Abstract: A wet scrubber (1) and a method of using the wet scrubber to clean a process gas containing sulphur dioxide comprising at least one spray level system (20) with atomizing nozzles (38) to which an absorption liquid is supplied for atomization by the nozzles (38). The method comprises operating the spray level system (20) in at least a first operating mode with an active nozzle density of at least 0.7 nozzles/m2, an absorption liquid flow of at least 10 m3/hour per nozzle and a Total Flow of at least 30 m3/hour/m2.

Abstract: The invention relates to an adsorber, including a reaction chamber, an adsorbent having adsorption properties enabling the at least partial removal of water from a gas stream including NOx and/or SOx, and a coating essentially consisting of a polymer material on at least a portion of the inner metal wall of the reaction chamber, said polymer being resistant to the acidic liquids at temperatures above 150° C.

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: The gaseous effluent is contacted with an aqueous solution comprising at least one amine and at least one amine degradation inhibiting compound. A stainless steel withstanding corrosion upon contact with the amine degradation inhibiting compound is first selected. Equipments whose surfaces in contact with the aqueous solution are made from this stainless steel are used.

Abstract: Embodiments of the present invention relate to a system and method for efficient removal of sulfur oxides (SOx), nitrogen oxides (NOx) and particulate matter (PM) contained in an exhaust gas generated from fuel combustion and efficient treatment of water containing microorganisms (e.g. ballast water).

Abstract: A method of scrubbing flue gas includes introducing flue gas comprising an acidic gas through an inlet into a tower; spraying an acid-absorptive fluid into the tower such that the acid-absorptive fluid contacts the flue gas; accumulating the acid-absorptive fluid in a recycle tank portion of the tower; and introducing an oxygen-containing gas into the acid-absorptive fluid in the recycle tank portion of the tower, wherein the oxygen-containing gas is introduced through at least one opening of an aerator, each of the at least one openings are positioned to release the oxygen-containing gas at least at a distance greater than or equal to a predetermined radial distance from the flue gas inlet, the predetermined radial distance being equal to at least 10% of a diameter of the recycle tank portion of the tower.

Abstract: A system and process are disclosed for selective removal and recovery of H2S from a gaseous volume, e.g., from natural gas. Anhydrous organic, sorbents chemically capture H2S gas to form hydrosulfide salts. Regeneration of the capture solvent involves addition of an anti-solvent that releases the captured H2S gas from the capture sorbent. The capture sorbent and anti-solvent are reactivated for reuse, e.g., by simple distillation.

Abstract: A method for treating a process gas with a liquid comprises contacting a process gas with a hygroscopic working fluid in order to remove a constituent from the process gas. A system for treating a process gas with a liquid comprises a hygroscopic working fluid comprising a component adapted to absorb or react with a constituent of a process gas, and a liquid-gas contactor for contacting the working fluid and the process gas, wherein the constituent is removed from the process gas within the liquid-gas contactor.

Abstract: An absorbent according to the present invention absorbs CO2 or H2S contained in flue gas emitted from a power generating plant such as a thermal plant, and contains three or more amine compounds selected from linear or cyclic amine compounds having a primary amino group, and linear or cyclic amine compounds having a secondary amino group. By way of a synergetic effect of the mixture of these compounds, the absorption speed of CO2 or H2S absorption is improved. A small amount of CO2 contained in a large amount of boiler flue gas can be absorbed efficiently.

Abstract: A method of assembling an acid gas component reduction system includes coupling at least one acid removal system in flow communication with at least one first synthetic gas (syngas) stream with at least one acid gas component having a first acid gas component concentration. The method also includes coupling at least one integral absorber in flow communication with the at least one acid removal system. The method further includes configuring the at least one integral absorber such that substantially continuous service of the at least one integral absorber facilitates producing a second syngas stream having a second acid gas component concentration that is less than the first acid gas component concentration.

