Abstract: A plant comprises a feed gas source, H2S removal unit, first absorber and a second, pressure reduction stages, first and second heat exchangers, stripping unit, and a conduit. The H2S removal unit selectively removes H2S from a feed gas from the feed gas source to produce an H2S depleted feed gas. The first absorber and the second absorber remove CO2 from the H2S depleted feed gas using a semi-lean and an ultralean solvent to produce a product gas and a rich solvent. The plurality of pressure reduction stages generates a cooled flashed solvent. The first heat exchanger and the second heat exchanger use the cooled flashed solvent to cool the H2S depleted feed gas and the semi-lean solvent. The stripping unit strips the flashed solvent with dried air to produce the ultralean solvent, and the conduit combines a portion of the ultralean solvent with the H2S depleted feed gas.

Abstract: This application is in the field of technologies for desulfurization and demercaptanization of raw gaseous hydrocarbons (including natural gas, tail gas, technological gas, etc, including gaseous media). It can be used for simultaneous dehydration and desulfurization/demercaptanization of any kind of raw gaseous hydrocarbons.

Abstract: A method for recovering sulfur from an acid gas feed is provided. The method comprising the steps of mixing the acid gas feed and an absorption process outlet stream to form a combined Claus feed, introducing the combined Claus feed and a sulfur dioxide enriched air feed to a Claus process to produce a Claus outlet gas stream, introducing the Claus outlet gas stream to a thermal oxidizer, treating the thermal oxidizer outlet stream in a gas treatment unit to produce a dehydrated stream, introducing the dehydrated stream to a membrane sweeping unit to produce a sweep membrane residue stream and a sulfur dioxide enriched air feed, introducing a sweep air stream to a permeate side of the membrane sweeping unit, and introducing the sweep membrane residue stream to a sulfur dioxide absorption process to produce the absorption process outlet stream and a stack feed.

Abstract: A metal air battery having an air purification module and a method of operating the metal air battery, the metal air battery including: a battery cell module configured to generate electricity using oxidation of a metal and reduction of oxygen; an air purification module including a first adsorption unit and being configured to supply air purified by the first adsorption unit to the battery cell module, the first adsorption unit being configured to adsorb an impurity; and a detection module configured to detect a concentration of the impurity, wherein the air purification module further includes a recycling unit configured to desorbs the impurity adsorbed into the first adsorption unit; and a controller configured to control an operation of the recycling unit based on the concentration of the impurity detected by the detection module.

Abstract: A plant includes a pretreatment unit for H2S removal and air dehydration, and at least two absorbers that receive a feed gas at a pressure of at least 300 psig with variable CO2 content (e.g., between 5 to 60 mol %), wherein the feed gas is scrubbed in the absorbers with an ultralean and a semi-lean physical solvent, respectively, at low temperatures to at least partially remove the CO2 from the feed gas. Such configurations produces a low CO2 dry treated gas and a H2S-free CO2 for sequestration while advantageously providing cooling by expansion of the rich solvent that cools the semi-lean solvent and the feed gas, wherein an ultralean solvent is produced by stripping using dry air.

Abstract: A system for producing an oxygenate, comprising: a desulfurization apparatus for contacting a raw material gas comprising hydrogen and carbon monoxide with a desulfurizing agent comprising copper; and a synthesis apparatus for contacting the raw material gas treated by the desulfurizing apparatus with an oxygenate-synthesis catalyst comprising rhodium.

Abstract: A method for removing sulfur-containing compounds from a sulfur recovery unit (SRU) tail gas stream includes the steps of introducing the SRU tail gas stream to a reducing unit to produce a membrane feed, the reducing unit configured to reduce the sulfur-containing compounds to hydrogen sulfide, introducing the membrane feed to a hydrogen sulfide membrane unit, the hydrogen sulfide membrane unit comprising a membrane, wherein the membrane feed comprises hydrogen sulfide, allowing the membrane feed to contact a feed side of the membrane such that hydrogen sulfide permeates through the membrane to a permeate side, and collecting the retentate gases that fail to permeate through the membrane to produce a stack feed, wherein the stack feed comprises retentate gases.

