A process for altering the composition of a feed gas containing H.sub.2S equivalents is disclosed. The process comprises (a) contacting the feed gas with a solid adsorbent at a temperature of 250-500 C., to obtain a loaded adsorbent, (b) purging the loaded adsorbent with a purge gas comprising steam, thus producing a product stream which typically contains substantially equal levels of CO.sub.2 and H.sub.2S. The process further comprises a step (c) of regenerating the purged adsorbent by removal of water. The adsorbent comprises alumina and one or more alkali metals, such as potassium oxides, hydroxide or the like.

A treatment system for remediating some forms of sulfur, CO.sub.2, and other contaminants/impurities from a gas stream includes at least one of a process vessel and a treatment coil. Each of the vessel and treatment coil have internals, different in design from each other, which promote intimate mixing and extended contact time between a treatment composition and a gas being treated. The vessel, which additionally facilitates vapor/liquid separation, operates about one-half to two-thirds full of liquid treatment composition. In some embodiments, the treatment coil is a serpentine arrangement of piping, into which the atomized treatment composition is injected on a continuous basis.

The present disclosure provides compositions and methods for using recombinant C.sub.1 metabolizing microorganisms capable of metabolizing sulfur containing compounds and other contaminants to biologically convert sour or acidic natural gas into high-value molecules, and to allow recovery of stranded oil.

The disclosure includes a method, comprising passing a fluid into a co-current contactor, passing a solvent into the co-current contactor, dividing the solvent into solvent droplets having a first average droplet size, placing the fluid in contact with the solvent droplets to create a combined stream, coalescing at least a portion of the solvent droplets to create solvent droplets having a second average droplet size, wherein the second average droplet size is greater than the first average droplet size, and separating the fluid and the solvent.

A scrubbing solution for removing contaminants, including particularly hydrogen sulfide, from a fluid. The scrubbing solution includes at least one scrubbing reagent which has a primary or secondary amine and an acid, which may be phosphoric acid. The fluid being scrubbed is passed through the scrubbing solution. The contaminants react with the scrubbing reagent securing them in the scrubbing solution. The fluid being scrubbed and the scrubbing solution are then separated. The scrubbing solution is heated and, if the scrubbing solution is under pressure, the pressure is reduced. The acid facilitates thorough removal of the contaminants, and especially the hydrogen sulfide, from the scrubbing solution. The scrubbing solution is then ready for reuse. Because the scrubbing solution is rendered substantially free of hydrogen sulfides, it can absorb other sulfide contaminants that might not otherwise be absorbed.

The invention relates to the field of membrane gas separation. A method of removing components of gas mixtures which is based on passing the components of a gas mixture through a nanoporous membrane and subsequently selectively absorbing them with a liquid absorbent that is in contact with the nanoporous membrane, wherein to prevent the gas from getting into the liquid phase of the absorbent and the liquid phase of the absorbent from getting into the gas phase, a nanoporous membrane with homogeneous porosity (size distribution less than 50%) and a pore diameter in the range of 5-500 nm is used, and the pressure differential between the gas phase and the liquid absorbent is kept below the membrane bubble point pressure. An acid gas removal performance of more than 0.3 nm.sup.3/(m.sup.2 hour) in terms of CO.sub.2 is achieved at a hollow-fiber membrane packing density of up to 3200 m.sup.2/m.sup.3, which corresponds to a specific volumetric performance of acid gas removal of up to 1000 nm.sup.3 (m.sup.3 hour). The technical result is that of providing effective extraction of undesirable components from natural and process gas mixtures.

The present disclosure is to functionalised polyamine hydrogels that can be used for capturing one or more acidic gases from gaseous streams and atmospheres. In particular, the present disclosure is directed to hydrogels comprising a cross-linked polyamine or copolymer thereof, wherein the cross-linked polyamine comprises one or more amine groups substituted with an optionally substituted alkanol group. Methods and apparatuses for removing acidic gases from gaseous streams or atmospheres using the functionalised hydrogels are also disclosed.

The invention is directed to a process to continuously treat a hydrogen sulphide comprising gas, said process comprising the following steps: (a) contacting the hydrogen sulphide comprising gas with an aqueous alkaline liquid comprising sulphide-oxidising bacteria and elemental sulphur particles thereby producing a loaded aqueous liquid comprising dissolved sulphide, polysulphide compounds, sulphide-oxidising bacteria and elemental sulphur particles and a gas having a lower content of hydrogen sulphide, and passing the loaded aqueous liquid through a polysulphide reactor zone comprising one or more plug flow reactor zones, (b) contacting the loaded aqueous liquid with an oxidant to enable the sulphide-oxidising bacteria to oxidise sulphide to elemental sulphur, thereby producing an enriched aqueous liquid comprising an increased amount of elemental sulphur particles and (c) separating elemental sulphur particles from the enriched aqueous liquid, wherein the residence time of the loaded aqueous liquid between its preparation in step (a) and its supply to step (b) is between 3 and 45 minutes, and wherein the content of elemental sulphur as part of the polysulphide compounds in the loaded aqueous liquid [S.sup.0 in S.sub.x.sup.2?] as supplied to step (b) is above 0.7 mM.

Provided is a method for treating an oil gas, which can realize high-efficiency separation for and recovery of gasoline components, C.sub.2, C.sub.3, and C.sub.4 components. The method first conducts separation of light hydrocarbon components from gasoline components, and then performs subsequent treatment on a stream rich in the light hydrocarbon components, during which it is no longer necessary to use gasoline to circularly absorb liquefied gas components, which significantly reduces the amount of gasoline to be circulated and reduces energy consumption throughout the separation process. Besides, in this method, impurities, such as H.sub.2S and mercaptans, in the stream rich in the light hydrocarbon components are removed first before the separation for the components. This ensures that impurities will not be carried to a downstream light hydrocarbon recovery section, thus avoiding corrosion issues caused by hydrogen sulfide in the light hydrocarbon recovery section.

The present disclosure provides compositions and methods for using recombinant C1 metabolizing microorganisms capable of metabolizing sulfur containing compounds and other contaminants to biologically convert sour or acidic natural gas into high-value molecules, and to allow recovery of stranded oil.