Abstract: A method of removing mercury from flue gases from combustion plants, such as for example power plants or waste incineration plants, is achieved in which mercury-containing flue gases are brought into contact with an adsorption reagent either directly or indirectly by being contained in an absorption reagent, whereby mercury is substantially adsorbed by the adsorption reagent during this contact. After adsorption has occurred the adsorption reagent is separated from the flue gases and subsequently from the absorption reagent and added to an aqueous solution containing an oxidizing agent, whereby the adsorbed mercury dissolves as Hg2+. The Hg2+-containing solution is subsequently separated from the adsorption agent and the Hg2+ then is removed from the solution. This method enables the mercury to be removed from flue gas in a simple and economical manner.

Abstract: A differential absorption spectrum for a reactive gas in a gas mixture can be generated for sample absorption data by subtracting background absorption data set from the sample absorption data. The background absorption data can be characteristic of absorption characteristics of the background composition in a laser light scan range that includes a target wavelength. The differential absorption spectrum can be converted to a measured concentration of the reactive gas using calibration data. A determination can be made whether the background composition has substantially changed relative to the background absorption data, and new background absorption data can be used if the background composition has substantially changed. Related systems, apparatus, methods, and/or articles are also described.

Abstract: A method for displacing acid gas constituents from natural gas to acid gas removal installations equipped with Claus installations with free capacities utilizes a portion of the acid gas which is removed from a first flow of natural gas containing acid gas. The acid gas removed from the first flow of natural gas is fed to at least one other acid gas removal installation, whereby this feeding results in the acid gas removed from the first flow of natural gas being mixed with at least one second flow of natural gas with which it is transported to at least one other acid gas removal installation.

Abstract: The invention relates to a gas liquid contactor and effluent cleaning system and method and more particularly to individually fed nozzle banks including an array of nozzles configured to produce uniformly spaced flat liquid jets shaped to minimize disruption from a gas. An embodiment of the invention is directed towards a gas liquid contactor having a plurality of modules including a liquid inlet and outlet and a gas inlet and outlet. An array of nozzles is in communication with the liquid inlet and the gas inlet. The array of nozzles is configured to produce uniformly spaced flat liquid jets shaped to minimize disruption from a gas flow and maximize gas flow and liquid flow interactions while rapidly replenishing the liquid.

Abstract: An absorber (110) in a gas treatment plant (100) produces a rich solvent (116) that is flashed to produce flashed rich solvent (134D) and recycle gas (132D), wherein the recycle gas (132D) is not mixed with the absorber feed gas (112) as commonly practiced, but mixed with the rich solvent (116). Such configurations exhibit superior rich solvent loading, thereby reducing solvent circulation. Further contemplated gas treatment plants (100)may also include a regenerator (150) in which carbon dioxide from atmospheric flashed vapor (142) of the rich solvent (144) is employed as a stripping gas in a regenerator (150) to strip hydrogen sulfide from the rich solvent (144), and wherein sweet gas (114) is employed to strip the carbon dioxide from the rich solvent (144).

Abstract: A process for the removal of sour gas from pressurized natural gas which is polluted by sulphur compounds and other sour gas compounds includes initially feeding natural gas into a sour gas absorption unit, in which the sulphur components and any other components are absorbed by a physically acting solution yielding a sour gas rich absorbent. The absorbant is heated and fed into a high-pressure flash unit, in which the desorbed sour-gas is separated yielding a sour gas poor absorbent. The desorbed sour gas is cooled and the vaporized absorbent is condensed out of the sour gas stream. The sour-gas poor absorbent from the high-pressure flash unit is freed from residual sour gas in a gas stripping unit by stripping gas. The absorbent obtained in the sour gas unit is cooled and recycled permitting the desorbed sour gas to be condensed by cooling water or cooling air.

Abstract: An acid gas absorbent comprising an alkylamino alkyloxy (alcohol) monoalkyl ether and a process for the selective removal Of H2S from gaseous mixtures containing H2S and CO2 using an absorbent solution comprising an alkylamino alkyloxy alcohol monoalkyl ether.

