Abstract: A system for optimizing operation of an amine regeneration system comprising a flash tank, a rich/lean heat exchanger, a still, a reflux condenser, a reflux accumulator, a pump, a reboiler, and a flash tank pressurization assembly.

Abstract: Processing schemes and arrangements for the amine treatment of high olefin content (e.g., ethylene-rich) carbon dioxide-containing streams such as for the effective separation and removal of carbon dioxide therefrom are provided. Corresponding or associated processing schemes and arrangements for the catalytic cracking of a heavy hydrocarbon feedstock and obtaining light olefins substantially free of carbon dioxide via absorption-based product recovery are also provided.

Abstract: A method for removing CO2 in a exhaust gas from combustion of carbonaceous material, in which method the exhaust gas is brought in countercurrent flow with a liquid CO2 absorbent in a contact section of an absorption column, to produce a CO2 depleted exhaust gas that is released into the atmosphere and a CO2 rich absorbent that is withdrawn from the absorption column, wherein the exhaust gas is introduced into the absorption column at a temperature above about 90 and the exhaust gas is cooled in the absorption column by countercurrent flow of the liquid absorbent in the absorption column, is described.

Abstract: A system for optimizing start-up of an amine regeneration system comprising a rich/lean heat exchanger, a still, a reflux condenser, a reflux accumulator, a pump, a reboiler, and a reflux accumulator fill line assembly.

Abstract: Apparatus comprising an absorber device provided with a plurality of sequentially adjacent sections for flowing a gas stream therethrough. A conduit infrastructure comprising a section configured to ingress, communicate with and egress from each section of the absorber device, and a recovery and regeneration section, is configured with a plurality of heat exchange and cooling equipment. A process wherein a liquid solvent provided with at least one chemical compound selected for reacting with the selected gaseous component, is counter-flowed against and commingled with the gas stream. The liquid solvent temperature is controllably manipulated between each section of the column to provide: (a) thermodynamic-driven mass transfer at the front end of the absorber device, and (b) kinetic-driven mass transfer at the back end of the absorber device. The heat generated during the recovery of the gaseous component from the absorption liquid solvent system is recovered for use in regenerating solvent system.

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: Hindered cyclic polyamines and their salts are absorbents useful in acid gas treatment processes.

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

Abstract: An process for efficiently deacidizing a gaseous mixture is described. The process utilizes a self-concentrating absorbent that absorbs an acid gas at reduced overall energy costs for the deacidizing operation.

Abstract: A process for removing acid gas from a gas stream utilizes a low viscosity absorbent comprising a solution of at least one selected amine. The absorbent may include (1) at least one polyamine in the absence of an effective amount of tertiary amine functionalities having a pKa sufficient to neutralize carbamic acid, wherein the polyamine has at least one primary amine functionality having a pKa of <10.0 at 25° C. and wherein the feed gas stream has an SO2 concentration less than 5 ppm vol.; or (2) a polyamine in the absence of an effective amount of tertiary amine functionalities having a pKa sufficient to neutralize carbamic acid, wherein the polyamine has at least one secondary amine functionality having a pKa for each sorbing nitrogen of <10.0 at 25° C. The polyamines may include diethylenetriamine (DETA), triethylenetetramine (TETA) and tetraethylenepentamine (TEPA) or mixtures thereof.

Abstract: A method of deacidizing a gaseous effluent including acid compounds includes the following stages: a) contacting the gaseous effluent with a first fraction of an absorbent solution containing reactive compounds with at least two amine functions, so as to obtain a gaseous effluent depleted in acid compounds and a liquid effluent laden with acid compounds, b) contacting the liquid effluent obtained in stage a) with a second fraction of absorbent solution laden with molecules more acid than the acid compounds, so as to cause formation of a first liquid phase depleted in acid compounds and a second liquid phase enriched in acid compounds and laden with more acid molecules, c) separating the first phase from the second phase, and d) regenerating the second phase so as to release a gas stream rich in acid compounds and a liquid stream poor in acid compounds and laden with more acid molecules.

Abstract: The present invention is related to a system for removal of moisture and contaminants from recirculated flue gas. The system includes a spray tower for spraying the flue gas with a liquid reagent to remove contaminants from the flue gas. A heat exchanger, integrally connected to the spray tower, cools the liquid reagent before the reagent is sprayed onto the flue gas stream. Cooled liquid reagent improves the condensation of the water vapor in the flue gas during the spraying process and provides a lower moisture content flue gas exiting the system. Combustion process efficiency improves as flue gas redirected to the burner for combustion contains.

