Amoco Corporation

Standard Oil Company (indiana)

Russell L McGalliard

Paul T Pendergraft

Clifton S Goddin, Jr

Davis L Taggart

Lyman Yarborough

Truman P Moote

David G Hild

Ralph R Eguren

Gary W Larrabee

Myron L Dunton

This invention relates to water pollution control and concerns a method for removing dispersed oil droplets from water by contacting oleophilic bodies with an oil-water emulsion before the emulsion is separated in a settling tank. Oleophilic bodies which float on oil are provided in a settling tank into which an oil-water emulsion is introduced downwardly. Oil-free water is drawn off at the bottom of the tank.

Method of oil/water separation utilizing coalescing bodies

An improved method for reducing the hydrogen sulfide and hydrogen polysulfide content of liquid sulfur, wherein, the liquid sulfur is brought into contact with a solid degradation catalyst consisting of alumina or a cobalt-molybdenum impregnated alumina at 250.degree. F. to 320.degree. F., preferably 270.degree.-275.degree. F., in the presence of a gaseous purge stream of air or oxygen enriched air. In addition to exhibiting a many fold increase in rate of reaction relative to the use of either the catalyst without a purge gas or the purge gas alone, the use of an oxygen containing purge gas (such as wet air) in combination with the catalyst (such as alumina) shows a significant improvement, when compared to the use of a dry nitrogen purge in combination with the catalyst under similar conditions, in the kinetics of both the conversion of the polysulfides to sulfide (rate constant of 0.611 for wet air vs. 0.409 for dry nitrogen at 300.degree. F.) and the removal of hydrogen sulfide from liquid sulfur (rate constant of 0.877 in wet air vs. 0.62 for dry nitrogen at 300.degree. F.).

Process for removal of hydrogen sulfide and hydrogen polysulfide from

Regeneration of sulfided metal oxide absorbent in an absorber is conducted using as diluent for oxygen a portion of Claus plant gas-in-process withdrawn upstream of the absorber. The result is a reduction in the size of the absorber and/or a reduction in the rate of return of regeneration effluent to a Claus plant during regeneration of such absorbent.

Sulfur recovery process using metal oxide absorber feed for regeneration

A method is described by which sour liquid hydrocarbon streams are sweetened by subjecting said streams to oxidizing conditions in the presence of a hydrocarbon soluble alkanolamine.

Use of alkanolamines in sweetening sour liquid hydrocarbon streams

A cryogenic process for separating relatively pure fractions of methane and carbon dioxide from mixtures thereof which also contain other components. The process utilizes a lean oil as an absorbent which performs the additional functions of preventing the formation of solid carbon dioxide within the apparatus and preventing formation of an azeotrope of carbon dioxide with ethane and enhancing the separation of hydrogen sulfide from carbon dioxide.

Process for separating relatively pure fractions of methane and carbon

The operation of a demethanizer being used to cryogenically separate high carbon dioxide content hydrocarbon feed into liquid ethane essentially free of both methane and carbon dioxide with simultaneous production of overhead gas comprising methane and carbon dioxide without carbon dioxide icing to foul equipment by virtue of maintaining pressure at which non-gaseous carbon dioxide remains dissolved in liquid hydrocarbon, can be improved by intentionally injecting a dehydrated methane-rich stripping gas to the bottom of the demethanizer. At temperatures below about -80.degree. F., the addition of a stream such as dehydrated inlet gas stabilizes the demethanizer operation by making the carbon dioxide to ethane ratio of the liquid bottoms product less sensitive to temperature fluctuations in the reboiler system heating the bottoms. In this manner, product recovery is increased while acceptable carbon dioxide as well as methane content can be maintained. Such a method is compatible with closed-loop control of the reboiler temperature based on gas chromatography measurements.

Growing community of inventors

Broken Arrow, OK, United States of America

Russell L McGalliard