Abstract: A method for removing sulfur-containing compounds is provided. In one embodiment, the method includes selectively separating a feed stream (118) comprising carbon dioxide and one or more sulfur-containing compounds, including hydrogen sulfide, at conditions sufficient to produce a first stream (122) comprising carbon dioxide and hydrogen sulfide and a second stream (124) comprising carbon dioxide and hydrogen sulfide. A molar ratio of carbon dioxide to hydrogen sulfide in the first stream is greater than a molar ratio of carbon dioxide to hydrogen sulfide in the second stream, and a molar ratio of hydrogen sulfide in the first stream to hydrogen sulfide in the second stream is about 0.005 or more.

Abstract: A process for purifying CO2 offgas streams to free them of chemical compounds, and to the recycling of the purified gas streams into the production process.

Abstract: Carbon dioxide, methane, nitrous oxide and three groups of fluorinated gases have been referred to as greenhouse gases and the most offensive gases in contributing to Global Warming This invention comprises the use of Titration and other chemical oxidation—reduction reactions in novel ways to scrub these gases from the Earth's atmosphere. The invention comprises identifying, developing, and spraying base aerosols to neutralize carbon dioxide, nitrous oxide, sulphur dioxide, and similar compounds whose oxides form acids when dissolved in water vapor. Acid-base titrations result in neutralization of the acid and the base. The formation of a salt and water typically are by-products. Salt precipitates such as CACO3—calcium carbonate or limestone settle into the oceans naturally forming limestone deposits which act as homes for microscopic sea life. Carbonic acid which results from CO2 being dissolved in water produces calcium carbonate when treated with a base.

Abstract: A method of treating exhaust gases is described comprising the introduction of a treatment composition including or comprising a micelle encapsulating compound. A preferred embodiment the treatment comprises by volume; from about 4 to about 40 parts of an alkoxylated C16-C18 tertiary amine surfactant, from about 1 to about 15 parts of at least one carboxylic acid having from 4 to 16 carbon atoms; about 1 to 6 parts of at least one of a C6-C14 alcohol, from 0 to 10 parts of a C4 and lower alcohol, with the balance being water to create a total of about 100 parts by volume. The treatment composition may be introduced into a confined flow path for exhaust gases at a rate of 0.1 to 6% although a range above and below that may be suitable. The invention also extends to a system for treating exhaust gases comprising a confined flow path for the exhaust gases and an application arrangement for applying a treatment composition comprising or including a micelle encapsulating surfactant.

Abstract: A plant includes a vacuum stripper (118) that receives a lean hydrogen sulfide-containing physical solvent (32) and in which substantially hydrogen sulfide-free stripping gas (51,52) is provided by at least one of a high-pressure flash vessel (110) and a medium pressure flash vessel (112). Contemplated configurations advantageously extend the range of use for physical solvents to treat sour gas comprising carbon dioxide and hydrogen sulfide, and can be used to meet most pipeline specification of 4 ppm hydrogen sulfide.

Abstract: Increasing the economic and environmental compatibility in treatment processes in sour gas production. For 25 yr, Mobil Erdgas Erdoel GmbH (MEEG) has been treating considerable amounts of sour gas in N. Germany. In 9 fields with different gas qualities, there are ca 30 producing wells. The main processes of the sour gas production and treatment are described. The gas is dried at the well site and if the reservoir pressure is not sufficient, compressed for transportation to the central processing facility. In most cases the use of sulfur solvents is necessary at the wells. Natural gas scrubbers for the total removal of hydrogen sulfide and Claus units with downstream units to obtain sulfur are utilized. To increase the environmental compatibility and economics, a number of secondary processes have been introduced for emission control; glycol stripping; and the Purisol, Selexol, Sulfinol, and Claus processes.