Abstract: Tetraorganoammonium and tetraorganophosphonium salts are useful as absorbents for the selective removal of acidic components from mixtures of said acidic components and CO2.

Abstract: A method of separating a mixture of carbon dioxide and a hydrocarbon gas using a metal-organic framework (MOF) material having a three-dimensional carborane ligand structure.

Abstract: This invention provides a method and process for the facile extraction of selected gases by means of a permeable membrane module, also known as a permeator, with effective and beneficial control of temperature the apparatus allowing temperature gradients or isothermal operation. The isolation and removal of subject gases, particularly those arising from combustion, i.e., combustion gases, is usually accomplished by means of absorber and stripper towers containing various packings to facilitate gas-liquid interaction. The inlet temperature has to be controlled but the temperature varies along the length of the tower height. In contrast, a membrane-based separation device, whether it is a permeator design or a traditional two body absorber and stripper, operates better, particularly if driven by a catalyst, under a controlled temperature regimen.

Abstract: The invention relates to a fluid separating device with a lower section with a fluid feeding device and a liquid discharging device, an upper section with a fluid feeding device and a gas discharging device, a contact device which is constructed in such a manner that gas, which rises from the lower section into the upper section, comes into contact with liquid which sinks from the upper section into the lower section. Thereby, the rising gases can be depleted of components which are soluble in said liquid. Furthermore, a measuring device for determining the quantity of liquid and/or the alterations thereof is provided.

Abstract: The current invention provides methods and apparatus for integrating a high temperature waste heat recovery system with a chemical or refining process which requires heat energy at a temperature less than the operational temperature of the waste heat recovery system. Additionally, the current invention provides methods and apparatus suitable for retrofitting existing process units requiring heat energy at a temperature of T2 with a waste heat recovery system operating at temperature of T1 where T1 is greater than T2.

Abstract: A system (10) for absorbing an acidic component from a process stream (22), the system including: a process stream (22) including an acidic component; an absorbent solution to absorb at least a portion of the acidic component from the process stream (22), wherein the absorbent solution includes an amine compound or ammonia; an absorber (20) including an internal portion (20a), wherein the absorbent solution contacts the process stream (22) in the internal portion of the absorber; and a catalyst (27) to absorb at least a portion of the acidic component from the process stream (22), wherein the catalyst is present in at least one of: a section of the internal portion (20a) of the absorber (20), the absorbent solution, or a combination thereof.

Abstract: The present invention is directed to an improved method and system for separating and purifying gas using gas-liquid absorption. According to this invention, the method is carried out in an absorber, where a liquid absorbent, a gas mixture containing a gas to be absorbed were introduced from an inlet. During absorption, the second liquid phase was separated out from the absorbent. The absorbed gas was accumulated in one of liquid phases. After absorption, two liquid phases were separated. One of the liquids with rich absorbed gas was forward to regenerator. After regeneration, the liquid was cycled back to absorber. The liquid phase with lean absorbed gas was back to absorber directly to complete the cycle.

Abstract: All sulfur compounds can be efficiently removed from natural gas that contains hydrogen sulfide and other sulfur compounds such as mercaptan without using physical absorption. The process comprises an absorption step of treating natural gas by means of a chemical absorption method using an amine-containing solution to mainly remove hydrogen sulfide and carbon dioxide, an adsorption step of flowing the natural gas from the absorption step through a packed bed of a molecular sieve to mainly remove mercaptan, a recovery step of recovering sulfur compounds by converting the hydrogen sulfide removed in the absorption step into sulfur by means of the Claus process, a regeneration step of desorbing the mercaptan adsorbed on the molecular sieve in the adsorption step using heated gas and a reaction step of converting the mercaptan in the regeneration exhaust gas exhausted from the regeneration step into hydrogen sulfide.

Abstract: The invention relates to the use of a liquid, containing 0.1 to 100% of an amine or several amines of formula H2N—CH2(CHR2)x—(OCH2(CHR3)y)z—OR1, where R1?C1 to C6 alkyl, R2?H or CH3, R3?H or CH3, x=0 to 3, y=0 to 3, z=0 to 10 and 0 to 99.9% of any further solvent including piperazine and/or water for separating acid gas components from technical gases.

