The present invention relates to a process for removing acid compounds contained in a gaseous effluent which consists in bringing a gaseous effluent into contact, in the absorption column, with an absorbent solution comprising water, between 20% and 28% by weight of pentamethyldipropylenetriamine and between 5% and 35% by weight of N-methyldiethanolamine.

The present disclosure relates to methods and systems for sweetening natural gas may utilize a water wash to achieve a reduction in raw natural gas stream contaminants (e.g., particulate contaminants and/or chemical contaminants) and/or to recover solvent used for removing H.sub.2S and CO.sub.2 from the natural gas. For example, a method may include contacting a first natural gas stream with a first water stream in a co-current contacting system to produce a second natural gas stream and a second water stream, wherein the first natural gas stream comprises natural gas, an acid gas, and a contaminate, and wherein a concentration of the contaminate in the second natural gas stream is less than a concentration of the contaminate in the first natural gas stream; and removing at least a portion of the acid gas from the second natural gas stream.

A treatment composition for remediating for remediating H.sub.2S, CO.sub.2 and other contaminant(s) in a fluid mixture of contaminated liquids and gasses comprising: a hydrocarbon based liquid; and at least one hydroxide compound dispersed or dissolved into the hydrocarbon based liquid. The at least one hydroxide compound dispersed or dissolved into the hydrocarbon based liquid constitutes 30-50 wt% of the treatment composition, the at least one hydroxide compound includes at least one of potassium hydroxide and sodium hydroxide, and a pH of the treatment composition is in a range of 13-14.0.

This invention provides compositions and methods that inhibit formation of alkenyl sulfide polymers and allow the hydrogen sulfide to be removed when scavenging hydrogen sulfide by reaction with aldehydes.

The present disclosure relates to systems and methods useful in the separation of a mixed gaseous stream into one or more individual components. Resulting products can include, for example, carbon dioxide, sulfurous compounds (e.g., hydrogen sulfide), nitrogen, helium, fuel gas (e.g., natural gas, or a single or mixed hydrocarbon stream), and liquefied natural gas. The methods can include processing within a first contacting column a combination of a multi-component feed stream and an anti-freezing agent, removing from the first contacting column a stream containing a fuel gas, removing from the first contacting column a stream containing a sulfurous material, and processing the stream containing the sulfurous material in a second contacting column to provide a stream comprising at least ethane and to provide a separate stream comprising at least a portion of the sulfurous material.

This disclosure relates to CO.sub.2-philic crosslinked polyethylene glycol membranes useful for natural gas purification processes. Also provided are methods of using the membranes to remove CO.sub.2 and H.sub.2S from natural gas.

The present invention relates to a process and system for forming a hydrocarbon feedstock from a biomass material, and the hydrocarbon feedstock formed therefrom. The present invention also relates to a process and system for forming a bio-derived LPG fuel from a hydrocarbon feedstock, and the bio-derived LPG fuel formed therefrom, as well as intermediate treated hydrocarbon feedstocks formed during the process.

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

Embodiments may include a hydrogen sulfide scrubber system that includes a charging chamber, a reaction vessel, and a treated gas trap. Embodiments may include a mobile vehicle, vessel, or platform that includes a mobile vehicle, vessel, or platform with a mounted hydrogen sulfide scrubber system. The hydrogen sulfide scrubber system is configured as previously described. Embodiments may include a method of using a hydrogen sulfide scrubber system.

An integrated amine and redox gas treatment system is configured to treat an influent hydrocarbon containing stream. The system includes a reduction oxidation unit connected directly downstream of an amine unit. The amine unit is configured to separate the influent fluid stream into a first amine effluent stream including hydrocarbons and a second amine effluent stream including a connection pressure and comprising CO.sub.2. The reduction oxidation unit is configured to receive the second amine effluent stream from the amine unit and operate at the connection pressure while releasing a reduction oxidation effluent stream including purified CO.sub.2 The connection pressure includes a single pressure or a plurality of pressures at which both the amine unit and the reduction oxidation unit are configured to operate.