Abstract: A process for inhibiting the formation of carbon and/or coke from a carbon-containing reactive gas stream on the permeate side of an oxygen ion transport membrane, or for increasing the oxygen partial pressure thereon, by separating a feed gas stream to form an oxygen-depleted gas stream on the retentate side and a gas stream containing oxygen reaction products on the permeate side. The permeate side is purged with the carbon-containing reactive gas stream, and at least a portion of the exhaust gas stream formed from the reaction of the reactive gas stream with the separated oxygen is recirculated to purge the permeate side.

Abstract: A process for the removal of CO.sub.2 and sulfur compounds from natural gas and raw synthesis gas wherein N-formylmorpholine and N-acetylmorpholine mixtures are used as the desorbent at temperatures between -20.degree. C. and +40.degree. C. at pressures of 10 to 150 bar in a scrubbing operation. The acid gases are removed from the absorbent by flashing and the regenerated absorbent is recycled to the absorbent.

Abstract: This invention is an integrated process which removes acidic gases such as H.sub.2 S, COS and CO.sub.2 from raw synthesis gas. The H.sub.2 S and COS is concentrated and separately recovered. The separately recovered CO.sub.2 is used as a moderator with the purified syngas in a combustion turbine. The process comprises separating H.sub.2 S and COS from a raw synthesis gas by absorption with a liquid solvent, removing coabsorbed CO.sub.2 by stripping the solvent with nitrogen, separating the H.sub.2 S and COS from the solvent and recovering sulfur from the H.sub.2 S and COS. The energy value of the CO.sub.2 and its value as a diluent in reducing NO.sub.x is recovered by using the CO.sub.2 as a moderator during combustion of the purified synthesis gas in a gas turbine.

Abstract: Methods are provided for the selective removal of CO.sub.2 from a multicomponent gaseous stream to provide a CO.sub.2 depleted gaseous stream having at least a reduction in the concentration of CO.sub.2 relative to the untreated multicomponent gaseous stream. In the subject methods, the multicomponent gaseous stream is contacted with CO.sub.2 nucleated water under conditions of selective CO.sub.2 clathrate formation, where the CO.sub.2 nucleated water serves as liquid solvent to produce a CO.sub.2 clathrate slurry and CO.sub.2 depleted gaseous stream. In a preferred embodiment, the CO.sub.2 clathrate slurry is then decomposed to produce CO.sub.2 gas and nucleated water. The subject methods find use in a variety of applications where it is desired to selectively remove CO.sub.2 from a multicomponent gaseous stream, including chemical feedstock processing applications and air emissions control applications.

Abstract: A method for reducing residual ammonia gas from a steam in a steam condenser. The method includes forming a condensate and a residual gas in a first stage, then forming a condensate curtain in the second stage and passing the residual gas through the condensate curtain prior to exiting the steam condenser. The method may be employed to remove ammonia and carbon dioxide gas from a geothermal steam.

Abstract: A system and method for removing a contaminant from a carrier gas is provided including the steps of: introducing a liquid into a fluid conduit, wherein the liquid is characterized by a first fluid flow rate and wherein the conduit is arranged to define a conduit periphery that completely encloses fluids within the conduit; introducing a carrier gas and a contaminant into the fluid conduit, wherein the carrier gas is characterized by a second fluid flow rate; arranging the fluid conduit to define an inclined conduit section and establishing the first fluid flow rate and the second fluid flow rate such that a succession of moving slugs are created in the inclined conduit section of the fluid conduit; providing an outlet flow of a third fluid downstream of the succession of moving slugs, wherein the third fluid includes the carrier gas; providing an outlet flow of a fourth fluid downstream of the succession of moving slugs, wherein the fourth fluid includes a combination of the liquid and at least a portion of

Abstract: A method of treating a fluid containing at least methane and at least one acid gas and producing the acid gas or gases in liquid form. The method includes a step of regenerating the solvent, operated at a pressure whose value is at least equal to the bubble pressure of the mixture of acid gases produced in liquid form, a step in which the gaseous fraction from the regeneration step is rectified in a contact zone by separating at least some of the solvent from the gaseous fraction, a step in which the gaseous fraction from the modification step is cooled to a given temperature to cause at least some of the gaseous faction to condense forming at least one liquid fraction enriched with liquid acid gases and a step during which the liquid fraction of gases is separated from the remaining gaseous fraction.