Abstract: A method is provided for removing acid gases and ammonia from a fluid stream in which a fluid stream comprising acid gases and ammonia is brought into contact with an aqueous absorption medium. The fluid stream is depleted of acid gases and ammonia and the absorption medium stream, which is charged with acid gases and ammonia, is regenerated in a desorption step. The acid gases and the ammonia are stripped out of the absorption medium and the condensable fractions thereof are condensed. A condensate and also a purified absorption medium stream are obtained. The condensate is ejected in part or completely from the desorption step, or feed in part or completely to a distillation column in which ammonia is separated off overhead as an aqueous solution or in the pure state. A aqueous bottom stream is obtained which is recycled to the absorption step or the desorption step.

Abstract: A method for obtaining an acid gas stream having a pressure of from 3 to 30 bar by removal of acid gases from a fluid stream containing H2S, the molar fraction of H2S based on the total amount of acid gases being at least 50 mol %, the method comprising bringing the fluid stream into intimate contact with a liquid absorption medium, thus producing a fluid stream substantially freed from acid gases and an acid-gas-loaded liquid absorption medium; separating the fluid stream and the liquid absorption medium; separating, by heating and optionally by expansion or stripping, the liquid absorption medium into an acid gas stream and a regenerated liquid absorption medium; passing the regenerated liquid absorption medium into a heat exchanger and cooling it there by using part of its thermal energy to heat up the acid-gas-loaded liquid absorption medium; and recirculating the regenerated liquid absorption medium.

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 combustion fume flowing in through line 1 is decarbonated by contacting with a solvent in column C2. The solvent laden with carbon dioxide is regenerated in zone R. The purified fume discharged through line 9 comprises part of the solvent. The method allows to extract the solvent contained in the purified fume. The purified fume is contacted in zone ZA with a non-aqueous ionic liquid of general formula Q+ A?; Q+ designates an ammonium, phosphonium and/or sulfonium cation, and A? an anion likely to form a liquid salt. The solvent-depleted purified fume is discharged through line 17. The solvent-laden ionic liquid is regenerated by heating in evaporation device DE. The solvent separated from the ionic liquid in device DE is recycled.

Abstract: A system for removing carbon dioxide from an atmosphere to reduce global warming and increase availability of renewable energy including an air extraction system that collects carbon dioxide from the atmosphere through a medium and removes carbon dioxide from the medium; a sequestration system that isolates the removed carbon dioxide to a location for at least one of storage and generation of a renewable carbon fuel; and one or more renewable energy sources that supply heat to the air extraction system to remove the carbon dioxide from the medium.

Abstract: A system for removing carbon dioxide from an atmosphere to reduce global warming and increase availability of renewable energy including an air extraction system that collects carbon dioxide from the atmosphere through a medium and removes carbon dioxide from the medium, a sequestration system that isolates the removed carbon dioxide to a location for at least one of storage and generation of a renewable carbon fuel, and one or more power supplying units that supply heat to the air extraction system to remove the carbon dioxide from the medium, at least one of the one or more power supplying units being a concentrated solar power supplying unit.

Abstract: A process and apparatus for obtaining a hydrogen product and a sulfur product from a feed gas comprised of hydrogen sulfide. In the process, a first separating step separates the feed gas to obtain a first purified hydrogen sulfide fraction comprised of at least about 90 percent hydrogen sulfide by volume. A dissociating step dissociates hydrogen sulfide present in the first purified hydrogen sulfide fraction to convert it into a dissociated first purified hydrogen sulfide fraction comprised of elemental hydrogen and sulfur. A second separating step separates the dissociated first purified hydrogen sulfide fraction to obtain a hydrogen rich fraction comprised of elemental hydrogen. The sulfur product may also be obtained from the dissociated first purified hydrogen sulfide fraction. Finally, the hydrogen product is obtained from the hydrogen rich fraction. The apparatus is provided for performing the process.

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 process for the removal of hydrogen sulfide and mercaptans from a gas stream containing a high ratio of mercaptans to hydrogen sulfide, wherein the first step removes hydrogen sulfide by washing the gas stream with an aqueous washing solution comprising water, a physical solvent and a chemical solvent. The first removal step is followed by a second removal step by which mercaptans are removed from the washed gas stream by means of molecular sieves.

