GB2103645A - Process for the removal of CO2 and, if present H2S from a gas mixture - Google Patents

Process for the removal of CO2 and, if present H2S from a gas mixture Download PDF

Info

Publication number
GB2103645A
GB2103645A GB08217024A GB8217024A GB2103645A GB 2103645 A GB2103645 A GB 2103645A GB 08217024 A GB08217024 A GB 08217024A GB 8217024 A GB8217024 A GB 8217024A GB 2103645 A GB2103645 A GB 2103645A
Authority
GB
United Kingdom
Prior art keywords
solvent
process according
pressure
gas mixture
gas
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Granted
Application number
GB08217024A
Other versions
GB2103645B (en
Inventor
Michael William Mcewan
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Shell Internationale Research Maatschappij BV
Original Assignee
Shell Internationale Research Maatschappij BV
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Shell Internationale Research Maatschappij BV filed Critical Shell Internationale Research Maatschappij BV
Publication of GB2103645A publication Critical patent/GB2103645A/en
Application granted granted Critical
Publication of GB2103645B publication Critical patent/GB2103645B/en
Priority to MY650/85A priority Critical patent/MY8500650A/en
Expired legal-status Critical Current

Links

Classifications

    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10K—PURIFYING OR MODIFYING THE CHEMICAL COMPOSITION OF COMBUSTIBLE GASES CONTAINING CARBON MONOXIDE
    • C10K1/00—Purifying combustible gases containing carbon monoxide
    • C10K1/08—Purifying combustible gases containing carbon monoxide by washing with liquids; Reviving the used wash liquors
    • C10K1/16—Purifying combustible gases containing carbon monoxide by washing with liquids; Reviving the used wash liquors with non-aqueous liquids
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
    • B01D53/1456—Removing acid components
    • B01D53/1462—Removing mixtures of hydrogen sulfide and carbon dioxide
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
    • B01D53/1493—Selection of liquid materials for use as absorbents
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/46—Removing components of defined structure
    • B01D53/48—Sulfur compounds
    • B01D53/52—Hydrogen sulfide
    • B01D53/526—Mixtures of hydrogen sulfide and carbon dioxide
    • C—CHEMISTRY; METALLURGY
    • C07—ORGANIC CHEMISTRY
    • C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
    • C07C7/00—Purification; Separation; Use of additives
    • C07C7/11—Purification; Separation; Use of additives by absorption, i.e. purification or separation of gaseous hydrocarbons with the aid of liquids
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10K—PURIFYING OR MODIFYING THE CHEMICAL COMPOSITION OF COMBUSTIBLE GASES CONTAINING CARBON MONOXIDE
    • C10K1/00—Purifying combustible gases containing carbon monoxide
    • C10K1/08—Purifying combustible gases containing carbon monoxide by washing with liquids; Reviving the used wash liquors
    • C10K1/10—Purifying combustible gases containing carbon monoxide by washing with liquids; Reviving the used wash liquors with aqueous liquids
    • C10K1/12—Purifying combustible gases containing carbon monoxide by washing with liquids; Reviving the used wash liquors with aqueous liquids alkaline-reacting including the revival of the used wash liquors
    • C10K1/14—Purifying combustible gases containing carbon monoxide by washing with liquids; Reviving the used wash liquors with aqueous liquids alkaline-reacting including the revival of the used wash liquors organic
    • C10K1/143—Purifying combustible gases containing carbon monoxide by washing with liquids; Reviving the used wash liquors with aqueous liquids alkaline-reacting including the revival of the used wash liquors organic containing amino groups
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
    • Y02C20/00—Capture or disposal of greenhouse gases
    • Y02C20/40—Capture or disposal of greenhouse gases of CO2
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P20/00—Technologies relating to chemical industry
    • Y02P20/151—Reduction of greenhouse gas [GHG] emissions, e.g. CO2

Abstract

A process for removal of CO2 and, if present H2S, from a gas mixture, in which a) the gas mixture is contacted at elevated pressure countercurrently with a solvent comprising a tertiary amine and a physical absorbent; b) the loaded solvent obtained is flashed to a pressure higher than the total partial pressure of CO2 and H2S present in the loaded solvent at the prevailing temperature; c) the loaded solvent obtained in step b) is flashed to a pressure below the total partial pressure of CO2 and H2S present in the loaded solvent at the prevailing temperature, and semi-lean solvent obtained in step c) is, optionally after all or part thereof has been totally regenerated, used as solvent in step a).