Abstract: A process for removing acid gases from a water vapor-containing fluid stream comprises a) providing an absorption liquid which is incompletely miscible with water; b) treating the fluid stream in an absorption zone with the absorption liquid to obtain an acid gas-depleted treated fluid stream and an acid gas-loaded absorption liquid; c) directing the treated fluid stream to a rehydration zone and treating the fluid stream with an aqueous liquid to volatilize at least part of the aqueous liquid; d) regenerating the loaded absorption liquid to expel the acid gases at least in part and obtain a regenerated absorption liquid, and directing the regenerated absorption liquid to step b); and e) separating, from the absorption liquid, an aqueous liquid that has condensed in the absorption zone, and directing the aqueous liquid to step c). The process allows for an efficient removal of water accumulated in the absorption liquid system.

Abstract: A coal fired Oxy boiler power plant with a condensate system, combustion system and post combustion CO2 capture plant configured and arranged to remove CO2 from a flue gas stream generated in the combustion system. The condensation system includes a plurality of serial low pressure heaters arranged in flow series downstream of the pump and at least one parallel low pressure heater arranged fluidly parallel to at least one of the serial low pressure heaters. Flue Gas Heat Recovery System, Flue Gas Condenser and Gas Processing unit are thermally integrated into the condensate system.

Abstract: A method of producing syngas comprising receiving raw syngas from a gasification unit; introducing the raw syngas and water to a syngas scrubber to produce unshifted syngas; introducing a first portion of unshifted syngas to a first cooling unit to produce cooled unshifted syngas and a first aqueous condensate comprising cyanide in an amount of 5-200 ppmw; recycling the first aqueous condensate to the syngas scrubber; introducing a second portion of unshifted syngas to a water gas shift unit to produce shifted syngas; introducing the shifted syngas to a second cooling unit to produce cooled shifted syngas and a second aqueous condensate comprising cyanide in an amount of less than 2.5 ppmw; contacting the cooled shifted syngas with the cooled unshifted syngas to produce modified syngas; and introducing the second aqueous condensate to a sour water stripper to produce stripped water and an acid gas comprising H2S, CO2, and ammonia.

Abstract: A solvent system comprising an ionic Liquid formed from a relatively acidic component and a nitrogenous base for the removal of acid gases from mixed gas streams is provided. Also provided is a process for removing acid gases from mixed gas streams using the disclosed solvent system. The solvent system may be utilized within a gas processing system.

Abstract: Disclosed is a transportable reformer for the catalytic primary reforming of hydrocarbons using steam at elevated pressure, comprising a reforming tube system, a furnace disposed about the reforming tube system, a plurality of manifolds in communication with the reformer tubes, a plurality of flue gas tunnels disposed beneath and in gaseous communication with the furnace, wherein each of the manifolds is integrally coupled to, disposed between, and supported by the opposing outer walls of an adjacent pair of flue gas tunnels such that the reformer is configured to be transportable as a single unit without additional support structures.

Abstract: Methods and apparatuses for separating CO2 and sulfur-containing compounds from a synthesis gas obtained from gasification of a carbonaceous feedstock. The primary separating steps are performed using a sour pressure swing adsorption (SPSA) system, followed by an acid gas enrichment system and a sulfur removal unit. The SPSA system includes multiple pressure equalization steps and a rinse step using a rinse gas that is supplied from a source other than directly from one of the adsorber beds of the SPSA system.

Abstract: The invention relates to methods for regenerating a used sorbent having a gas adsorbate adsorbed thereto. In particular, the used sorbent comprises liquid marbles. The liquid in the liquid marbles is comprised of a material or mixture of materials that selectively removes unwanted gaseous component in the gas to be purified.

Abstract: An air pollution control apparatus includes: a denitration unit that removes nitrogen oxides from a flue gas; a desulfurization unit that is installed on a gas flow downstream side of the denitration unit to remove the sulfur oxides in a flue gas 11B; a finish denitration and desulfurization unit that is installed on the gas flow downstream side of the desulfurization unit to perform finish denitration and desulfurization of NO2 and SO2; and a carbon dioxide recovery unit that is installed on the gas flow downstream side of the finish denitration and desulfurization unit to remove and recover the carbon dioxide in a flue gas.