Abstract: The gaseous effluent flowing in through line 1 is contacted in absorption zone ZA with the liquid absorbent solution flowing in through line 9. The gaseous effluent depleted in acid compounds is discharged through line 2. The absorbent solution laden with acid compounds is discharged through line 3. The absorbent solution once laden with acid compounds comprises two phases: a first phase poor in acid compounds and a second phase rich in acid compounds. The two phases are separated in zone ZS. The first phase is recycled through lines 5 and 9 to absorption zone ZA. The second phase is fed through line 4 into regeneration zone ZR. In zone ZR, the acid compounds are separated from the absorbent solution. The acid compounds are discharged through line 7. The regenerated absorbent solution is recycled through lines 6 and 9 to zone ZA.

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: The invention relates to the use of an absorption liquid for purifying gases from gaseous acidic contaminants, the absorption liquid comprising A) 0.1 to 100% by weight of one or more amines of the formula I where R1 is H, C1-C6-alkyl, an aromatic radical having 6 to 18 carbon atoms or a radical of the formula 2 R2 is H, C1-C6-alkyl, an aromatic radical having 6 to 18 carbon atoms or a radical of the formula 3 R3 is C1-C6-alkyl or an aromatic radical having 6 to 18 carbon atoms R4 is H or CH3 R5 is H or CH3 x is a number from 0 to 3 y is a number from 0 to 3 z is an integer between 1 and 30, and also, if appropriate, B) 0 to 99.9% by weight of water, and/or C) 0 to 99.9% by weight of any desired solvent.

Abstract: Methods and configurations are drawn to a plant in which an effluent gas with a sulfur dioxide content of more than 1.5% is mixed with a substantially sulfur dioxide free offgas from a contactor to form a mixed feed gas for a hydrogenation reactor, wherein the mixed feed gas has a sulfur dioxide content of less than 1.5%.

Abstract: A process for the abatement of hydrogen sulphide in refinery gases by means of a liquid-ring compressor (10) uses, as service liquid, an aqueous solution of amines already available in the refinery itself. The process also comprises a stage of washing of the gas discharged by the compressor, by means of a column (20) mounted on a three-phase separator supplied with a regenerated solution of amines. The treatment in the liquid-ring compressor enables an effective abatement of the amount of hydrogen sulphide to be achieved, which can be further improved by washing using a regenerated amine solution supplied to the column set above the liquid/gas separator (18) downstream of the compressor.

Abstract: A process for removing contaminants from a waste gas stream comprises treating the waste gas stream to remove at least one of SO2 and NOx and to obtain a lean stream having a reduced level of at least one of SO2 and NOx and, contacting the lean gas stream with a mercury absorbent solution comprising permanganate to remove mercury vapour and to obtain a mercury lean stream and a mercury rich absorbent solution. The mercury rich absorbent solution may be subsequently treated on a batch basis to remove precipitated manganese dioxide and obtain a solution containing mercury ions.

Abstract: An acid gas removal plant includes an absorber that provides a rich solvent to two regenerators that independently generate a lean and a semi-lean solvent, wherein the semi-lean solvent is produced in one of the regenerators using heat and/or steam derived from the other regenerator. Further heat integration is particularly contemplated with power plants in which the power plant provides high-level heat to the acid gas removal plant and wherein the power plant receives low-level heat from the acid gas removal plant.

Abstract: The disclosure relates to an absorbent for removing acid gases from fluids. The absorbent contains at least one tertiary amine, an amine which is selected from hydroxyethylpiperazine, bis(hydroxyethylpiperazine) or a mixture of these and piperazine. The absorbent may optionally contain a physical solvent for the acid gases.

Abstract: An integrated environmental control system for cabin air of an aircraft or spacecraft. Humidity and temperature of cabin air are controlled with a direct contact liquid air contaminant control system that revitalizes cabin air by removal of carbon dioxide and other trace gas contaminants through use of a direct contact air, liquid scrubber element and stripper element. The scrubber element has two rotor elements rotatably mounted in a housing first for centrifugal separation of an air flow and liquid absorbent mixture which liquid absorbent has absorbed carbon dioxide and trace gas contaminants. Then second for centrifugal separation of an air flow and acid water wash mixture which acid water wash has liquid absorbent and other contaminants. The processed air is then passed through a charcoal bed filter for further removal of contaminants. A rotary contact processor may also be used to reprocess contaminated liquid absorbent for reuse.

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: A method of treating an acidic component in an exhaust gas includes contacting the exhaust gas with an aqueous solution including a water-soluble amine that produces a water-soluble salt when reacted with the acidic component of the exhaust gas.

