Methods and systems for gas separation of syngas applying differences in water solubilities of syngas components, the method including producing a product gas comprising hydrogen and carbon dioxide from a hydrocarbon fuel source; separating hydrogen from the product gas to create a hydrogen product stream and a byproduct stream by solubilizing components in water that are more soluble in water than hydrogen; injecting the byproduct stream into a reservoir containing mafic rock; and allowing components of the byproduct stream to react in situ with components of the mafic rock to precipitate and store components of the byproduct stream in the reservoir.

It is an object of the present invention to downsize facility for removing or reducing concentration of hydrogen sulfide and oxygen in gas and reduce facility cost. Syngas g contains hydrogen sulfide and oxygen as target constituents of removal or reduction in concentration. Hydrogen sulfide content and oxygen content in the syngas g are measured in a preceding measurement part 13. Then, the syngas g is contacted with desulfurizing agent 14a including iron oxide. Selection is made whether to further execute deoxidization in a deoxidizing part 16 or omit or simplify the deoxidization according to results of measurements in the preceding measurement part 13.

Methods and systems for separating C.sub.3 hydrocarbons from lighter hydrocarbons, carbon monoxide, carbon dioxide, and water are provided. In certain embodiments, the methods include feeding a gaseous mixture including C.sub.1, C.sub.2, and C.sub.3 hydrocarbons and benzene solvent to the absorber column where benzene solvent selectively absorbs C.sub.3 hydrocarbons. The methods can further include removing a first stream comprising benzene solvent and absorbed C.sub.3 hydrocarbons from the absorber column, and feeding the first stream to a stripper column where benzene solvent is separated from C.sub.3 hydrocarbons, and removing a second stream comprising C.sub.3 hydrocarbons from the stripper column.

Disclosed herein is a rotating packed bed, RPB, for mass transfer between a sorbent and a gas, the RPB comprising: a central chamber arranged to receive a flow of a sorbent that is a liquid; and a flow path for the sorbent between the central chamber and a region for mass transfer between a gas and the sorbent; wherein, in use, the flow of sorbent through the region for mass transfer is substantially in cross-flow with the flow of gas through the region for mass transfer. Advantageously, mass transfer between a liquid sorbent and a gas is improved.

The invention pertains to a method for recovering HCl from a HCl containing gas stream wherein a HCl containing gas stream with a temperature of 20 to 25 C. is provided to an adiabatic absorption unit where it is contacted with water as an absorbent, resulting in the formation of a top gas stream and a aqueous HCl product solution, wherein the temperature of the top gas stream is at least 70 C. and wherein the aqueous HCl product solution has a HCl concentration in the range of 5-20 wt. %. It is preferred for the HCl-containing gas stream to be derived from a hydrogenation step wherein a feed comprising monochloroacetic acid (MCA) and dichloroacetic acid (DCA) is reacted with hydrogen to form a HCl-containing gas stream and a product stream comprising MCA and a reduced amount of DCA. The HCl product solution is preferably diluted to a concentration of 1-8 wt. %, and the diluted solution is used as absorbent in a second absorption step, wherein HCl is absorbed from a further HCl-containing gas stream to form a second aqueous HCl solution. The further HCl-containing gas stream is preferably derived from a chlorination step wherein acetic acid is reacted with chlorine, resulting in the formation of the further HCl-containing gas stream and a feed comprising monochloroacetic acid (MCA) and dichloroacetic acid (DCA).

The present process invention in continuation to the U.S. Ser. No. 14/392,066 appertains to Advanced Combustion in post-combustion carbon capture, wherein the CO.sub.2-containing flue gas, said CO2-Stream, is cleaned from harmful constituents, recirculated, oxygenized and employed for combustion for the fossil fuels, referred to Flue Gas Oxy-Fueling in order to obtain a CO.sub.2-rich gas upstream to CO2-CC with significantly less gas flow rate subject to further processing. This continuation process patent also presents processing to prepare a CO.sub.2-rich CO2-Stream for the pre-combustion carbon capture downstream of gasification and gas cleaning process; or from the secondary CO2-Stream that stems from the cathodic syngas [CO/2H.sub.2] downstream of HPLTE-SG of patent parent, then downstream of the HP/IP-water shift converters in [CO.sub.2/3H.sub.2] composition, whereas the CO.sub.2-rich CO2-Stream from either pre-combustion process is routed to the CO2-CC for CO.sub.2 cooling and condensation section of the U.S. Ser. No. 14/392,066 to obtain liquid carbon dioxide for re-use as new fossil energy resource.