Abstract: A system for absorbing and separating acid gases may include an absorbing tower in which a gas containing an acid gas is supplied, a recycling tower that is disposed close to the absorbing tower, an absorbent that absorbs an acid gas in the absorbing tower and discharges the acid gas back to the recycling tower while circulating through the absorbing tower and the recycling tower, and a condenser that is connected to the recycling tower and condenses an acid gas produced in the recycling tower, wherein a centrifugal separator that separates the absorbent, using a centrifugal force, is disposed at a lower portion in the absorbing tower.

Abstract: A method for treatment of a flue gas involves feeding the flue gas and a lean solvent to an absorber. The method further involves reacting the flue gas with the lean solvent within the absorber to generate a clean flue gas and a rich solvent. The method also involves feeding the clean flue gas from the absorber and water from a source, to a wash tower to separate a stripped portion of the lean solvent from the clean flue gas to generate a washed clean flue gas and a mixture of the water and the stripped portion of the lean solvent. The method further involves treating at least a portion of the mixture of the water and the stripped portion of the lean solvent via a separation system to separate the water from the stripped portion of the lean solvent.

Abstract: The present invention relates to a system and a method therefor capable of reducing the amount of heat which must be supplied to a regeneration tower for regenerating an absorbent in an acid gas capture process for such acid gas as carbon dioxide and provides a low energy-type acid gas capture system and method using recirculation of an absorbent capable of reducing energy consumption by recirculating the absorbent, from which acid gas has been pre-separated, to an absorption tower before supplying the absorbent to the regeneration tower in an acid gas capture system.

Abstract: A method and system for supplying additional hydrogen from a reservoir of stored hydrogen in a salt cavern to a hydrogen pipeline to assist in meeting customer demand for hydrogen is provided. Contaminants introduced while the stored hydrogen stream is in the salt cavern may cause the crude hydrogen stream to not have the required product purity specification. The stored hydrogen is removed from the salt cavern as a crude hydrogen stream and thereafter diluted with higher purity hydrogen formed from the pipeline to form a hydrogen product stream at or below the product purity specification. The hydrogen product can be formed without removal of any of the contaminants in the crude stream, thereby creating a more cost effective and simplified supply process compared to conventional processes employing a salt cavern for hydrogen supply.

Abstract: Disclosed is an aqueous solution for absorbing and recovering carbon dioxide from a carbon dioxide-containing gas, the aqueous solution containing an amino alcohol compound represented by Formula 1 and an amine compound represented by Formula 2, wherein R represents an alkyl group having 1 to 5 carbon atoms; and n represents 1 or 2, wherein X represents —NR1R2; Y represents —NR3R4; R1, R2, R3 and R4 may be the same or different, and each represents an alkyl group having 1 to 3 carbon atoms; and m represents an integer of 3 to 7.

Abstract: A process is provided for the removal of impurities from the exhaust gases being emitted from a power generation plant. A multi-stage temperature based separation system is being utilized. The removal of undesirable compounds/elements is accomplished by directing the exhaust gases from the power plant through a first stage cooling unit to lower the temperature of the exhaust gases to a first predetermined level that is below the boiling point of one or more of the undesired compounds/elements, diverting the resulting liquid to storage, directing the gas to a second stage cooling unit to further lower the temperature of the exhaust gases to a second predetermined level that is below the boiling point of several more of the undesired compounds/elements. The resulting exhaust gas is a very clean syngas that may be used in various commercial applications.

Abstract: A fossil fuel fired power plant for the generation of electrical energy comprises a water steam cycle and a plant (10) for the capture of CO2 from exhaust gases emitted by the power plant and a steam jet ejector (24) configured and arranged to receive an input steam flow from a low- or intermediate pressure extraction point in the power plant and to increase its pressure. It is further arranged to receive motive steam (25) from a further extraction point in the power plant. A steam line (27, 22) directs the steam of increased pressure from the steam jet ejector (24) to the CO2 capture plant (10). The power plant according to this invention allows the use of low-pressure steam for the operation of the CO2 capture plant, where the extraction of such steam affects the overall efficiency of the power plant to a lesser degree than in power plant of the state of the art.