Description

SPECIFICATION Process for the removal of CO2 and, if present, H2S from a gas mixture The invention relates to a process for removal of C02 and, if present, H2S from a gas mixture.
In many cases it is necessary to remove CO2 and, if present, H2S and other sulphur-containing impurities such as COS from gas mixtures. The removal of H2S and/or other sulphur-containing impurities from gas mixtures may be necessary in order to render these gas mixtures suitable for catalytic conversions using sulphur-sensitive catalysts, orto reduce environmental pollution if the said gas mixtures or combustion gases obtained therefrom are discharged to the atmosphere.
Examples of CO2-containing bas mixtures from which H2S and/or other sulphur-containing compounds generally have to be removed are gases obtained by partial combustion, or complete or partial gasification, of oil and coal, refinery gases, town gas, natural gas, coke-oven gas, water gas, propane and propene.
Removal of COP from gas mixtures, either as such from a gas mixture which contains no or virtually no H2S (e.g. natural gases), or in admixture with H2S in case the latter compound is present in the gas mixture, is often necessary to bring the gas mixtures on a desired calorific value and/or to avoid corrosion in transport lines and/or to avoid freezing in cryogenic equipment and/or to avoid transport of CO2 which is of no value in the gas mixture ultimately to be used for a certain purpose.
In many cases the Co2 and, if present the H2S, will be removed from the said gas mixtures using liquid solvents, which will often be basic. At least part of the CO2 present in the gas mixtures will be absorbed in the liquid solvent together with at least part of the H2S, if present. The H2S and C02 (which in this specificatin are also indicated as acid gases) will be removed from the said gas mixtures at the pressure of the gas mixture concerned, i.e. in many cases at elevated pressure.
The loaded solvent obtained after absorption of COP and, if present, H2S from the gas mixture is to be regenerated partly or totally, during which regeneration H2S, if present, and CO2 are set free.
In case H2S is present in an appreciable content in the gas obtained after regeneration of the loaded solvent, this gas cannot be discharged to the atmos phere before at least most of the H2S has been removed therefrom. The H2S is very suitably re moved from this gas by converting it to elemental sulphur, which is separated off. The conversion of H2S into elemental sulphur is generally carried out in the art by means of a Claus process in which some of the H2S is oxidized to SO2, and sulphur and water are formed by reaction of H2S with SO2, with or without the assistance of a suitable catalyst. In order to be able to carry out a Claus process, the molar percen tage of H2S in a mixture with COP must be at least about 15.If this percentage is between about 15 and about 40, the Claus process can be carried out by separating one-third part of the gas, combusting the H2S therein to SO2, and subsequently mixing the resultant SO2-containing gas with the balance of the H2S-containing gas, after which the Claus reaction can be further carried out at elevated temperature and preferably inthe presence of a catalyst. In case the gas contains about 40% mol H2S or more, the Claus process can be carried out by combusting the gas with a quantity of air which is sufficient to convert one-third part of the H2S into SO2, and subsequently reacting the H2S and 302 to form sulphur and water.
In many instances the gas set free during regeneration of the loaded solvent is unsuitable for use in a Claus process, the H2S content thereof being too low and further processes for increasing the H2S content are to be carried out with such a gas.
In case the gas set free during regeneration should have an H2S content which is sufficiently high for use in a Claus process it may nevertheless be of importance to increase the H2S content thereof, because in the latter case the total amount of gas to be used in the Claus process is lower, and accordingly the installation can be of smaller size.
The increase in H2S content of the gas set free during regeneration of the loaded solvent can, of course, be achieved by preferential absorption of the H2S from that gas in a suitable solvent, and regeneration of that solvent after loading. However, such a second absorption process is unattractive in view of the extra installations to be built and the extra amount of energy needed for regeneration of that loaded solvent.
The invention provides a process for the removal of CO2, and if present, H23 from a gas mixture, in which process the energy needed for the regeneration of the solvent loaded with CO2 and, of present, H2S is very low, and in which process gases with high H2S contents suitable to be used in a Claus process are obtained with a single absorption step from gas mixtures containing H2S.
Accordingly, the invention provides a process for removal of COp, and, if present, H2S from a gas mixture, which process is characterized in that: a) the gas mixture is contacted at elevated pressure countercurrently with a solvent which comprises a tertiary amine and a physical absorbent; b) the loaded solvent obtained is flashed at least once by pressure release to a pressure which is above the total partial pressure of the COP and H23 present in the loaded solvent at the prevailing temperature; c) the loaded solvent obtained in step b) is flashed at least once by pressure release to a pressure which is below the total partial pressure of the CO2 and H23 present in the loaded solvent at the prevailing temperature, and semi-lean solvent obtained in step c) is, optionally after all or part thereof has been totally regenerated, used as solvent in step a).