Abstract: Hydrogen sulfide is selectively enriched from an acid gas (1) that comprises relatively large quantities of carbon dioxide using a configuration in which a portion of an isolated hydrogen sulfide stream is introduced into an absorber (51) operating as a carbon dioxide rejecter. The resulting concentrated hydrogen sulfide enriched solvent (4) is then further used (directly or indirectly) to absorb hydrogen sulfide from an acid feed gas.

Abstract: A process for the reduction of carbonyl sulfide (COS) in a gas stream is described. It comprises contacting the gas stream with an iron oxide-based material. The present invention relates to the removal of COS from any type of gas stream, in particular those which include one or more of the group comprising ethane, methane, hydrogen, carbon dioxide, hydrogen cyanide, ammonia, hydrogen sulfide, and noble gases. These include natural gas, and in particular syngas. Syngas is useable in a Fischer-Tropsch process. The present invention provides a simple but effective process for the reduction of COS, especially with a material that can easily be located in existing guard beds—avoiding any re-engineering time and costs. The iron oxide-based materials can also be useable against other impurities, providing a single bed solution.

Abstract: The present application discloses compositions comprising ionic liquids and an amine compound, and methods for using and producing the same. In some embodiments, the compositions disclosed herein are useful in reducing the amount of impurities in a fluid medium or a solid substrate.

Abstract: The present invention provides a process for the absorption of sulfur dioxide from flue gases comprising the steps of: a) providing input seawater or brackish water; b) treating at least a portion of the seawater or brackish water to form a more concentrated solution of ions; and c) contacting the flue gas with an aqueous stream containing the concentrated solution to form flue gas with a reduced content of sulfur dioxide and a wash solution. wherein the treatment in stage (b) is a process selected from the group consisting of vacuum distillation, distillation, reverse osmosis, or any combination thereof.

Abstract: The invention relates to a method for cooling rising vapor (3) in a desorption column (2) by means of a condenser, which is situated at the head of the desorption column, is configured as an indirect heat exchanger and is traversed by a coolant (1). According to said method, the coolant enters at the bottom of the condenser (1) and flows upwards through conduits (8) that are arranged vertically in the condenser. The coolant is enriched with hydrogen sulphide prior to its entry into the condenser (1) and after the absorption of heat, escapes as an overflow (6) from the top of the condenser (1) through upper openings (10) of the conduits (8). The invention also relates to a desorption column (2) for carrying out said method.

Abstract: With the help of a method of selective removal of hydrogen sulphides, organic sulphur components and CO2 from crude gases, by using a first and second absorption stage (41 or 49) for separating almost pure CO2, a solution has to be found, with which, among other things, hydrogen sulphides and organic sulphur compounds can be removed in as selective a manner as possible. This is achieved as follows: the absorption agent coming out of the first absorption stage (41) and enriched with hydrogen sulphide and CO2 a.o.

Abstract: A gas (1) comprising hydrogen sulfide, carbon dioxide, and hydrocarbon contaminants is treated in a plant (FIG. 2) in a configuration in which waste streams are recycled to extinction. In especially preferred aspects of contemplated methods and configurations, hydrogen sulfide and other sulfurous components are converted to a sulfur product (37), carbon dioxide (44A) is separated at a purity sufficient for enhanced oil recovery or sale, and hydrocarbon contaminants are purified to a marketable hydrocarbon product (49).

Abstract: The invention provides a process for treating a loaded solvent stream having a time-varying contaminant concentration, the process comprising the steps of: (a) providing a plurality of hold-up tanks; (b) feeding the loaded solvent stream in dependence on its contaminant concentration to one or more of the hold-up tanks and; (c) allowing lowed solvent to flow from the plurality of hold-up tanks to obtain a smoothed loaded solvent stream having a reduced time-varying contaminant concentration. The invention further provides a treating unit comprising a circuit for circulating a solvent stream, which circuit includes a device for smoothing contaminant peak concentrations, said device comprising a plurality of hold-up tanks each hold-up tank having at least one inlet and an outlet equipped with an outlet valve, the device further comprising an inlet distributor allowing the control of solvent flow to one or more of the hold-up tanks.