Abstract: A method and apparatus for processing a sour gas rich in carbon dioxide in a Claus process, so sulfur compounds are removed by a selective solvent in a gas scrubbing process. Sulfur components and carbon dioxide, are separated into at least two sour gas fractions, wherein at least one sour gas fraction having a higher content of sulfur components is obtained, wherein the fraction having the highest hydrogen sulfide content is introduced in the thermal reaction stage of the Claus furnace with a gas containing oxygen by means of a burner. The sulfur is converted to sulfur dioxide in the thermal reaction stage of the Claus furnace and exhaust gases are discharged into the closed Claus reaction chamber behind the burner. The remaining sour gas fractions stripped of sulfur components are fed to the Claus reaction chamber and are mixed with the combustion gases leaving the burner.

Abstract: A process for workup of an industrial carbon dioxide-rich gas to be freed of sulfur components, in which an industrial gas to be freed of sulfur components is purified by a gas scrubbing, and the laden solvent is freed of carbon dioxide and hydrogen sulfide by a regeneration to obtain at least one acid gas fraction having a relatively high content of sulfur components, and the fraction with the highest hydrogen sulfide (H2S) content is supplied to a Claus plant with downstream Claus process gas hydrogenation, and at least one carbon dioxide-laden, low-hydrogen sulfide acid gas fraction from the regeneration device, which has a reduced sulfur content compared to the fraction with the highest hydrogen sulfide (H2S) content, is combined with the hydrogenated Claus process gas to give a combined process gas stream, which is supplied to further processing or to recycling into the process.

Abstract: Amine compositions comprising sterically hindered amines and associated methods are provided. In some embodiments, amine compositions of the present disclosure may be useful for selective removal of H2S from an acidic gas stream.

Abstract: A gas purification system including a hydrogen sulfide (H2S) absorber, a carbon dioxide (CO2) absorber, a flash tank, and a H2S concentrator. The gas purification system may also include a gas path though the H2S absorber prior to the CO2 absorber, a first solvent path sequentially through the CO2 absorber, the H2S absorber, and the H2S concentrator, and a second solvent path sequentially through the CO2 absorber, the flash tank, and the H2S concentrator, wherein the first and second solvent paths flow a common solvent.

Abstract: An IGCC plant has a precombustion decarbonization unit in which acid gas is removed from a combustion gas before the combustion gas enters a combustion turbine. In one preferred configuration, a sulfur removal unit removes hydrogen sulfide from a feed gas before the desulfurized feed gas enters an autorefrigeration unit in which carbon dioxide is removed. In another preferred configuration, hydrogen sulfide is converted to carbonyl sulfide in a dryer, and the carbonyl sulfide is absorbed in the liquid carbon dioxide that is prepared from the feed gas using autorefrigeration.

Abstract: Sulfur contaminants, such as elemental sulfur (S8), hydrogen sulfide and other sulfur components in fluids (e.g., air, natural gas, and other gases, as well as water and other liquids) are removed using a silicone-based chemical filter/bath. In one embodiment, a silicone-based chemical filter includes a membrane having a cross-linked silicone that is a reaction product of an olefin and a polyhydrosiloxane. For example, sulfur contaminants in air may be removed by passing the air through the membrane before the air enters a data center or other facility housing computer systems. In another embodiment, a silicone-based chemical bath includes a housing having an inlet port, an outlet port, and a chamber containing a silicone oil. For example, sulfur contaminants in air may be removed by passing the air through the silicone oil in the chamber before the air enters a data center or other facility housing computer systems.

Abstract: A sulfur dioxide absorbent comprising an ionic liquid comprised of alkyl ether-substituted imidazolium cation and an alkanesulfonate anion moieties possesses a high thermal/chemical stability, high SO2 absorption rate and low regeneration temperature, and is useful for an effective separation of SO2 from a combustion exhaust gas mixture or the like.