The method includes limiting saturation of output absorbent with dispersed and recirculating gas molecules with full completion of chemical reactions in the first stage, countercurrent contact between the gas and absorbent in the loading elements of the nozzle in the second stage, further extraction of gas molecules by absorbent in the irrigation chamber of the third stage. Then the gas for the absorption of hard-to-recover components is transferred to the irrigation chamber of the fourth stage, where it is irrigated with fine droplets of fresh and circulating absorbent. Then the direct-flow contact between the gas-liquid phase is carried out in the checker loading elements of the fifth stage. Finally, interphase contact of depleted gas with absorbent is completed in the bubbling chamber of the sixth stage and in the interchamber space between the fifth and sixth chambers. The bubbling chamber of the I stage is divided by a partition into the final and the main bubbling chambers, and the ceramic dispersants and/or hypersonic Hartmann's oscillators are installed in them. The pipeline of the removal of the saturated absorbent is attached to the final chamber, and the circulation pumps are attached to the main chamber of the I stage the and bubbling chamber of the VI stage, the pressure pipelines of the circulation pumps are connected to the scattering reflectors of the irrigation chambers of the III and IV stages. The pressure pump pipeline for supplying the fresh absorbent is connected to the hypersonic acoustical dispersant and the scattering reflectors which are set in the irrigation chamber of the IV stage. The space between the chambers of the I and the II stage is closed and attached by the pipeline of the gas discharge conduit to the distribution nozzles mounted at the bottom of the checker chamber of the II stage. The pipeline for the gas outlet conduit of irrigation chamber of the III stage is attached to the irrigation chamber of the IV stage. The pipes of supply, bypass and gas withdrawal and absorbent are equipped with the magnetic valves. Pumps are equipped with frequency converters (inverters). Valves, inverters and air conditioner are connected to the unit of the automatic control system. The invention allows to achieve the effect of a finite solubility of hard-to-recover gas components in the liquid and the automation of technological processes in order to reduce the power consumption.

The disclosure provides seven integrated methods for the chemical sequestration of carbon dioxide (CO.sub.2), nitric oxide (NO), nitrogen dioxide (NO.sub.2) (collectively NO.sub.x, where x=1, 2) and sulfur dioxide (SO.sub.2) using closed loop technology. The methods recycle process reagents and mass balance consumable reagents that can be made using electrochemical separation of sodium chloride (NaCl) or potassium chloride (KCl). The technology applies to marine and terrestrial exhaust gas sources for CO.sub.2, NOx and SO.sub.2. The integrated technology combines compatible and green processes that capture and/or convert CO.sub.2, NOx and SO.sub.2 into compounds that enhance the environment, many with commercial value.

This disclosure relates generally to processes sour gas treating for H2S Removal, separation of impurities such as hydrocarbons, BTEX and mercaptans and the Partial Acid Gas Enrichment integrated system from the sour gas field developments, or any application. The combination of innovation schemes comprises one or more absorbers, primary and secondary regenerators. The secondary regenerator functions are, enriching the H2S stream further and to separate the hydrocarbons, mercaptans and BTEX where an additional acid gas enrichment and hydrocarbons removal could be eliminated. Then there is a unique sulfur recovery and tail gas treating with a unique 2-zone reaction furnace, tail gas absorber which operated as partial acid gas enrichment by receiving split acid gas from the SRU and the hydrolysis reactor to hydrolyze sulfur compounds. The acid gas from the primary and the secondary amine regeneration and the acid gas recycle from the tail gas which is preheated and these streams flow to the 2-zones reaction furnace in the sulfur recovery unit to establish a stable low emission and higher recovery.

A process for treating an H.sub.2S- and CO.sub.2-comprising fluid stream, in which a) the fluid stream is treated in a first absorber at a pressure of 10 to 150 bar with a first substream of a regenerated H.sub.2S-selective absorbent to obtain a treated fluid stream and an H.sub.2S-laden absorbent; b) the H.sub.2S-laden absorbent is heated by indirect heat exchange with regenerated H.sub.2S-selective absorbent; c) the heated HS-laden absorbent is decompressed to a pressure of 1.2 to 10 bar in a low-pressure decompression vessel to obtain a first CO.sub.2-rich offgas and a partly regenerated absorbent; d) the partly regenerated absorbent is regenerated in a desorption column to obtain an H.sub.2S-rich offgas and regenerated absorbent; e) the H.sub.2S-rich offgas is fed to a Claus unit and the offgas from the Claus unit is fed to a hydrogenation unit to obtain hydrogenated Claus tail gas; f) the hydrogenated Claus tail gas and the first CO.sub.2-rich offgas are treated in a second absorber at a pressure of 1 to 4 bar with a second substream of the regenerated H.sub.2S-selective absorbent to obtain a second CO.sub.2-rich offgas and a second H.sub.2S-laden absorbent; and g) the second H.sub.2S-laden absorbent is guided into the first absorber. Also described is a plant suitable for performance of the process. The process is notable for a low energy requirement.