Abstract: The invention relates to a process for the removal of, H2S and mercaptans from a gas stream comprising these compounds, which process comprises the steps of: (a) removing H2S from the gas stream by contacting the gas stream in a H2S-removal zone with a first aqueous alkaline washing liquid to obtain a H2S-depleted gas stream and a sulphide-comprising aqueous stream; (b) removing mercaptans from the H2S-depleted gas stream obtained in step (a) by contacting the H2S-depleted gas stream in a mercaptan-removal zone with a second aqueous alkaline washing liquid to obtain a mercaptan-depleted gas stream and an thiolate—comprising aqueous stream; (c) contacting the combined aqueous streams comprising sulphide and thiolates obtained in step (a) and step (b) with sulphide-oxidizing bacteria in the presence of oxygen in an oxidation reactor to obtain a sulphur slurry and a regenerated aqueous alkaline washing liquid; (d) separating at least part of the sulphur slurry obtained in step (c) from the regenerated aqueous al

Abstract: Compositions and methods related to the removal of acidic gas. In particular, the present disclosure relates to a composition and method for the removal of acidic gas from a gas mixture using a solvent comprising a diamine (e.g., piperazine) and carbon dioxide. One example of a method may involve a method for removing acidic gas comprising contacting a gas mixture having an acidic gas with a solvent, wherein the solvent comprises piperazine in an amount of from about 4 to about 20 moles/kg of water, and carbon dioxide in an amount of from about 0.3 to about 0.

Abstract: A solid is separated from a gas scrubber by collecting a solids burden not collected at a solids-collection device of a flue gas desulfurization system by adding at least one flocculant, flocculation aid or mixtures thereof, while using a separating device; wherein te flue-gas desulfurization system contains at least one absorption device disposed downstream from said solids-collection device.

Abstract: A process for separating the components of a multi-component gas stream is disclosed. The multi-component gas stream is contacted with a solvent in an extractor to produce an overhead stream enriched with unabsorbed component(s) and a rich solvent bottoms stream enriched with absorbed component(s). The rich solvent bottoms stream is then flashed at reduced pressure to regenerate lean solvent and to recover the absorbed component(s) as an overhead stream. The regenerated solvent is recycled to the extractor. A portion of the circulating solvent comprises external solvent added to the system. A second portion of the circulating solvent comprises internal solvent contained in the feed gas.

Abstract: A method for removing organic sulfur compounds from a vent gas is described. Also described is an apparatus for absorbing organic sulfur compounds from vent gas.

Abstract: There is disclosed herein a solution for removing a sulphur compound or carbon dioxide from a fluid and methods for its use, said solution comprising a metal at between about 0.05 to 25 percent by weight, an amine at between about 10 to 80 percent by volume and water. The sulphur compound may be hydrogen sulphide or a mercaptan. In one aspect, the method is practiced at temperatures significantly below zero.

Abstract: A method for contacting a liquid with a gas in which the gas is introduced into a vessel containing at least one hollow fiber membrane having a plurality of porous hollow fibers. The liquid is introduced into a lumen of at least a portion of the plurality of porous hollow fibers at a liquid pressure sufficient to overcome a resistance to wetting of the porous hollow fibers, thereby covering at least a portion of an outer surface of the plurality of porous hollow fibers with the liquid and providing intimate contact between the gas and the liquid.

Abstract: Disclosed is a method for the treatment of hydrogen sulfide. The method preferably includes forming a solvent-surfactant blend, preparing a microemulsion by combining the solvent-surfactant blend with a carrier fluid and contacting the hydrogen sulfide with the microemulsion. In preferred embodiments, the solvent-surfactant blend includes a surfactant and a solvent selected from the group consisting of terpenes and alkyl or aryl esters of short chain alcohols.