The solvent comprises a tertiary amine, a physical absorbent and preferably water.
Acid gases are able to react with tertiary amines.
Very suitable tertiary amines are aliphatic, in particu larthosewhich contain at least one hydroxyalkyl group per molecule. Examples are triethanolamine, tripropanolamine, triisopropanolamine, ethyldiethanolamine, dimethylethanolamine, diethylethanolamine. Preference is given to methyldiethanolamine.
A physical absorbent is a compound in which acid gases are soluble, but without undergoing a reaction therewith. Very suitable physical absorbents are sulfolane and substitued sulfolanes, alcohols with 1-5 carbon atoms per molecule (e.g. methanol), tetraethylene glycol dimethyl ether, Nmethylpyrrolidone, alkylated carboxylic acid amides (e.g. dimethylformamide). Preference is given to sulfolane. The word "sulfolane" denotes the compound "tetrahydrothiophene 1,1-dioxide".
The contents of tertiary amine and physical absorbent (and, if present, water) in the solvent may vary between wide limits. Very suitably the solvent contains in the range of from 10 to 60% of tertiary amine, preferably methyldiethanolamine, in the range of from 15 to 55%w of physical absorbent, preferably sulfolane, and in the range of from 5 to 35%w of water.
It is essential that the solvent used in the process according to the invention comprises a tertiary amine and a physical absorbent. In modified processes solely differing from the process according to the invention in that the solvent contains a secondary and/or a primary amine instead of a tertiary amine or contains a tertiary amine but no physical absorbent, less CO2 is set free in the flashing in step c), and accordingly, in case H2S was present in the original gas mixture, the semi-lean solvent obtained in the partial regeneration in step c) contains H23 and CO2 in a lower molar ratio than obtained with the process according to the invention.Moreover, total regeneration (which in general is carried out by stripping with steam) of the said semi-lean solvent requires in the case of the above modified processes more steam and yields a mixture of CO2 and H2S in a less favourable molar ratio for a Claus process than in the case of the process according to the invention.
A modified process differing from that according to the invention in that the solvent comprises one or more physical absorbents only, amines being absent, requires in many cases more solvent and more absorption trays in an absorption column used in step a) to achieve the same amount of acid gases absorbed than the process according to the invention. Moreover, more non-acid gases are absorbed in solvents which comprise one or more physical absorbents only than in the solvents used in the process according to the invention, which non-acid gases are set free during the flashing in step b).In case a solvent is used which comprises one or more physical absorbents only, this amount of non-acid gases is so great that it is not attractive to use it as fuel (as can be done with the non-acid gases set free in step b) in the process according to the invention, and accordingly these non-acid gases need repressurizing (with the aid of capital intensive compressors) prior to recycling to step a).
The contacting of the gas mixture with the solvent in step a) is carried out at elevated pressure, which is considered to be a pressure of at least 5, in particular of at least 10 bar. Pressures in the range of from 20 to 100 bar are very suitable.
The contacting of the gas mixture with the solvent is very suitably carried out in a contacting zone, e.g.
an absorption column which comprises in the range of from 15 to 80 contacting layers, such as valve trays, bubble cap trays, baffles and the like. It has surprisingly been found that by using the solvent in the process according to the invention the H23 can substantially be removed from the gas mixture used as feed while regulating the amount of CO2 which is left in the purified gas. This regulation can be achieved by regulating the solvent circulation, i.e.
the ratio of solvent fed to the extracting zone and the amount of gas mixture fed thereto. In case no or hardly no H2S is present in the gas mixture, the amount of CO2 removed therefrom can also be regulated by the solvent circulation. If desired, the CO2 can be removed to a very great extent. The solvent circulation can still be further reduced, if desired, by removing loaded solvent at an intermediate point from the contacting zone at the lower part thereof, externally cooling the removed loaded solvent, and reintroducing it to the lower part of the contacting zone for further contacting of the gas mixture to be purified, e.g. as described in British patent specification 1,589,231.
The temperature during the contacting of the gas mixture and the solvent in step a) may vary between wide limits. Temperatures in the range of from 15 to 11 0 C are very suitable, temperatures in the range of from 20 to 80"C are preferred.
In step a) all or the greater part of COS, if present, is removed from the gas mixture.
