica content of catalyst inventory to prevent alumina

Carbon monoxide and sulfur oxides are removed from catalyst regenerator flue gas in an FCC system using a nonzeolitic cracking catalyst and sulfur from the flue gas is shifted to form hydrogen sulfide, which is recovered in the gases removed from the cracking reactor in the system by reacting carbon monoxide in the regenerator flue gas with oxygen in contact with a particulate carbon monoxide combustion promoter, reacting sulfur oxides in the regenerator flue gas with particulate alumina physically mixed with the nonzeolitic catalyst to form a sulfur-containing solid, and forming hydrogen sulfide in the cracking reactor by contacting the sulfur-containing solid with the hydrocarbon feed.

Process for removing pollutants from nonzeolitic catalyst regenerator

Carbon monoxide and sulfur oxides are removed from flue gas produced in a catalyst regenerator in an FCC system and sulfur from the flue gas is shifted to form hydrogen sulfide, which is recovered in the gases removed from the cracking reactor in the system by introducing sufficient molecular oxygen into the catalyst regenerator to provide an atmosphere therein having a molecular oxygen concentration of at least 0.1 volume percent, reacting carbon monoxide in the regenerator flue gas with oxygen in contact with a particulate carbon monoxide combustion promoter physically admixed with the cracking catalyst, reacting sulfur oxides in the regenerator flue gas with silica-free alumina included as a discrete phase in the FCC catalyst to form a sulfur-containing solid in the catalyst, and forming hydrogen sulfide in the cracking reactor by contacting the sulfur-containing solid with the hydrocarbon feed.

Removing pollutants from flue gas in nonzeolitic catalytic cracking

Sulfur oxides are removed from a gas and the sulfur is converted to hydrogen sulfide by the steps of: (1) reacting sulfur oxides in the gas with alumina to form a solid sulfur-containing compound and remove sulfur oxides from the gas; and (2) contacting the solid compound resulting from step (1) with a hydrocarbon at a temperature of about 800.degree.-1300.degree. F. and reacting the solid sulfur-containing compound with components of the hydrocarbon to form hydrogen sulfide.

Catalyst for removing sulfur from a gas

Method for removing pollutants from catalyst regenerator flue gas

Carbon monoxide and sulfur oxides are removed from flue gas produced in a catalyst regenerator in an FCC system and sulfur from the flue gas is shifted to form hydrogen sulfide, which is recovered in the gases removed from the cracking reactor in the system by reacting carbon monoxide in the regenerator flue gas with oxygen in contact with a particulate carbon monoxide combustion promoter, reacting sulfur oxides in the regenerator flue gas with particulate alumina physically mixed with the FCC catalyst to form a sulfur-containing solid, and forming hydrogen sulfide in the cracking reactor by contacting the sulfur-containing solid with the hydrocarbon feed.

Process for removing pollutants from catalyst regenerator flue gas

Sulfur oxides are removed from flue gas in a catalyst regenerator in a fluid catalyst cracking system while liquid-hydrocarbon product yield from the system is maintained at a high level by heating a particulate silica-containing cracking catalyst to 800-1500.degree. F; impregnating 0.1 to 25 weight percent aluminum onto the catalyst particles; and cycling the resulting particles through the cracking reactor and catalyst regenerator in the cracking system.

Process for removing sulfur from a gas

Sulfur oxides are removed from a gas and the sulfur is converted to hydrogen sulfide by the steps of: (1) reacting sulfur oxides in the gas with alumina to form a solid sulfur-containing compound and remove sulfur oxides from the gas; and (2) contacting the solid compound resulting from step (1) with a hydrocarbon at a temperature of about 800.degree.-1300.degree. F and reacting the solid sulfur-containing compound with components of the hydrocarbon to form hydrogen sulfide.

Growing community of inventors

San Anselmo, CA, United States of America

Robert L Flanders