Abstract: This invention provides novel processes utilizing compositions comprising substituted polyamines as acid gas scrubbing solutions and methods of using the compositions in an industrial system. The invention relates to the use of such polyamine compounds in industrial processes to remove acidic contaminants from natural and industrial fluid streams, such as natural gas, combustion gas, natural gas, synthesis gas, biogas, and other industrial fluid streams. The compositions and methods of the invention are useful for removal, absorption, or sequestration of acidic contaminants and sulfide contaminants including CO2, H2S, RSH, CS2, COS, and SO2.

Abstract: An ionic liquid solvent and gas purification method using the same are provided. The ionic liquid solvent consists of a main absorbent, a regulator for the main absorbent, an auxiliary absorbent, an activator, an antioxidant and water. The ionic liquid involves a low synthetic cost, low viscosity and high absorption capacity, and can be easily regenerated and recycled. The method, compared with traditional processes, has advantages such as a greater absorption capability and lower operation cost.

Abstract: A CO2 recovery apparatus includes a desulfurization tower which includes a desulfurization unit and a cooling unit, an absorption tower which includes a CO2 absorption unit and an acid washing unit, a regeneration tower, and an acid water production device configured to produce acid water by causing exhaust gas yet to be introduced into the desulfurization to come into contact with water. In the CO2 recovery apparatus, the water to be come in contact with the exhaust gas is condensed water that is generated in the desulfurization tower, the absorption tower, or the regeneration tower.

Abstract: Methods for removing sulfur from a gas stream prior to sending the gas stream to a gas separation membrane system are provided. Two schemes are available. When the sulfur content is high or flow is relatively high, a scheme including two columns where one tower is regenerated if the sulfur concentration exceeds a preset value can be used. When the sulfur content is low or flow is relatively low, a scheme including one column and an absorption bed.

Abstract: This invention provides novel compositions comprising substituted polyamines as acid gas scrubbing solutions and methods of using the compositions in an industrial system. The invention relates to the use of such polyamine compounds in industrial processes to remove acidic contaminants from natural and industrial fluid streams, such as natural gas, combustion gas, natural gas, synthesis gas, biogas, and other industrial fluid streams. The compositions and methods of the invention are useful for removal, absorption, or sequestration of acidic contaminants and sulfide contaminants including CO2, H2S, RSH, CS2, COS, and SO2.

Abstract: A method of removing gaseous byproducts from a gas stream includes generating via at least one partial-combustion device a gas stream that includes gaseous byproducts. The method also includes channeling the gas stream from the at least one partial-combustion device to a fluid compression device that is configured to increase a pressure of the gas stream. The method further includes channeling the gas stream to a gaseous byproducts removal system to absorb at least a portion of the gaseous byproducts from the gas stream using a solvent. The method also includes discharging at least a portion of the gaseous byproducts from the gaseous byproducts removal system.

Abstract: The present invention provides a method and apparatus for the treat en of process gas from an anaerobic digestion system or a landfill gas system. In one embodiment, the system comprises a caustic scrubber including a vertical column having a top and a bottom and including a counter current flow system, wherein a process gas stream flows up vertically through the column in counter current flow to a caustic liquid solution that flows downward through the column. The caustic liquid solution removes at least one acid from the process gas stream, wherein treated gas that is substantially free of acids bubbles out through an opening at the top of the vertical column.

Abstract: A separation and scrubbing system for exhaust gases includes a plurality of industrial discharge outlets, a separation unit, pipelines to direct exhaust gases from the industrial discharge outlets to the separation unit and pipelines to return treated exhaust gases to stacks corresponding to the industrial discharge outlets.

Abstract: A method of deacidizing a gaseous effluent comprising acid compounds where the gaseous effluent is contacted in C1 with an adsorbent solution so as to obtain a gaseous effluent depleted in acid compounds and an absorbent solution laden with acid compounds, the absorbent solution being selected for its property of forming two separable phases when it has absorbed an amount of acid compounds and when it is heated. The absorbent solution laden with acid compounds is then heated in E1 and E3 so as to separate two fractions: a first absorbent solution fraction depleted in acid compounds and a second absorbent solution fraction enriched in acid compounds. These two fractions are then separated in BS1. The second fraction is regenerated in C2 so as to release part of the acid compounds, and the first absorbent solution fraction and the regenerated absorbent solution are recycled as absorbent solution.

