A method comprises separating a hydrocarbon feed stream having carbon dioxide into a heavy hydrocarbon stream and a light hydrocarbon stream. The light hydrocarbon stream is separated into a carbon dioxide-rich stream and a carbon dioxide-lean stream. At least a portion of the carbon dioxide-lean stream is fed to a hydrocarbon sweetening process. Another method comprises receiving a hydrocarbon feed stream that comprises 30 molar percent to 80 molar percent carbon dioxide. A heavy hydrocarbon stream is separated from the hydrocarbon feed stream, wherein the heavy hydrocarbon stream comprises at least 90 molar percent C.sub.3+ hydrocarbons. A carbon dioxide-rich stream is separated from the hydrocarbon feed stream, wherein the carbon dioxide-rich stream comprises at least 95 molar percent carbon dioxide.

A method comprises separating a hydrocarbon feed stream having carbon dioxide into a heavy hydrocarbon stream and a light hydrocarbon stream. The light hydrocarbon stream is separated into a carbon dioxide-rich stream and a carbon dioxide-lean stream. At least a portion of the carbon dioxide-lean stream is fed to a hydrocarbon sweetening process. Another method comprises receiving a hydrocarbon feed stream that comprises 30 molar percent to 80 molar percent carbon dioxide. A heavy hydrocarbon stream is separated from the hydrocarbon feed stream, wherein the heavy hydrocarbon stream comprises at least 90 molar percent C.sub.3+ hydrocarbons. A carbon dioxide-rich stream is separated from the hydrocarbon feed stream, wherein the carbon dioxide-rich stream comprises at least 95 molar percent carbon dioxide.

Process for hydrotreatment of hydrocarbon-containing feedstock comprising sulphur- and nitrogen-containing compounds, comprising: a) separating the feedstock into heavy and light fractions, b) a first hydrotreatment stage wherein the heavy fraction and hydrogen are contacted with a first hydrotreatment catalyst Z1 to produce a first desulphurized effluent, c) separating the first effluent into a first gaseous fraction and a first liquid fraction, d) purifying the first gaseous fraction to produce a hydrogen-rich flow, e) mixing the light fraction with the first liquid fraction to produce a mixture, f) a second hydrotreatment stage wherein the mixture from stage e) and the hydrogen-rich flow from stage d) are contacted with a second hydrotreatment catalyst Z2 to produce a second desulphurized effluent, g) separating the second effluent into a second gaseous fraction and a second liquid fraction, h) recycling at least part of the second gaseous fraction to b) as a flow of hydrogen.

The present invention concerns a process for the treatment of a hydrocarbon feed containing hydrogen and hydrocarbons including C.sub.1 to C.sub.4 hydrocarbons. The process employs two steps for recontacting gaseous and liquid phases and in which at least one of the recontacting steps is carried out in a column (30, 40) in which the gaseous and liquid streams are brought into counter-current contact.

The present invention concerns a process for the treatment of a hydrocarbon feed containing hydrogen and hydrocarbons including C.sub.1 to C.sub.4 hydrocarbons, employing a first and a second recontacting step and in which the gaseous effluent obtained from the second recontacting step is recycled to the first recontacting step. The process is of particular application to the treatment of a hydrocarbon feed obtained from catalytic reforming with a view to recovering hydrogen and C.sub.3 and C.sub.4 hydrocarbons.

The present invention concerns a process for the treatment of a hydrocarbon feed containing hydrogen and hydrocarbons including C.sub.1 to C.sub.4 hydrocarbons, comprising the following steps: separating the hydrocarbon feed into a gaseous phase and a liquid phase containing hydrocarbons; cooling the liquid phase obtained from step a) to a temperature of 45 C. or less using a cooling device; carrying out a first recontacting step on the cooled liquid phase with the gaseous phase in a counter-current column in order to recover a first gaseous effluent which is rich in hydrogen and a first liquid hydrocarbon effluent;
in which, before the cooling step b), the liquid phase obtained from step a) is pre-cooled by exchange of heat in an exchanger supplied with the first gaseous effluent and/or the first liquid hydrocarbon effluent obtained from step c).

Organic sulfur compounds contained in refinery off gas streams having either high ort low concentrations of olefins are converted to hydrogen sulfides which can be then be removed using conventional amine treating systems. The process uses a catalytic reactor with or without a hydrotreater depending on the olefin concentration of the off gas stream. The catalytic reactor operates in a hydrogenation mode or an oxidation mode to convert a majority of organic sulfur compounds into hydrogen sulfides.

Organic sulfur compounds contained in refinery off gas streams having either high ort low concentrations of olefins are converted to hydrogen sulfides which can be then be removed using conventional amine treating systems. The process uses a catalytic reactor with or without a hydrotreater depending on the olefin concentration of the off gas stream. The catalytic reactor operates in a hydrogenation mode or an oxidation mode to convert a majority of organic sulfur compounds into hydrogen sulfides.

A method and apparatus for continuously treating acid gases including recovering absorbent chemicals by introducing streams leaving a regenerator and/or leaving an absorber into a static mixing zone wherein supplemental washing water is added to recover absorbent chemicals. Improvements to the prior art methods are provided where one or more absorbent chemical recovery units are included to increase the amount of recovered absorbent chemicals exiting the regenerator and/or exiting the absorber are increased and/or maximized. Absorbent chemical recovery units can include mixing units where liquid is added to the stream of sour gas and absorbent chemical to mix with and absorb the absorbent chemical from the stream.

A method and apparatus for continuously treating acid gases including recovering absorbent chemicals by introducing streams leaving a regenerator and/or leaving an absorber into a static mixing zone wherein supplemental washing water is added to recover absorbent chemicals. Improvements to the prior art methods are provided where one or more absorbent chemical recovery units are included to increase the amount of recovered absorbent chemicals exiting the regenerator and/or exiting the absorber are increased and/or maximized. Absorbent chemical recovery units can include mixing units where liquid is added to the stream of sour gas and absorbent chemical to mix with and absorb the absorbent chemical from the stream.