Abstract: Apparatus for removing ammonia from a gas stream includes primary and secondary scrubbers each of which includes a gas inlet, a gas outlet, and a slurry atomizer. The gas inlet of the primary scrubber is operatively connected to a gas stream having ammonia contained therein. A primary slurry feed system operatively connected to the slurry atomizer of the primary scrubber feeds to the slurry atomizer a primary slurry composition of a molybdic acid at a pH level. The gas inlet of the secondary scrubber is operatively connected to the gas outlet of the primary scrubber. A secondary slurry feed system operatively connected to a slurry atomizer of the secondary scrubber feeds to the slurry atomizer a secondary slurry composition of a molybdic acid at pH level. The pH level of the secondary slurry composition is lower than the pH level of the primary slurry composition.

Abstract: This disclosure relates generally to vehicles with reduced emissions. More particularly, this disclosure relates to systems, methods, and apparatuses related to vehicles with reduced carbon dioxide emissions. The carbon dioxide emissions may be stored in a carbon dioxide clathrate.

Abstract: An absorber of a carbon dioxide capture system according to an embodiment includes: a release region for releasing carbon dioxide from an absorbing liquid supplied from a stripper; and a second gas-liquid contact unit to which carbon dioxide released in the release region is supplied together with exhaust gas discharged from a first gas-liquid contact unit. The absorbing liquid having released the carbon dioxide therefrom in the release region is supplied to the second gas-liquid contact unit by an absorbing liquid supply device. The absorbing liquid having passed through the second gas-liquid contact unit is guided to the first gas-liquid contact unit while bypassing the release region. The second gas-liquid contact unit brings the exhaust gas and the absorbing gas into contact with each other so as to cause the carbon dioxide contained in the exhaust gas to be absorbed in the absorbing liquid.

Abstract: A formulation and process for capturing CO2 use an absorption mixture containing water, biocatalysts and a carbonate compound. The process includes contacting a CO2-containing gas with the absorption mixture to enable dissolution and transformation of CO2 into bicarbonate and hydrogen ions, thereby producing a CO2-depleted gas and an ion-rich solution, followed by subjecting the ion-rich solution to desorption. The biocatalyst improves absorption of the mixture comprising carbonate compounds and the carbonate compound promotes release of the bicarbonate ions from the ion-rich solution during desorption, producing a CO2 gas stream and an ion-depleted solution.

Abstract: An exhaust gas treatment system comprising: a CO2 chemical absorption equipment comprising an absorption column which absorbs carbon dioxide (CO2) in a combustion exhaust gas discharged from a combustion device with the use of an absorbing solution comprising an amine compound as a main component and a regeneration column which regenerates the absorbing solution by desorbing CO2 from the absorbing solution which absorbed CO2; a flash tank which depressurizes the absorbing solution withdrawn from a lower part of the regeneration column to flash-evaporate the absorbing solution; a vapor recompression equipment which compresses the vapor generated by the flash tank; a temperature control device which adjusts the vapor compressed by the vapor recompression equipment to be within a predetermined temperature; and a piping for feeding the vapor adjusted to the predetermined temperature by the temperature control device to the regeneration column.

Abstract: A fossil fuel-fired power station having a removal apparatus for carbon dioxide which is located downstream of a combustion facility and through which an offgas containing carbon dioxide may flow is provided. The removal apparatus comprises an absorption unit and a desorption unit. The desorption unit is connected to a renewable energy source.

Abstract: According to one embodiment, a carbon-dioxide-recovery-type steam power generation system comprises a boiler that produces steam and generates an exhaust gas, a first turbine that is rotationally driven by the steam, an absorption tower allows carbon dioxide contained in the exhaust gas to be absorbed into an absorption liquid, a regeneration tower that discharges the carbon dioxide gas from the absorption liquid supplied from the absorption tower, a condenser that removes moisture from the carbon dioxide gas, discharged from the regeneration tower, by condensing the carbon dioxide gas using cooling water, a compressor that compresses the carbon dioxide gas from which the moisture is removed by the condenser, and a second turbine that drives the compressor. The steam produced by the cooling water recovering the heat from the carbon dioxide gas in the condenser is supplied to the first turbine or the second turbine.