Abstract: Novel solvent composition for selective removal of COS from a gas stream containing same, said composition comprising a) at least one polyalkylene glycol alkyl ether of the formula R1O-(Alk-O)n—R2??(I) or 1,3-dimethyl-3,4,5,6-tetrahydro-2(1H)-pyrimidinone or a mixture of N-formylmorpholine and N-acetylmorpholine wherein R1 is an alkyl group having from 1 to 6 carbon atoms; R2 is hydrogen or an alkyl group having from 1 to 4 carbon atoms; Alk is an alkylene group, branched or unbranched, having from 2 to 4 carbon atoms, and n is from 1 to 10; and b) at least one alkanolamine compound of the formula R3NHR4OR6??(II) or at least one piperazine compound of formula wherein R3 is hydrogen, an alkyl group having from 1 to 6 carbon atoms, or the R4OH group; R4 is a branched or unbranched alkylene group having from 1 to 6 carbon atoms; R5, independently in each occurrence, is hydrogen or an hydroxyalkyl group having from 1 to 4 carbon atoms; and R6 is hydrogen, an alkyl group having from 1

Abstract: A method and system for dehumidifying flue gas from a flue gas-generating process that supplies the flue gas to a wet flue gas processor. A wet cooling tower supplies water to a wet flue gas processor to condense water from the flue gas and form a liquid mixture in the wet flue gas processor.

Abstract: A multi-stage scrubbing system comprises a pre-scrubber system structured to receive a vent stream therein and pre-scrub the vent stream with a pre-scrubber fluid. The pre-scrubber system includes a first outlet for discharging a pre-scrubbed vent stream and a second outlet for discharging a discharge stream of pre-scrubber fluid. A main scrubber system is fluidly coupled to the first outlet of the pre-scrubber system for receiving and further scrubbing the pre-scrubbed vent stream.

Abstract: The present invention is directed to water-dispersible, oil-soluble triazine sulfide-scavenging compositions for use in hydrocarbon recovery and processing applications. The compositions include a triazine component, a glycol ether component, and an optional alcohol component. The compositions contain a minor amount of water up to a maximum of about 15% by volume. The compositions can be used in any type of sulfide-scavenging operation and significantly reduce corrosion problems found with conventional triazine scavengers.

Abstract: An absorbent liquid according to the present invention is an absorbent liquid for absorbing CO2 or H2S or both from gas, in which the absorbent liquid includes an alkanolamine as a first compound component, and a second component including a nitrogen-containing compound having in a molecule thereof two members or more selected from a primary nitrogen, a secondary nitrogen, and a tertiary nitrogen or a nitrogen-containing compound having in a molecule thereof all of primary, secondary, and tertiary nitrogens. The absorbent liquid has an excellent absorption capacity performance and an excellent absorption reaction heat performance, as compared to an aqueous solution containing solely an alkanolamine and a nitrogen-containing compound in the same concentration in terms of wt %, and can recover CO2 or H2S or both from gas with smaller energy.

Abstract: The gaseous effluent to be treated is contacted in C1 with an absorbent solution selected for its property of forming two separable phases when it has absorbed an amount of acid compounds and when it is heated. According to the invention, the absorbent solution is regenerated in at least two stages in regeneration zones Z1 and Z2. At the end of the first regeneration stage in Z1, at least part of the partly regenerated absorbent solution is separated into two fractions in B1: a fraction rich in acid compounds and a fraction depleted in acid compounds. Fraction 10 rich in acid compounds is sent to the second regeneration stage in Z2. The fraction depleted in acid compounds and regenerated absorbent solution 6 from the second regeneration stage are recycled to absorption column C1. The method can be applied to combustion fumes decarbonation and to natural gas or synthesis gas deacidizing.