Abstract: A system and methods of reducing sulfur emissions are provided. In one embodiment, a method for reducing sulfur emissions is provided. The method includes routing at least a portion of an untreated gas to a low pressure absorber, removing at least a portion of sulfur from the untreated gas to create a low pressure absorber overhead gas, and further processing the low pressure absorber overhead gas.

Abstract: A compact and energy-efficient polluting gas desulfurization apparatus which reduces gas flow pressure loss and the consumption of electrical power. A drum is rotationally supported at its radial center by a horizontal shaft within a fixed duct having a gas inlet port at one end and a gas outlet port at the other end. The right and left sides of the drum and its circumferential surface are lattice-like structures, and the internal space of the drum is filled with gas-liquid contact filler pieces. A slurry holding tank is disposed beneath the rotating drum. Slurry, which is pumped upward by a circulation system, is discharged onto the top of the circumferential surface of the drum at a point offset from the horizontal shaft along the radial axis, thus forming a mechanism able to rotate the drum from the weight of the slurry only and thus eliminating the need for an electric motor.

Abstract: One embodiment of the present invention relates to a process for treating a flue gas stream (22) from a coal-fired boiler to reduce the amount of mercury contained therein. The process includes subjecting the flue gas stream (22) to a first wet scrubbing process for reducing the concentration of sulfur oxides therein and thereby producing a water-saturated flue gas stream (22) and subjecting the water-saturated flue gas stream to a second wet scrubbing process having an aqueous acidic solution comprising hydrogen peroxide to produce a flue gas having a reduced mercury content.

Abstract: Methods and systems for handling sour carbon dioxide (CO2) streams are provided. In one aspect, a method for sequestering an emissions-heavy gas includes removing at least a portion of an acid gas from a rich solvent in an acid gas stripper to create the emissions-heavy gas, and channeling the emissions-heavy gas to a storage system.

Abstract: The invention concerns a process for the removal of sulphur compounds from a hydrocarbon stream, especially a gaseous hydrocarbon gas stream, comprising said sulphur compounds, which process comprises contacting said gas stream with an adsorbent comprising a zeolite having a pore diameter of at least 5 ? to adsorb the sulphur compounds thereon, the adsorption process followed by a regeneration process of used, loaded adsorbent by contacting the said loaded adsorbent with a regeneration gas stream having a relative water humidity less than 100%, especially less than 80%. Suitably the regeneration is followed by a dry regeneration treatment. The invention further relates to a process for the regeneration of adsorbent comprising a zeolite having a pore diameter of at least 5 ? loaded with sulphur compounds by contacting the adsorbent with a regeneration gas stream having a relative water humidity less than 100%, especially less than 80%. Suitably the regeneration is followed by a dry regeneration treatment.

Abstract: A process for separating carbon dioxide from a fluid containing carbon dioxide, NO2, and at least one of oxygen, argon, and nitrogen comprises the steps of separating at least part of the fluid into a carbon dioxide enriched stream, a carbon dioxide depleted stream comprising CO2 and at least one of oxygen, argon, and nitrogen and a NO2 enriched stream and recycling said NO2 enriched stream upstream of the separation step.

Abstract: The natural gas arriving through pipe 1 is deacidified by being brought into contact with a solvent in zone C. The solvent charged with acid compounds is regenerated in zone R. The acid gases, released into pipe 5 upon regeneration, include a quantity of solvent. The method enables the solvent contained in the acid gases to be extracted. In zone ZA, the acid gases are brought into contact with a non-aqueous ionic liquid whose general formula is Q+ A?, where Q+ designates an ammonium, phosphonium, and/or sulfonium cation, and A? designates an anion able to form a liquid salt. The solvent is removed from the acid gases evacuated through pipe 6. The ionic liquid charged with solvent is regenerated by heating in an evaporator DE. The ionic liquid regenerated is recycled through pipes 8 and 9 to zone ZA. The solvent is evacuated through pipe 13.

