This invention relates to a process and an apparatus for producing a mixed feed stream for a steam reforming plant from a first feed stream containing methane and a second feed stream comprising higher hydrocarbons, olefins and diolefins. According to the invention, the required hydrogenation of the mono- and diolefins and the hydrodesulfurization of the organic sulfur compounds contained in the feed stream are carried out step by step under process conditions optimized in each case. Furthermore, the inlet temperature into the respective reaction zone is controlled such that overheating of the feedstocks is avoided, which otherwise leads to undesired coke deposits, cloggings and the accelerated deactivation of the catalysts used.

A method for gas separation, purification and clarification by FTrPSA uses the temperature and pressure of different raw gases as well as the differences in adsorption separation coefficients and physicochemical properties among all components in the raw gases at a temperature range of 80-200 C. and a pressure range of 0.03-4.0 Mpa, regulates the adsorption or desorption regeneration operation in the PSA cycle process by coupling various separation methods, and expands the adsorption theory that the PSA or TSA separation process is limited to the cyclic operation of adsorption and desorption regeneration through pressure or temperature changes, thus realizing the gradient utilization of energy in the process of gas separation, purification and clarification as well as the easy-to-match and easy-to-balance cyclic operation of adsorption and desorption regeneration in the process of intercooling & shallow-cooling and medium & high-temperature PSA separation to separate, purify and clarify various raw gases.

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.

Processes and systems for upgrading a hydrocarbon. In some embodiments, the process for upgrading a hydrocarbon, can include contacting a gas that can include one or more C.sub.1-C.sub.4 hydrocarbons and carbonyl sulfide with a sorbent under conditions sufficient to cause at least a portion of the carbonyl sulfide to sorb onto the sorbent to produce a treated gas lean in carbonyl sulfide and a sorbent rich in carbonyl sulfide. The process can also include contacting the sorbent rich in carbonyl sulfide with a regenerating gas that can include molecular hydrogen, one or more C.sub.1-C.sub.4 hydrocarbons, or a mixture thereof to produce a regenerated sorbent and a desorb effluent that can include a sulfur-based contaminant. The process can also include introducing at least a portion of the desorb effluent into a pyrolysis zone of a steam cracker and recovering a steam cracker effluent from the pyrolysis zone.

A method for recovering C2 components in a methane-containing industrial gas includes the steps of (1) cooling a compressed methane-containing industrial gas and performing gas-liquid separation; (2) absorbing C2 components in the gas phase by using an absorbent to obtain an absorption rich liquid; (3) returning the absorption rich liquid to the compression in step (1) or mixing the absorption rich liquid with the liquid phase obtained in step (1) to obtain a mixed liquid, and depressurizing the mixed liquid or the absorption rich liquid; (4) performing methane desorption on the depressurized stream to obtain a rich absorbent, or performing second gas-liquid separation on the depressurized stream, followed by methane desorption on the second liquid phase to obtain a rich absorbent; and (5) desorbing and separating the rich absorbent to obtain a lean absorbent and an enriched gas, and recycling and reusing the lean absorbent.

Oxidative dehydrogenation of paraffins to olefins provides a lower energy route to produce olefins. Oxidative dehydrogenation processes may be integrated with a number of processes in a chemical plant such as polymerization processes, manufacture of glycols, and carboxylic acids and esters. Additionally, oxidative dehydrogenation processes can be integrated with the back end separation process of a conventional steam cracker to increase capacity at reduced cost.

A method comprising: introducing a refinery off gas stream into an oil absorber wherein the refinery off gas stream comprises H.sub.2, N.sub.2, O.sub.2, methane, ethane, ethylene, propane, propylene, and C.sub.4+; introducing a solvent into the oil absorber; counter-currently contacting the refinery off gas stream and the solvent in the oil absorber; generating an absorber overhead stream comprising H.sub.2, N.sub.2, O.sub.2, and methane; generating an absorber bottoms stream comprising the solvent wherein ethane, ethylene, propane, propylene, and C.sub.4+ are dissolved in the solvent; introducing the absorber bottoms stream into a solvent regenerator and generating an overhead stream comprising ethane, ethylene, propane, propylene, and C.sub.4+; and introducing the overhead stream into a C.sub.2-C.sub.3 splitter that generates a dilute ethylene product stream and a bottoms product stream, wherein the dilute ethylene product stream comprises ethylene and ethane, and wherein the bottoms product stream comprises propane, propylene, and C.sub.4+.

Oxidative dehydrogenation of paraffins to olefins provides a lower energy route to produce olefins. Oxidative dehydrogenation processes may be integrated with a number of processes in a chemical plant such as polymerization processes, manufacture of glycols, and carboxylic acids and esters. Additionally, oxidative dehydrogenation processes can be integrated with the back end separation process of a conventional steam cracker to increase capacity at reduced cost.

The present invention describes a process for the simultaneous removal of arsenic and sulphur compounds from hydrocarbon streams of fossil origin, wherein hydrocarbon streams of fossil origin resulting from the retorting process of schist are purified by direct contact with hydrated iron oxide, such as goethite (-FeOOH) in its raw natural form (limonite ore particles).

A system and method for improving the quality of a raw gas or raw syngas passes the raw gas or raw syngas past a catalytic element comprising catalyst with an optional sorbent. A downstream measurement of one or more parameters of the improved gas is fed back to a controller configured to regulate the regeneration of the catalyst and optional sorbent and, optionally, the flow rate of the regeneration fluid to the catalytic element. The system and method are particularly suitable for improving raw syngas generated from a carbonaceous material in a fixed bed or fluidized-bed or entrained-flow gasifier. One or more undesirable syngas constituents are subject to one or more of catalytic cracking, reforming, partial oxidation and/or decomposition to promote their conversion into desirable syngas constituents. At least one catalytic element is regenerated in situ, either periodically, continuously, or in a combination of these two modes.