Abstract: The invention relates to a method for the removal of carbon dioxide from a gas flow with a carbon dioxide partial pressure in the gas flow of less than 200 mbar, whereby the gas flow is brought into contact with a liquid absorption agent, selected from an aqueous solution (A) of an amino compound with at least two tertiary amino groups in the molecule and (B) an activator, selected from the primary and secondary amines, or (A) a tertiary aliphatic amine, the reaction enthalpy ?RH for the protonation of which is greater than that for methyldiethanolamine and (B) an activator, selected from 3-methylaminopropylamine, piperazine, 2-methylpiperazine, N-methylpiperazine, homopiperazine, piperidine and morpholine. The method is particularly suitable for the treatment of flue gases and also relates to an absorption agent.

Abstract: An amine recovery apparatus includes a carbon dioxide absorption section and plural water washing sections. The carbon dioxide absorption section brings the exhaust gas into vapor-liquid contact with an absorbing solution containing an amine compound and produces decarbonated exhaust gas. The water washing sections bring the decarbonated exhaust gas into vapor-liquid contact with washing water and sequentially recover the amine compound accompanying the decarbonated exhaust gas, while the decarbonated exhaust gas passes through the water washing sections in sequence from inlet portions to outlet portions thereof, respectively. The water washing sections have plural liquid reservoirs provided at the inlet portions of the water washing sections, respectively, and the liquid reservoirs reserve the washing water which is transported to the outlet portions of the water washing sections and supplied to the water washing sections, respectively.

Abstract: A system for optimizing operation of an amine regeneration system comprising a flash tank, a rich/lean heat exchanger, a still, a reflux condenser, a reflux accumulator, a pump, a reboiler, and a flash tank pressurization assembly.

Abstract: A system for optimizing start-up of an amine regeneration system comprising a rich/lean heat exchanger, a still, a reflux condenser, a reflux accumulator, a pump, a reboiler, and a reflux accumulator fill line assembly.

Abstract: An improved system and method for using polyethylene glycol (PEG) as a processing fluid additive for safely and effectively treating water-wet hogout propellant as well as any other water-wet propellants, explosives and hazardous wastes (solids and liquids) to make them compatible with the MSO process. The method includes the step of applying liquid PEG to the hazardous waste to create a slurry or feedstock that when fed directly into the MSO reactor vessel prevents the occurrence of smelt-water explosions due to the accumulation of dangerous levels of sodium chloride, and/or sodium sulfide in the molten salt bath. The PEG possesses special qualities that make it ideal for this purpose. It is a low cost, low viscosity, commercially available, non-hazardous (per OSHA standards), water soluble, low toxicity chemical that burns cleanly leaving little or no residue.

Abstract: A method is provided for making low-cost CO2 sorbents that can be used in large-scale gas-solid processes. The improved method entails treating an amine to increase the number of secondary amine groups and impregnating the amine in a porous solid support. The method increases the CO2 capture capacity and decreases the cost of utilizing an amine-enriched solid sorbent in CO2 capture systems.

Abstract: A system and method is disclosed for treating a mixture of hydrocarbon and carbon dioxide gas produced from a hydrocarbon reservoir. The system includes a gas power turbine adapted to burn the produced gas mixture of hydrocarbon and carbon dioxide gas with oxygen as an oxidizing agent and a capture system to collect the exhaust gas from the power turbine. An inlet compressor receives exhaust gas from the capture system and compresses the exhaust gas for injection of the exhaust gas into a hydrocarbon reservoir and for recycle to the power turbine. The system may further include a membrane system that preferentially removes carbon dioxide and hydrogen sulfide from the produced gas stream before said stream is used as fuel gas in the power turbine. The carbon dioxide and hydrogen sulfide removed by the membrane system is combined with the exhaust gas, and the combined gas is injected into a hydrocarbon reservoir.

Abstract: Hydrogen sulfide and mercaptans may be removed from a fluid or gaseous stream by reacting the hydrogen sulfide and mercaptans in the stream with a scavenger selected from a: (i.) 1,3,5-trisalkanylamino hexahydro-1,3,5-triazine derivative; (ii.) morpholine or piperazine derivative; (iii.) amine oxide; (iv.) alkanolamine; or (v.) aliphatic or aromatic polyamine.

Abstract: 1,3,5-(2H2,4H2,6H2) tripropanediamine N,N,N?,N?,N?,N? hexamethyl is used to scavenge sulfur compounds from hydrocarbons. A novel method of making the triazine comprises autocondensing (CH3)2NCH2CH2CH2N?CH2.