Abstract: Upon cooling to 15 to 45° C., a process for the treatment of raw product gas generated by pressure gasification of solid fuels comprises the removal of HCN and NH3 in a preliminary stage, of H2S and COS and possibly other sulfur-containing compounds in a first stage and of CO2 in a second stage by physisorption with cold oxygenate, and the pure product gas is supplied to the direct reduction of iron ore as reduction gas and/or as fuel gas. An improvement of the process consists in that recycle gas loaded with CO2 and steam, which is branched off from the circuit of the recycle gas of the direct reduction of iron ore, is admixed to the desulfurized product gas upon removal of the steam contained therein.

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: 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: An acid gas absorbent comprising a metal sulfonate, phosphonate or carboxylate of a hindered amine and a process for the selective removal Of H2S as well as other acidic components such as carbon disulfide, carbonyl sulfide and oxygen and sulfur derivatives of C1 to C4 hydrocarbons from mixtures containing such acidic components and CO2 using said absorbent.

Abstract: The invention provides a process for producing purified gas from feed gas comprising H2S, CO2 and HCN and/or COS, the process comprising the steps of: (a) contacting feed gas comprising H2S, CO2 and HCN and/or COS with a HCN/COS hydrolysis sorbent in the presence of water in a HCN/COS hydrolysis unit, thereby obtaining gas depleted in HCN and/or COS; (b) contacting the gas depleted in HCN and/or COS with absorbing liquid in an H2S/CO2 absorber to remove H2S and CO2, thereby obtaining the purified gas and absorbing liquid rich in H2S and CO2; (c) heating and de-pressurizing at least part of the absorbing liquid rich in H2S and CO2 to obtain hot flash gas enriched in CO2 and absorbing liquid enriched in H2S; (d) contacting the absorbing liquid enriched in H2S at elevated temperature with a stripping gas, thereby transferring H2S to the stripping gas to obtain regenerated absorbing liquid and stripping gas rich in H2S; and (e) leading at least part of the flash gas enriched in CO2 to the HCN/COS hydrolysis unit

Abstract: In one embodiment, a gas purification system is provided. The system includes a first solvent section having a first carbon dioxide (CO2) absorber, a hydrogen sulfide (H2S) absorber, and a first solvent path that routes a first solvent through the first CO2 absorber and the H2S absorber. The gas purification system also includes a second solvent section having a second carbon dioxide (CO2) absorber and a second solvent path that flows a second solvent through the second CO2 absorber. The gas purification system has a gas path though the first and second solvent sections, wherein the first and second solvent paths are separate from one another, and the first and second solvents are different from one another.

Abstract: The invention relates to a method for reducing polyhalogenated compounds in incineration plants comprising at least one combustion chamber. The aim of the invention is to provide a more efficient method. To achieve this, SO2 is separated from the flue gas in at least one gas washer and is recirculated to the combustion chamber.

Abstract: The present invention relates to a process for separating off CO2 from a gas stream, wherein in a second step the CO2 is removed from the CO2-absorbing agent by means of phase separation.

Abstract: The present invention relates processes of removal of acidic gases from a gas stream, comprising the steps of a) contacting a wash solution stream with said gas stream containing acidic gases to be removed to allow absorption of the acidic gases into the wash solution stream; b) withdrawing wash solution enriched with acidic gases from said wash solution stream at a first withdrawal level; c) cooling said withdrawn wash solution; and d) reintroducing said cooled wash solution to the wash solution stream at a first reintroduction level to form a mixed wash solution stream, said first reintroduction level being upstream of said first withdrawal level. The present invention also relates to systems for removal of acidic gases from a gas stream.