The loaded solvent obtained from step a) contains CO2, H2S (if any) and, in general, amounts of dissolved non-acid components from the gas mixture to be purified, e.g. hydrocarbons and/or hydrogen and/or carbon monoxide. These non-acid gases are to be removed at least partially from the loaded solvent by flashing in step b) to a pressure which is higher than the total partial pressure of the acid gases present in the loaded solvent. In this way only very small amounts of acid gases are released from the solvent together with the non-acid gases, e.g. hydrocarbons and/or hydrogen and/or carbon monoxide.If desired, the gas mixture obtained from the flashing in step b) may be recirculated to step a), but in order to avoid recompressing this gas mixture is preferably used for any other purpose, e.g. as fuel gas (if desired after removal of all or part of the H2S present, e.g. by contacting the said gas mixture with a small amount of lean solvent). Non-acid gases have to be removed from the loaded solvent before this solvent is flashed to a pressure which is lower than the total partial pressure of the acid gases, because otherwise the hydrocarbons and/or hydrogen and/or carbon monoxide would be set free together with an appreciable amount of acid gases.
As in many cases these acid gases or combustion gases obtained therefrom are to be discharged to the atmosphere, the hydrocarbons and/or hydrogen and/or carbon monoxide would be discharged or burnt simultaneously, which would be a waste of these valuable compounds.
Although the loaded solvent may be flashed in step b) several times, each time at a lower pressure, in most cases the greater part of dissolved non-acid components will be removed in one flash step, and for that reason it is preferred to flash the loaded solvent once in step b).
The loaded solvent obtained in step b) - which besides acid gases contains only small amounts of other dissolved compounds - is flashed in step c) to a pressure below the total partial pressure of the acid gases in the said loaded solvent at the prevailing temperature. It has been found that in the process according to the invention (in which a solvent comprising a tertiary amine and a physical absorbent is used) the amount of CO2 set free is much higher than in modified processes differing solely from the process according to the invention in that the solvent contains a secondary and/or primary amine instead of a tertiary amine or contains a tertiary amine, but no physical absorbent.In case the loaded solvent also contains H2S the gas set free after the pressure release in step c) has a much higher molar ratio of CO2 to H2S than the molar ratio of these gases originally present in the loaded solvent. It is of advantage to heat the loaded solvent, e.g. to a temperature in the range of from 45 to 11 00C before or during flashing in step c), because in that case the molar ratio of CO2 to H2S in the gases set free after the pressure release is still further increased. The above modified process in which a solvent is used which comprises a secondary or primary amine and a physical absorbent or a solvent which comprises a tertiary amine and no physical absorbent, gives a much lower molar ratio of Cm, to H2S in the gas set free after the pressure release.
Because the gas set free in step c) has a higher molar ratio of CO2 to H23 than that of the original loaded solvent, the molar ratio of H23 to CO2 present in the solvent remaining after the pressure release in step c) is higher than originally.
Because at each pressure release in step c) the molar ratio of H2S to CO2 in the remaining solvent is increased, it may be of advantage to flash the loaded solvent in step c) at least twice, each time to a lower pressure or at a higher temperature in case the original gas mixture contains H2S. In general, the pressure of the loaded solvent after the pressure release in step c) will be about atmospheric.
In step c) a large amount of CO2 is set free, and accordingly the loaded solvent is in fact regenerated to an appreciable extent, yielding semi-lean solvent.
In case the original gas mixture was substantially free from H23 the semi-lean solvent obtained in step c) contains CO2 as the only acid gas, and it is preferentially used as such at least partially as solvent in step a); in many cases the amount of CO2 present in the semi-lean solvent obtained in step c) will be so low that it is preferred to use this semi-lean solvent as the only solvent in step a). If desired, part or all of the semi-lean solvent obtained in step c) can be totally regenerated (e.g. by stripping with steam) and used as solvent in step a). In case totally regenerated solvent and semi-lean solvent are both used as solvents in step a) the former is preferentially introduced into the contacting zone at a point further removed from the inlet of the gas mixture than the semi-lean solvent.
In case the original gas mixture did not only contain CO2 but also H23 the acid gases set free during the flashing in step c) in a number of cases will contain so small amounts of H2S that they can be discharged to the atmosphere after incineration.
If desired or needed the H23 present in the gases set free during the flashing in step c) may be removed therefrom by contacting these gases with a solvent under conditions which favour preferential removal of H2S over CO2. For such removal, e.g. a mixture comprising an amine and optionally a physical absorbent, may suitably be used, in particular the solvent to be used according to the present invention. In order to achieve a high selectivity for H2S removal the contacting is very suitably carried out in a column with less than 20 contact trays and at high gas velocities, e.g. as described in British patent specification 1,362,384.