Abstract: There is disclosed herein a solution for removing a sulphur compound or carbon dioxide from a fluid and methods for its use, said solution comprising sulphuric acid, a metal at between about 0.05 to 10 percent by weight, an amine at between about 10 to 80 percent by volume and water. In one aspect, the sulphuric acid is in the form of a chelating agent and in another it is in the form of a derivative of a sulphur-based acidic compound. The sulphur compound may be hydrogen sulphide, carbonyl sulphide or a mercaptan. In one aspect, the method is practiced at temperatures significantly below zero. In another aspect, this invention is an acid/amine solution comprising sulphuric acid, sulphuric acid in the form of a chelating agent, or a derivative of a sulphur-based acidic compound and monoethanolamine. This solution may be used as a source of monoethanolamine.

Abstract: The present invention is directed to an improved integrated process for the removal of heavy hydrocarbons, carbon dioxide, hydrogen sulfide, and water from a raw natural gas feed stream. More specifically, the integrated process of the present invention comprises a three step process involving the adsorption of heavy hydrocarbons and water on an adsorbent bed selective for the same, a subsequent aqueous lean amine treatment for the absorptive removal of acid gases, such as carbon dioxide and hydrogen sulfide, and an adsorptive removal of water. The process of the present invention results in a highly purified natural gas product stream.

Abstract: A plant includes an absorber (105) that receives a feed gas (10) at a pressure of at least 400 psig and comprising at least 5 mol % carbon dioxide, wherein the absorber (105) is operated at an isothermal or decreasing top-to-bottom thermal gradient, and wherein the absorber (105) employs a physical solvent to at least partially remove an acid gas from the feed gas (10). Such configuration advantageously provide cooling (108) by expansion of the rich solvent (21) generated in the absorber (105), wherein both a semi-rich solvent (13) generated and recycled to the absorber (105) and the feed gas (10) are cooled by expansion of the rich solvent (21).

Abstract: The present invention is directed to an improved integrated process for the removal of heavy hydrocarbons, carbon dioxide, hydrogen sulfide, and water from a raw natural gas feed stream. More specifically, the integrated process of the present invention comprises a three step process involving the adsorption of heavy hydrocarbons and water on an adsorbent bed selective for the same, a subsequent aqueous lean amine treatment for the absorptive removal of acid gases, such as carbon dioxide and hydrogen sulfide, and an adsorptive removal of water. The process of the present invention results in a highly purified dry natural gas product stream.

Abstract: Processing schemes and arrangements for separating hydrogen sulfide, carbon dioxide and hydrogen from a fluid stream including a solvent-based acid gas separation zone, a membrane separation zone and a pressure swing adsorption unit are provided. At least a portion of a carbon dioxide-lean non-permeate stream produce in the membrane separation zone is recycled to the acid gas separation zone to strip and recover co-absorbed carbon dioxide from the solvent. Recovered carbon dioxide can be beneficially combusted in an associated gas turbine to generate electricity. Additionally, a portion of a pressure swing adsorption tail gas stream and/or a sulfur recovery tail gas stream may also be recycled to the acid gas separation zone for further processing.

Abstract: One embodiment of the present invention relates to a process for treating a flue gas stream (22) from a coal-fired boiler to reduce the amount of mercury contained therein. The process includes subjecting the flue gas stream (22) to a first wet scrubbing process for reducing the concentration of sulfur oxides therein and thereby producing a water-saturated flue gas stream (22) and subjecting the water-saturated flue gas stream to a second wet scrubbing process having an aqueous acidic solution comprising hydrogen peroxide to produce a flue gas having a reduced mercury content.

Abstract: The present invention relates to a system and method for the recycling of sulfur hexafluoride (SF6), from a waste gas of a manufacturing process, such as a semiconductor processing method. In particular, the present invention provides a simplified system and method that utilizes additional SF6 as a purge gas for the system pump and allows relatively easy separation of the SF6 from the other waste gas components.