Abstract: A method and process is described for producing negative carbon fuel. In its broadest form, a carbon-containing input is converted to combustible fuels, refinery feedstock, or chemicals and a carbonaceous solid concurrently in separate and substantially uncontaminated form. In an embodiment of the invention, biomass is converted via discrete increasing temperatures under pressure to blendable combustible fuels and a carbonaceous solid. The carbonaceous solid may be reacted to synthesis gas, sold as charcoal product, carbon credits, used for carbon offsets, or sequestered.

Abstract: A system for removing gaseous pollutants, such as mercury from flue gases of a solid-fueled furnace (17), includes a sorbent mill (34) that receives superheated steam and a sorbent (28), such as activated carbon, in a partially agglomerated state, that processes the sorbent (28) by de-agglomerating and comminuting the sorbent (28). An educator (35) transports the processed sorbent (28) to a distributor (36) that injects it into the flue gases at a contact location having a temperature between 500° F. and 900° F., whereupon the sorbent (28) adsorbs mercury from the flue gas. A particle collection device (24) removes the processed sorbent (28) having adsorbed mercury, from the flue gas.

Abstract: Provided are a front impurity-removing device with a compressor for compression of the exhaust gas from an oxyfuel combustion device to make impurities in the exhaust gas water-soluble and with a cooler for cooling of the exhaust gas compressed by the compressor to condense moisture in the exhaust gas to discharge drainage with the impurities dissolved, and at least a single rear impurity-removing device with a rear compressor for compression of the exhaust gas to a pressure higher than that of the compressor and a rear cooler to discharge drainage. A water sprayer for humidifying the exhaust gas from the oxyfuel combustion device and a front cooler are provided for producing and discharging drainage with impurities dissolved therein upstream of the compressor in the front impurity-removing device.

Abstract: Provided is a CO2 recovery system including: a high-pressure absorption tower; a high-pressure regeneration tower that partially regenerates a CO2 absorption solution from the absorption tower through a first liquid feed line; a second liquid feed line that extracts a semi-lean solution having a heat resistance temperature thereof or lower from the high-pressure regeneration tower and introduces a portion of the semi-lean solution into a middle stage of the high-pressure absorption tower; a branch line that introduces a rest of the semi-lean solution into a flash drum; a third liquid feed line that introduces a lean solution after adding pressure thereto into a top of the high-pressure absorption tower; a high-pressure CO2 compression device where high-pressure CO2 gas from the high-pressure regeneration tower is introduced; and a low-pressure CO2 compression device where low-pressure CO2 from the flash drum is introduced.

Abstract: The carbon dioxide recovery system includes: a first steam line 21a through which low-pressure steam 14L is fed from an intermediate-pressure turbine 12 to a low-pressure turbine 13; a second steam line 21b into which the low-pressure steam 14L is branched from the first steam line 21a; a first regulation valve V1 for regulating the opening of the low-pressure steam 14L from 100% to 0%; a second regulation valve V2 for regulating the opening of the low-pressure steam 14L from 0% to 100% depending on the amount of control provided to the first regulation valve V1; a first auxiliary turbine 22A for recovering power using the low-pressure steam 14L being fed; and a first steam feed line 25L through which exhaust steam 23 discharged from the first auxiliary turbine 22A is supplied as a source of heat to a reboiler 24.

Abstract: A CO2 recovery system includes an absorber 2 and a regenerator 3. The absorber 2 includes a CO2 absorbing section 21 and at least one water-washing section 22. The CO2 absorbing section 21 allows flue gas 101 to come into contact with a basic amine compound absorbent 103 so that the basic amine compound absorbent 103 absorbs CO2 in the flue gas 101. The at least one water-washing section 22 allows the decarbonated flue gas 101A in which the amount of CO2 has been reduced in the CO2 absorbing section 21 to come into contact with wash water 104A and 104B to reduce the amounts of the basic amine compounds entrained in the decarbonated flue gas 101A. The regenerator 3 releases the CO2 from the basic amine compound absorbent 103 containing CO2 absorbed therein.

