Organic sulfur compounds which are generally present in the crude oil undergoes various transformations while processing the crude oil in the secondary processing units such as fluid catalytic cracker, hydrocracker, delayed coker, visbreaker, etc. The sulfur present in the feed which enters into these secondary processing units are distributed into various products coming out of the units. Sulfur compounds which are present in the various product fractions are removed to meet the desired specifications before routing to the final product pool. Conventionally, sulfur present in the LPG has been removed by amine treatment followed by caustic and water wash. The present invention relates to a process for removal of sulfur and other impurities from Liquefied Petroleum Gas (LPG) comprising olefins through reactive desulfurization route. The present invention is an eco-friendly process as it minimizes or eliminates the use of caustic which is conventionally used to remove the sulfur from LPG.

A process for removal of acid gases from fluid stream, wherein the fluid stream is brought into contact with an absorbent to obtain a treated fluid stream and a laden absorbent, the absorbent comprising a diluent and a compound of the general formula (I) wherein R.sup.1 is selected from C.sub.1-C.sub.8-alkyl and C.sub.2-C.sub.8-hydroxyalkyl; R.sup.2 is selected from hydrogen and C.sub.1-C.sub.8-alkyl; R.sup.3 is selected from hydrogen and C.sub.1-C.sub.8-alkyl; R.sup.4 is selected from hydrogen and C.sub.1-C.sub.8-alkyl; R.sup.5 is C.sub.1-C.sub.8-alkyl; with the proviso that at least one of the following conditions (i) and (ii) is met: (i) R.sup.5 is C.sub.3-C.sub.8-alkyl bound to the nitrogen atom via a secondary or tertiary carbon atom; (ii) when R.sup.4 is hydrogen, R.sup.3 is C.sub.1-C.sub.8-alkyl; or when R.sup.4 is C.sub.1-C.sub.8-alkyl, at least one of R.sup.2 and R.sup.3 is C.sub.1-C.sub.8-alkyl; and n is an integer from 0 to 6. Further provided is an absorbent for the absorption of acid gases from a fluid stream, comprising a diluent and a compound of the general formula (I) as defined above, as well as the use of a compound of the general formula (I) as defined above for removal of acid gases from a fluid stream. The absorbents are useful for the selective removal of hydrogen sulfide from fluid streams and have high acid gas loading capacity, high stability, and low volatility.

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Provided are a process and a system for treating both a high-pressure (HP) and a low-pressure (LP) acid gas-containing gas streams. The system includes a HP absorber unit, a flash drum coupled downstream of the HP absorber unit, and a LP absorber unit coupled downstream of the flash drum. The process includes introducing a HP rich amine solution from a HP absorber unit into a flash drum, operating the flash drum such that a flashed sour gas and a flash drum rich amine solution are produced, and introducing the flashed sour gas and the LP acid gas-containing gas stream into a LP absorber unit.

Disclosed is method for removing carbonyl sulphide and/or carbon disulphide from a sour gas stream. The method comprises subjecting the gas stream to simultaneous contact with an absorption liquid, such as an aqueous amine solution, and with a catalyst suitable for hydrolyzing carbonyl sulphide and/or carbon disulphide. To this end, the invention also provides a reactor system wherein both an absorption liquid and a catalyst are present. In a preferred embodiment, the catalyst is a heterogeneous catalyst present on or in an absorption column, either coated on the trays of a column with trays, or contained in the packing of a packed column.

The present disclosure relates to systems and methods for separation of sulfurous material(s) from a multi-component feed stream. The systems and methods can comprise contacting the multi-component feed stream with a solvent in a contacting column so that at least a portion of the sulfurous material(s) is transferred from the multi-component feed stream to the solvent. A stream of a substantially purified gas can thus be provided along with a liquid stream comprising at least a majority of the sulfurous material. In particular, the solvent can comprise liquid carbon dioxide, which can be particularly beneficial for removing sulfurous materials from multi-component feed streams.

A two or particularly three-phase process, and corresponding apparatus, desulfurizes sour hydrocarbon gas, e.g., natural gas, generally better than known, using a fixed-bed, two-phase processes in terms of the amount of H.sub.2S scavenged and the breakthrough time of H.sub.2S. The three-phase process is effective in scavenging H.sub.2S at ambient temperature and pressure, using a copper salt catalyst impregnated on alumina or other generally inert support, which is regenerable.

Disclosed is an adsorbent containing a metal oxide for adsorption of hydrogen sulfide in biogas, and a biogas purification system using the same.

A particulate material for removing an acid gas and/or mercury contaminant from a hydrocarbon gas is disclosed. The particulate material comprises a superabsorbent hydrogel comprising a cross-linked hydrophilic polymer network having from 0.1 mol % to 50 mol % cross-linking agent. The superabsorbent hydrogel has one or more compounds capable of binding the acid gas and/or mercury contaminant incorporated into the hydrophilic polymer network by absorbing said one or more compounds as a liquid phase or an aqueous solution. Methods for preparing the particulate material and using the particulate material to remove one or more acid gas and/or mercury contaminants from a hydrocarbon gas, dehydrating the hydrocarbon gas, and mitigating corrosion in gas flowlines are also disclosed.

Methods and systems for operating and NGL recovery process are provided. In an exemplary method, an absorber column upstream of a fractionator column is operated at a higher pressure than a pressure in the fractionator column. An NGL (C.sub.3 plus) stream is taken from the bottom of a fractionator column and then ethylene/ethane stream is taken from the top of the fractionator column. A differential pressure between the absorber column and the fraction are column is controlled based, at least in part, on a flow rate of the fractionator feed stream from the absorber column to the fractionator column.

A method of recovery of rich gas where the rich gas is a hydrocarbon gas comprising less than 50 mole % methane is disclosed. The method comprises the steps of gathering the low pressure gas, compressing the gathered gas, cooling the compressed gas in a condenser so that a portion of the compressed gas condenses to form a liquefied gas and liquefied gas vapour in the condenser, and discharging the liquefied gas and liquefied gas vapour from the condenser, in which the cooling of the compressed gas is performed using at least one heat exchanger (40).