Abstract: A process train for treating a gas stream containing methane, nitrogen, and at least one of water vapor, acid gas, C.sub.3+ hydrocarbons and aromatic hydrocarbons, the gas stream typically, but not necessarily, being natural gas. The treatment train includes separation of methane from nitrogen by means of membranes that preferentially permeate methane and reject nitrogen. Preferred processes include both a dehydration step and an NGL removal step to treat the gas before it passes to the methane/nitrogen membrane separation step. The process train can also include additional steps, such as an acid gas removal step, or a cryogenic methane/nitrogen separation step.

Abstract: Water to be utilized is reacted with soda ash and lime to produce a less corrosive and foulant water. Reaction sludges are fed to a desulfurization unit, where SO.sub.x, NO.sub.x and CO.sub.2 abatement occurs; other industrial waste sludges and/or waters and/or gases can also be utilized in such connection. FIG. 1 is one of the possible process schemes of present invention.

Abstract: This invention provides a method for the removal of carbon dioxide present in gases which comprises bringing a CO.sub.2 -containing gas into contact with an aqueous solution containing at least one amine compound of the general formula ?1! ##STR1## wherein R.sup.1 to R.sup.8 may be the same or different and each represent a hydrogen atom or an alkyl group of 1 to 4 carbon atoms, and m is 0 or 1. The method of the present invention makes it possible to remove carbon dioxide efficiently. In particular, since carbon dioxide can be easily desorbed by heating the aqueous solution having absorbed carbon dioxide, the thermal energy required for regeneration of the aqueous solution can be reduced.

Abstract: This invention relates to a process for the separation of carbon dioxide and hydrogen sulfide from gases using a promoted methyldiethanolamine (MDEA) solution. In one broad respect, this invention is a gas separation process, including contacting an aqueous treating solution with a sour gas stream that contains carbon dioxide and hydrogen sulfide under conditions such that the gas stream is sweetened, wherein the aqueous treating solution contains methyldiethanol amine and 2-(2-aminoethoxy)ethanol in a ratio of at least about 2:1; and wherein the process is conducted in the absence of a reclamation step. By practice of this invention, the amount of 2-(2-aminoethoxy)ethanol that is converted to urea(bis-(2-hydroxyethoxyethyl)urea (BHEEU)) is minimized which obviates the need for a reclamation (regeneration) unit.

Abstract: A method of treating a gas, for example, natural gas containing at least one hydrocarbon and at least one acid gas to remove the acid gas from the natural gas and to produce at least one concentrated acid gas, wherein the gas is subjected to at least two stages of absorption using polar solvents having different properties.

Abstract: A process for the dehydration, deacidification and stripping of a gas, characterized in that:(a) at least one fraction of the gas is contacted with an aqueous phase containing methanol, the resultant gas being thus charged with methanol being withdrawn from stage (a);(b) the gas withdrawn from stage (a) is contacted with a mixture of solvents comprising methanol, water, and a solvent heavier than methanol, the gas leaving stage (b) being thus at least in part freed of the acid gases which it contained initially;(c) the mixture of solvent obtained from stage (b) is at least in part generated by special reduction and/or heating while liberating at least part of the acid gases, the mixture of solvent being at least partially regenerated, or being at the outlet of stage (c) recycled through stage (b); and(d) the gas obtained from (stage b) is refrigerated while producing at least an aqueous phase containing methanol which is at least in part recycled through stage (a).