Abstract: A method for producing a reaction product including at least one synthetic formulation that carbonates sufficiently, said method comprising: providing a first raw material, having a first concentration of M; providing a second raw material, having a second concentration of Me; and mixing the first raw material and the second raw material to produce a reaction product that includes at least one synthetic formulation having the general formula MaMebOc, MaMeb(OH)d, MaMebOc(OH)d or MaMebO(OH)d•(H2O)e, wherein M comprises at least one metal that can react to form a carbonate and Me is at least one element that can form an oxide during the carbonation reaction, wherein the at least one synthetic formulation is capable of undergoing a carbonation reaction, and wherein the at least one synthetic formulation is capable of undergoing volume change during the carbonation reaction.

Abstract: A target treatment volume for exhaust gas to be treated is specified based on the product of an actual flow rate of exhaust gas discharged toward a CO2 recovery device, and an exhaust gas treatment rate RG1, and a target recovery volume for CO2 to be recovered by the recovery device is specified based on the product of an actual volume of CO2 contained in the exhaust gas discharged from the generation source of the exhaust gas, the exhaust gas treatment rate RG1, and a CO2 recovery rate RCO2. RG1=TCO2/VG1 VG1: Flow rate of exhaust gas discharged from generation source of exhaust gas TCO2: Volume of exhaust gas to be treated by recovery device RCO2=CCO2/VCO2 VCO2: Volume of CO2 contained in exhaust gas to be treated by recovery device CCO2: Volume of CO2 to be recovered by recovery device.

Abstract: A method is described for separating CO2 and/or H2S from a mixed gas stream by contacting the gas stream with a non-aqueous, liquid absorbent medium of a primary and/or secondary aliphatic amine, preferably in a non-aqueous, polar, aprotic solvent under conditions sufficient for sorption of at least some of the CO2. The solution containing the absorbed CO2 can then be treated to desorb the acid gas. The method is usually operated as a continuous cyclic sorption-desorption process, with the sorption being carried out in a sorption zone where a circulating stream of the liquid absorbent contacts the gas stream to form a CO2-rich sorbed solution, which is then cycled to a regeneration zone for desorption of the CO2 (advantageously at <100° C.). Upon CO2 release, the regenerated lean solution can be recycled to the sorption tower. CO2:(primary+secondary amine) adsorption molar ratios >0.5:1 (approaching 1:1) may be achieved.

Abstract: Impurities in exhaust gas from oxyfuel combustor are removed using simple equipment to reduce installation cost. Compressor-based impurity removal system for compressing exhaust gas mainly composed of carbon dioxide from combustor before supply to carbon dioxide liquefier for removal of impurities in exhaust gas has impurity separators with compressors for compressing exhaust gas from combustor stepwisely to target pressure for liquefaction of carbon dioxide and with aftercoolers for cooling exhaust gas compressed by compressors, water condensed by cooling being discharged as drain, and alkaline agent supply unit for supplying alkaline agent to at least upstream side of aftercooler in first impurity separator. Impurities in exhaust gas are discharged through drain including alkaline agent.

Abstract: Provided are impurity separators which have compressors for supplying exhaust gas comprising carbon dioxide from oxyfuel combustor to target pressure stepwisely before supply to carbon dioxide liquefier and have aftercoolers for cooling exhaust gas compressed by the compressors stepwisely to target pressure, water condensed by cooling being discharged as drain; alkaline agent supply unit which supplies alkaline agent to upstream side of aftercooler in last impurity separator to discharge drain containing alkaline agent having removed impurities in exhaust gas from aftercooler in last impurity separator; and circulation line for supplying of drain from aftercooler in last impurity separator to upstream side of aftercooler in first impurity separator.