In case H2S was present in the original gas mixture the semi-lean solvent obtained in step c) contains H23 and CO2 in a high molar ratio. In view of the high content of H23 this semi-lean solvent is not suitable to be used as solvent in step a) and the acid gases present therein have to be removed therefrom. The acid gases are removed from the said semi-lean solvent by total regeneration to yield lean solvent.
The regeneration is very suitably carried out by heating in a regeneration column (e.g., to a temperature in the range of from 80 to 160"C),which heating is preferably carried out by stripping with steam.
The gas obtained during this regeneration has such an H23 content that it can be suitably used in a Claus process for the preparation of sulphur.
The lean solvent obtained after regeneration can very suitably be reused in step a), and also for contacting the flashed gas from step b) or c) if desired.
It will be clear that in order to keep the amount of energy needed in the process as low as possible, it is of advantage to carry out heat exchange of process streams where appropriate.
Example 1 10,000 kmol/h of a gas mixture (composition 80%v methane, 5%v ethane, 3%v propane, 1%v butane, 1 %v H23 and 10%v CO2) are introduced into the bottom of an absorption column containing 30 valve trays, at a temperature of 400C and a pressure of 50 bar. This gas mixture is countercurrently contacted with 300 m3/h of a lean solvent consisting of methyldiethanolamine (50%w), sulfolane (25%w) and water (25%w). Purified gas leaves the top of the absorption column in an amount of 9511.4 kmol/h; this gas contains 644 kmol/h CO2 and less than 4 volume parts per million (ppm) of H2S.
The loaded solvent (300 m3/h) is removed from the bottom of the absorption column; it contains 99.7 kmol/h H2S and 356 kmol/h CO2. This loaded solvent is flashed to a pressure of 15 bar at a temperature of 69.2"C. The gas flashed off (45 kmol/h) contains 1.4 kmol/h H2S, 10.7 kmol/h CO2, the balance consists of hydrocarbons. The loaded solvent obtained after this first flash contains 98.6 kmol/h H23 and 345 kmol/h CO2. It is heated by heat exchange with lean solvent, and flashed to a pressure of 1.3 bar at a temperature of700C. The gas set free during this second flash (293.6 kmol/h) consists of 35.6 kmol/h H2S and 258 kmol/h CO2.It is contacted countercurrently with 148 m3/h lean solvent in a second absorption column with 13 valve trays at a temperature of 40 C and a pressure of 1.1 bar, yielding 212 kmol/h of a gas which consists of CO2 containing 300 ppm H2S. The loaded solvent obtained in the last-mentioned absorption column is regenerated together with the semi-lean solvent obtained after the second flash.
This semi-lean solvent contains 63 kmol/h H2S and 87 kmol/h CO2. The regeneration is carried out by stripping with steam, yielding a gas which consists of 98.6 kmol/h H2S and 133 kmol/h CO2, which gas is very suitable to be used in a Claus process. The lean solvent obtained after regeneration (448 m3/h) is partly (148 m3/h) recycled to the second absorption column and partly (300 m3/h) (after heat exchange with the loaded solvent from the first flash) used as lean solvent in the absorption column.
Example 2 10,000 kmol/h of a gas mixture (composition 90.65% methane and 9.35%v CO2) are introduced into the bottom of an absorption column containing 20 valve trays at a temperature of 35 C and a pressure of 91 bar. This gas mixture is countercurrently contacted with 844 m3/h of a solvent which consists of methyldiethanolamine (50%w), sulfolane (25%w) and water (25%w). This solvent is semi-lean solvent; it contains 1374 kmol/h CO2 and no methane. The gas leaving the top of the absorption column (9069 kmol/h) consists for 98% of methane, the balance being CO2.
The loaded solvent (844 m3/h) is removed from the bottom of the absorption column; it contains 2131 kmol/h CO2 and 174 kmol/h methane and has a temperature of 53 C. This loaded solvent is flashed to a pressure of 24 bar and a temperature of 51 C.
The gas flashed off (204 kmol/h) consists of 159 kmol/h methane and 45 kmol/h CO2. The loaded solvent obtained after this first flash (844 m3/h) contains 2086 kmol/h C02 and 15 kmol/h methane. It is heated and flashed to a pressure of 1.3 bar and a temperature of 40 C. The gas set free during this second flash (727 kmol/h) consists of 15 kmol/h methane and 712 kmol/h CO2. The semi-lean solvent obtained in the second flash (844 m3/h) contains 1374 kmol/h CO2 and no methane, and is introduced at the top of the absorption column as solvent for the gas mixture to be purified as described above.
Comparative experiment For comparison the same process as described in Example 2 is carried out with a solvent consisting of diisopropanolamine (50%w), sulfolane (25%w) and water (25%w) (not according to the invention). For the removal of the same amount of CO2 from the feed gas, and the use of non-regenerated semi-lean solvent in the absorption step, a solvent circulation about five times as high as that needed in the process according to the invention described in Example 2 is needed. Moreover, about five times as much methane is absorbed per hour in the absorption column, and realeased in the first flash; the amount of methane set free in this first flash is so high that for ecomomical reasons this gas has to be recompressed and recycled, which makes the installation of expensive compressors necessary.