Abstract: The present invention provides a method and apparatus for the treatment of process gas from an anaerobic digestion system or a landfill gas system. In one embodiment, the system comprises a caustic scrubber including a vertical column having a top and a bottom and including a counter current flow system, wherein a process gas stream flows up vertically through the column in counter current flow to a caustic liquid solution that flows downward through the column. The caustic liquid solution removes at least one acid from the process gas stream, wherein treated gas that is substantially free of acids bubbles out through an opening at the top of the vertical column.

Abstract: A method for regenerating an amine-containing scrubbing solution which is obtained during gas purification and in which CO2 and sulfur compounds are chemically bonded, as well as a system that is suitable for carrying out the method. The contaminated scrubbing solution is heated, compressed, and expanded in several stages such that CO2 and sulfur compounds are separated. The expanded scrubbing solution is subdivided into two partial streams, and one partial stream is recirculated into the process.

Abstract: A method for removing methane from biogas is described. The method includes: (i) receiving biogas including methane and other components into a first tank; (ii) receiving water into the first tank; (iii) contacting the biogas with the water inside the first tank; (iv) dispensing methane gas from an outlet of the first tank; and (v) producing from the tank an effluent stream that includes other components of the biogas.

Abstract: Vapor-liquid contacting apparatuses comprising a primary contacting zone and a secondary contacting zone are disclosed. A representative secondary contacting zone is a secondary absorption zone, such as a finishing zone for subsequent contacting of the vapor effluent from the primary contacting zone to further remove impurities and achieve a desired purity of purified gas exiting the secondary absorption zone. The secondary contacting zone is disposed below the primary contacting zone, such that the secondary contacting zone, which must operate efficiently in removing generally trace amounts of remaining impurities, is more protected from movement than the more elevated, primary or initial contacting stages for bulk impurity removal. The apparatuses are therefore especially beneficial in offshore applications where they are subjected to rocking.

Abstract: Methods for making sulfide scavenging compositions are provided. The compositions are secondary amine-formaldehyde adduct (SAFA) scavengers comprising less than about 40 wt % N-methyl secondary amines therein. The methods include reacting secondary amines with formaldehyde. Methods for removing sulfides from fluid streams are also provided. The methods include adding secondary amine-formaldehyde adduct (SAFA) scavengers to fluid streams. SAFA scavengers comprising less than about 40 wt % N-methyl secondary amines of the total weight of SAFA scavengers are also disclosed.

Abstract: An apparatus 100 for scrubbing flue gas 122, the apparatus 100 including a tower 140 having an inlet 120 receiving a flow of flue gas 122 and a recycle tank portion 142; a fluid 162 disposed in the recycle tank portion 142; and an aerator 150 having at least one opening 152 for introduction of an oxygen-containing gas 154 into the fluid 162, wherein the at least one opening 152 is positioned to release the oxygen-containing gas 154 at least at a distance greater than or equal to a predetermined radial distance F from the inlet 120, the predetermined radial distance F being equal to at least 10% of a diameter of the recycle tank portion 142.

Abstract: Disclosed are methods for recovering CO2 and H2S from a feed gas including at least CO2 and H2S.

Abstract: A method of introducing flue gas, from a flue stack in a steam-assisted production facility, into a heat exchanger. The flue gas comprises boiler combustion products selected from at least one of commercial pipeline gas and produced gas. The method begins by cooling a portion of the water vapor in the flue gas in the heat exchanger to produce flue gas water. This flue gas water is then collected and removed as make-up water.

Abstract: Production brines are used to scrub a horizontal stack receiving exhaust from an energy source, controlling, reducing, or both noxious chemicals. Mutual remediation of flows from petroleous production cool and scrub exhausts from flares burning waste hydrocarbons, heaters lowering viscosity of crude oil, engines driving oil pumps or natural gas compressors, and the like. Resulting evaporation of production brines results in distilled water, more concentrated brines to reduce hauling, or, optionally, dehydrated dry waste minerals from the brines. Year-round operation of brine evaporation ponds is facilitated, and may be another source of process pre-heating.