Abstract: An enhanced Fischer-Tropsch process for the synthesis of sulfur free, clean burning, green hydrocarbon fuels, examples of which include syndiesel and aviation fuel. Naphtha is destroyed in a hydrogen generator and recycled as feedstock to a syngas (FT) reactor in order to enhance the production of syndiesel from the reactor. A further variation integrates a second hydrogen generator capturing light hydrocarbon gas for conversion to hydrogen and carbon monoxide which supplements the Fischer-Tropsch reactor. The result is a considerable increase in the volume of syndiesel formulated. A system for effecting the process is also characterized in the specification.

Abstract: A hydrogen sulfide and carbonyl sulfide removal method using microwave plasma comprising a hydrogen sulfide and carbonyl sulfide containing mixed-gas supplying step, a microwave supplying step, a plasma flame forming step, a hydrogen sulfide and carbonyl sulfide decomposing step in which hydrogen sulfide and the carbonyl sulfide are dissociated into atomic units, a rebinding step in which atomic units are rebound so that combustible gases are generated, and a separately collecting step in which the gases are separated and then are separately collected.

Abstract: A CO2 recovery system 10A has a CO2 recovery unit 11, a compression unit 12, and a condensed-water supply line 65A that supplies condensed water 64 to an absorbent regenerator 14. The CO2 recovery unit 11 includes a CO2 absorber 13 and the absorbent regenerator 14. The compression unit 12 has a first compressor 61-1 to an nth compressor 61-n that compress CO2 gas 56 emitted from the absorbent regenerator 14, a first separator 63-1 to an nth separator 63-n that reduce moisture in the CO2 gas 56, and a first heat exchanger 66-1 that performs heat exchange between the CO2 gas 56 emitted from the first compressor 61-1 and the condensed water 64 emitted from the first separator 63-1.

Abstract: The present application relates to a system and a process for gas cleaning.

Abstract: A method of modeling phase characteristics of thermodynamic systems utilizing pseudo-properties strategy and a reduced number of variables is disclosed herein. The method describes a means of determining the probability of phase splitting of mixtures of materials at a given temperature, pressure, and composition by characterizing the functions that describe the system via pseudo-properties, and also by describing the system in n?1 or fewer variables, where n represents the number of components in the system of interest. In an embodiment, a multi-component system is characterized in one variable, thereby providing simplified thermodynamic models in a time-efficient manner. In addition, the information generated by this reduced-variable calculation can further be used as a starting point for calculations of equations of state.

Abstract: The present invention generally relates to methods and systems for carrying out a pH-influenced chemical and/or biological reaction. In some embodiments, the pH-influenced reaction involves the conversion of CO2 to a dissolved species.

Abstract: A process for removing impurities, in particular oxides of sulphur (SOx) and/or oxides of nitrogen (NOx) from oxygen-containing gas streams by scrubbing with at least one washing agent is described. In order to achieve effective gas purification in an economical manner even in the case of so-called large “oxyfuel” furnaces which operate with oxygen as fuel gas, it is proposed to convert the impurities at an elevated pressure of at least 2 bar with at least one basic constituent of the washing agent into salts and to wash out said impurities as dissolved salts.

Abstract: A flue-gas purification system includes a flue-gas cycling system, a reacting means, and an absorbent adding system having at least a catalytic absorbent, wherein the catalytic absorbent is being gasified for reacting with the flue-gas in the reacting means in a homogenous gas-gas phase reacting manner. Therefore, the purification system has fast reaction rate between the pollutants of the flue-gas and the catalytic absorbent, which is preferably ammonia, to efficiently remove pollutants, so as to effectively purify the flue-gas.

Abstract: The present disclosure provides a method and apparatus for extracting carbon dioxide (CO2) from a fluid stream and for delivering that extracted CO2 to controlled environments for utilization by a secondary process. Various extraction and delivery methods are disclosed specific to certain secondary uses, included the attraction of CO2 sensitive insects, the ripening and preservation of produce, and the neutralization of brine.

Abstract: The invention comprises a process for removal of hydrogen sulfide from gaseous mixtures. The process involves the use of a mixture of a physical absorption solvent and an ionic liquid. The mixtures provided improved absorption of hydrogen sulfide, when compared to physical absorption solvents without the ionic liquid at low partial pressures of hydrogen sulfide. A regeneration cycle involving the addition of a solvent, such as water, is used to regenerate the mixture.