Claims (15)

1. A process for removal of CO2 and, if present, H2S from a gas mixture, characterized in that: a) the gas mixture is contacted at elevated pressure countercurrently with a solvent which comprises a tertiary amine and a physical absorbent; b) the loaded solvent obtained is flashed at least once by pressure release to a pressure which is above the total partial pressure of the CO2 and H2S present in the loaded solvent at the prevailing temperature; c) the loaded solvent obtained in step b) is flashed at least once by pressure release to a pressure which is below the total partial pressure of the CO2 and H2S present in the loaded solvent at the prevailing temperature, and semi-lean solvent obtained in step c) is, optionally after all or part thereof has been totally regenerated, used as solvent in step a).
2. A process according to claim 1, characterized in that the solvent contains water.
3. A process according to claim 1 or 2, characterized in that the tertiary amine is aliphatic and contains at least one hydroxyalkyl group per molecule.
4. A process according to claim 3, characterized in that the tertiary amine is methyldiethanolamine.
5. A process according to any one of the preceding claims, characterized in that the physical absorbent is tetrahydrothiophene 1,1-dioxide.
6. A process according to any one of the preceding claims, characterized in that the solvent contains methyldiethanolamine, tetrahydrothiophene 1,1dioxide and water.
7. A process according to claim 6, characterized in that the solvent contains in the range of from 10 to 60% of methyldiethanolamine, in the range of from 15 to 55%w of tetrahydrothiophene 1,1-dioxide and in the range of from 5 to 35%w of water.
8. A process according to any one of the preceding claims, characterized in that in step a) the gas mixture is contacted with the solvent in a contacting zone which comprises in the range of from 15 to 80 contacting layers.
9. A process according to any one of the preceding claims, characterized in that step a) is carried out at a pressure in the range of from 20 to 100 bar.
10. A process according to any one of the preceding claims, characterized in that step a) is carried out at a contacting temperature in the range of from 20 to 80 C.
11. A process according to any one of the preceding claims, characterized in that the loaded solvent in step C) is flashed to atmospheric pressure.
12. A process according to any one of the preceding claims, characterized in that semi-lean solvent obtained in step c) is regenerated by stripping with steam before being used as solvent in step a).
13. A process according to any one of claims 1-11, characterized in that the gas mixture is substantially free of H2S and the semi-lean solvent obtained in step c) is used as the only solvent in step a).
14. A process as claimed in claim 1, substantially as hereinbefore described with reference to the Examples 1 and 2.
15. Gas mixtures from which C02 and, if present, H2S have been removed by means of a process as claimed in any one of the preceding claims.
GB08217024A 1981-06-15 1982-06-11 Process for the removal of co2 and, if present h2s from a gas mixture Expired GB2103645B (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
MY650/85A MY8500650A (en) 1981-06-15 1985-12-30 Process for the removal of co2 and if present h2s from a gas mixture