Abstract: A process for producing a carbonic acid diester, a method of removing CO.sub.2 and an absorbent for CO.sub.2 and an apparatus therefor are provided and are capable of selective removing of CO.sub.2 by absorption from a CO-containing gas admixed with CO.sub.2 which is recovered from a reactor to thereby enable recycling CO to the reactor for use. The invention is characterized by (1) carrying out a reaction of an alcohol, carbon monoxide (CO) and oxygen in a reactor and withdrawing a gas (i) which contains CO and CO.sub.2 produced as a by-product of the reaction from the reactor; (2) contacting the withdrawn gas (i) with an alcohol solution so that at least part of the CO.sub.2 contained in the gas (i) is absorbed by the alcohol solution and removed from the gas (i), thereby obtaining a CO-containing gas (ii), and (3) recycling the CO-containing gas (ii) to the reactor. It is preferred that the gas (i) is subjected to vapor-liquid separation and a separated gas is contacted with the alcohol solution.

Abstract: A geothermal steam condenser for reducing residual ammonia gas from a geothermal steam. The present condenser includes a column attached to the condenser for forming a curtain of temperature conditioned condensate, such that residual ammonia gas is passed through the conditioned water curtain to be furthered absorbed prior to exiting the geothermal steam condenser.

Abstract: The process comprises a cold absorption step 2 for removing acid gas from natural gas using a solvent phase at a pressure P.sub.2 which delivers a purified gas 5; a step for depressurizing and separating resultant acidic solvent phase containing hydrocarbons (lines 4, 11), at a pressure P.sub.12 which is lower than pressure P.sub.2 in a column-heat exchanger 12 which delivers a purified gaseous effluent 13 overhead and a further solvent phase at the bottom (line 17) which is enriched in hydrogen sulphide; and a solvent phase regeneration step carried out in a distillation column 18 at a pressure P.sub.18 and no higher than pressure P.sub.12. A gas 29 containing essentially hydrogen sulphide which is depleted in hydrocarbons is recovered from column 18 and is a suitable feed for a Claus plant for eliminating H.sub.2 S. The regenerated hot solvent phase 20 indirectly exchanges heat with the cold acidic solvent phase from absorber 2 or separator 6. It is then recycled to the absorbent after cooling.

Abstract: Methods are provided for the selective removal of CO.sub.2 from a multicomponent gaseous stream to provide a CO.sub.2 depleted gaseous stream having at least a reduction in the concentration of CO.sub.2 relative to the untreated multicomponent gaseous stream. In the subject methods, the multicomponent gaseous stream is contacted with CO.sub.2 nucleated water under conditions of selective CO.sub.2 clathrate formation, where the CO.sub.2 nucleated water serves as liquid solvent. The subject methods find use in a variety of applications where it is desired to selectively remove CO.sub.2 from a multicomponent gaseous stream, including chemical feedstock processing applications and air emissions control applications.

Abstract: Water to be utilized is reacted with soda ash and lime to produce a less corrosive and foulant water. Reaction sludges are fed to a desulfurization unit, where SO.sub.x, NO.sub.x and CO.sub.2 abatement occurs; other industrial waste sludges and/or waters and/or gases can also be utilized in such connection. FIG. 1 is one of the possible process schemes of the present invention.

Abstract: A method for determining the efficiency of a carbon filter to absorb hydrocarbons from an organic amine solvent. After the solvent has passed through the filter, a sample is taken and passed through a standard gas chromatograph (GC) to measure the area counts for the hydrocarbons and the solvent. The sample does not have to have an internal standard added thereto nor does it have to be measured before it is run through the GC. The area counts are converted into actual amounts by using Reduction Factors taken from a specially-prepared calibration table. These amounts are normalized and added to give the total amount of hydrocarbons present in the solvent after it has passed through the carbon filter.

Abstract: Improved processes for treating gas streams containing hydrogen sulfide, carbon dioxide, water vapor and methane, particularly natural gas streams. The processes rely on the availability of two membrane types, one of which has a hydrogen sulfide/methane selectivity of at least about 40 when measured with multicomponent gas mixtures at high pressure. Based on the different permeation properties of the two membrane types, optimized separation processes can be designed. The membrane separation is combined with non-membrane treatment of the residue and/or permeate streams.