Abstract: In a wet-process gas treatment method of treating an acid gas by using at least two treating columns connected in series, a ratio of the concentration of an acid gas at an outlet to a concentration of the acid gas at an inlet of a first treating column is set higher than a ratio of the concentration of the acid gas at an outlet to the concentration of acid gas at an inlet of at least one of the other treating columns, thereby preventing deposits from forming in the interior of connecting pipes between the columns and in the interiors of the treating columns, to prevent the connecting pipes from being blocked.

Abstract: The use of turbulent contactors to simultaneously absorb selected acid gas components from a gas stream and flash off hydrocarbons entrained in a liquid stream which include a solvent or reagent for the selected gas component. In particular, the method comprises feeding the gas stream and liquid stream into a first contactor where they are contacted co-currently and subjected to turbulent mixing conditions, and passing the multi-phase flow from the first contactor to a second contactor. The multi-phase flow from the second contactor is subsequently separated into a gas phase and a liquid phase.

Abstract: An apparatus for removing constituents from a fluid stream is provided. The apparatus includes a duct, a collection device, a sorbent injector, and an acoustic generator. The duct has a fluid passageway to receive a fluid stream having constituents. The collection device filters the fluid stream. The sorbent injector injects a sorbent in the fluid passageway of the duct. The acoustic generator generates an acoustic field in the fluid passageway of the duct to promote sorption of the constituents for collection by the collection device. Additionally, a method is provided for removing constituents from a fluid stream.

Abstract: The raw natural gas is pretreated in treating unit 30. The treated gas is then purified by adsorption of the mercaptans in first enclosure 31. The various cuts that make up the purified gas are separated in fractionating unit 34. Part of the methane making up the purified gas is saturated with a C5+ hydrocarbon in contactor 33, then it is fed into second enclosure 32 so as to regenerate the adsorbent material contained in this second enclosure. The gas from the second enclosure is washed in unit 35, then recycled.

Abstract: This invention relates to a process for cleaning gas, in particular hydrocarbonaceous gas such as e.g. natural gas, which is contaminated with sulfur in the form of H2S and mercaptans as well as CO2. To remove the undesired sulfur-containing substances in the form of H2S and mercaptan from crude gas, it is proposed in accordance with the invention that the crude gas is introduced into an absorption and regeneration column and washed therein, three gas streams being withdrawn from this absorption and regeneration column, a first exhaust gas stream being introduced into a Claus plant, a second sour gas stream with a low H2S concentration being introduced into another absorption plant, and a third gas stream, the valuable gas with the mercaptans, being cooled and supplied to an adsorption plant, that from this adsorption plant a cleaned valuable gas is withdrawn, and a mercaptan-containing gas stream is subjected to washing, that this concentrated mercaptan-containing gas is supplied to the Claus plant.

Abstract: The arrangements described herein are based upon a theory of selective absorption of hydrogen sulphide over carbon dioxide from gas based on countercurrent contact between gas and tertiary or other amines which exhibit preferential affinity for H2S over CO2 primarily because of differential rates of absorption of the two gases. The process of enhanced selective absorption is accomplished by performing the absorption in two steps. The first operation is to contact lean amine with sour gas which contains both H2S and CO2. The object of the first operation is to produce an overhead gas that meets an arbitrary standard for content of H2S and CO2. The second operation is to enhance the selectivity for H2S by contacting the rich amine leaving the first operation with a second gas which is a highly concentrated acid gas having a higher H2S/CO2 ratio than the first acid gas.

Abstract: The invention relates to a method for treating a natural gas, saturated or not with water, containing essentially hydrocarbons, a substantial amount of hydrogen sulfide and possibly carbon dioxide. The method of the invention comprises a condensation stage intended to condense a major part of the water, a distillation stage wherein a gaseous effluent depleted in hydrogen sulfide and substantially free of water is recovered, and a contacting stage wherein the gaseous effluent from the previous stage is contacted with a solvent so as to obtain a treated gas substantially free of hydrogen sulfide and possibly of carbon dioxide.