Abstract: A method for treating a gas stream to remove heat, gaseous, liquid or particulate matter, or add heat, vapor, or moisture, which includes the steps of:providing a tower having a bed with fluidizable hollow ellipsoidal packing with a long semi-axis and a short semi-axis;introducing a liquid stream into the tower at a liquid flow rate L, and countercurrently introducing the gas stream into the tower at a gas flow rate G sufficient to maintain the bed in a fluidized state and a gas velocity v; andadjusting the volume ratio of the liquid flow to gas flow to cause the ellipsoidal packing to circulate predominantly in the vertical direction relative to the long semi-axis and to maintain a pressure gradient .DELTA.P/H.sub.o across the depth of the fluidized bed of at least about 1500 Pa/m, and, simultaneously, to satisfy the equation:L/G=K.sub.1 (.DELTA.P/H.sub.o v)+K.sub.2wherein L/G is the volume ratio of liquid to gas; .DELTA.P is the pressure drop across the bed; H.sub.

Abstract: Acid gas (a mixture of carbon dioxide and hydrogen sulfide) is absorbed by produced water from hydrocarbon wells. The acid gas is absorbed in the produced water in a static mixer. The time from the entry of the produced water into the static mixer to its exit is less than ten seconds. The produced water with the absorbed acid gas is pressurized to flow through a pipeline to an injection pump. The injection pump injects the produced water with the absorbed acid gas into injection wells which return the produced water into disposal strata. The produced water with the acid gas is maintained at a pressure higher than the pressure at the exit of the static mixer.

Abstract: An apparatus and a process for removing CO.sub.2 from a combustion exhaust gas, by effecting counterflow contact of aqueous alkanolamine solution with the combustion exhaust gas to absorb CO.sub.2 from the gas in the alkanolamine solution and effecting a further contact of the gas with either, condensate water formed by causing condensation of the gas after removal of CO.sub.2, or condensate water formed by causing condensation of the combustion exhaust gas directly after combustion of the fuel. The apparatus includes a tower (1), a first contact section (2) in the tower through which the exhaust gas flows upwardly in counterflow contact with the aqueous alkanolamine solution dispersed by a nozzle device (7) downstream of the first contact section (2), a second contact section (3) in the tower (1) downstream of the nozzle device (7) for effecting counterflow contact of reflux water from a spent absorbent liquor regenerating tower (28) with the gas after removal of CO.sub.2.

Abstract: Process for the simultaneous decarbonation and gasoline stripping of a gaseous mixture at an absolute pressure higher than 0.5 MPa containing methane, C.sub.2 and higher hydrocarbons and CO.sub.2 in which a demethanized rich solvent is regenerated so the process can be carried out more easily and at lower costs than previously known systems.

Abstract: A composition for acid gas absorbent comprising:(A): 99.99 to 70 wt % of a polyethylene glycol dimethyl ether composition represented by the following formula:CH.sub.3 O(C.sub.2 H.sub.4 O).sub.n CH.sub.3wherein n is an integer of 1 to 10; and,(B): 0.01 to 30 wt % of a compound containing at least one of an --NH-- group, a phenolic --OH group and an --S-- group in one molecule thereof but free from an alcoholic --OH group, is provided. More particularly, component B may be an amine, preferably a secondary amine, or a phenolic compound.

Abstract: A method for treating a gas stream to remove heat, gaseous, liquid or particulate matter, or add heat, vapor, or moisture, which includes the steps of:providing a tower having a bed with fluidizable hollow ellipsoidal packing with a long semi-axis and a short semi-axis;introducing a liquid stream into the tower at a liquid flow rate L, and countercurrently introducing the gas stream into the tower at a gas flow rate G sufficient to maintain the bed in a fluidized state and a gas velocity v; andadjusting the volume ratio of the liquid flow to gas flow to cause the ellipsoidal packing to circulate predominantly in the vertical direction relative to the long semi-axis and to maintain a pressure gradient .DELTA.P/H.sub.o across the depth of the fluidized bed of at least about 1500 Pa/m, and, simultaneously, to satisfy the equation:L/G=K.sub.1 (.DELTA.P/H.sub.o v)+K.sub.2wherein L/G is the volume ratio of liquid to gas; .DELTA.P is the pressure drop across the bed; H.sub.