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
GB8118288 1981-06-15

Publications (2)

Publication Number Publication Date
GB2103645A true GB2103645A (en) 1983-02-23
GB2103645B GB2103645B (en) 1984-03-21

Family

ID=10522502

Family Applications (1)

Application Number Title Priority Date Filing Date
GB08217024A Expired GB2103645B (en) 1981-06-15 1982-06-11 Process for the removal of co2 and, if present h2s from a gas mixture

Country Status (21)

Country Link
JP (1) JPS57209626A (en)
KR (1) KR840000263A (en)
AU (1) AU546704B2 (en)
BE (1) BE893386A (en)
BR (1) BR8203471A (en)
CA (1) CA1205276A (en)
DD (1) DD202129A5 (en)
DE (1) DE3222281C2 (en)
DK (1) DK162192C (en)
DZ (1) DZ429A1 (en)
ES (1) ES513052A0 (en)
FR (1) FR2507498B1 (en)
GB (1) GB2103645B (en)
IN (1) IN156408B (en)
IT (1) IT1210895B (en)
NL (1) NL193746C (en)
NO (1) NO154785C (en)
NZ (1) NZ200951A (en)
PL (1) PL236913A1 (en)
SU (1) SU1577685A3 (en)
ZA (1) ZA824163B (en)

Cited By (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4714480A (en) * 1986-01-09 1987-12-22 Shell Oil Company Removal of acid gases from a gas mixture
EP0375077A2 (en) * 1988-12-23 1990-06-27 Shell Internationale Researchmaatschappij B.V. Removing hydrogen sulphide from a gas mixture
WO1994013579A1 (en) * 1992-12-16 1994-06-23 The Regents Of The University Of California Process for recovery of sulfur from acid gases
US5347003A (en) * 1993-03-05 1994-09-13 Quaker Chemical Corporation Methods for regenerating a sulfur scavenging compound from a product of a sulfur scavenging reaction
WO1996002461A1 (en) * 1994-07-19 1996-02-01 Quaker Chemical Corporation Methods for recovering sodium sulfides from a sulfur scavenging reaction
US5698171A (en) * 1996-01-10 1997-12-16 Quaker Chemical Corporation Regenerative method for removing sulfides from gas streams
US5885538A (en) * 1997-07-02 1999-03-23 Quaker Chemical Corporation Method and composition for the regeneration of an aminal compound
WO1999021821A1 (en) * 1997-10-27 1999-05-06 Shell Internationale Research Maatschappij B.V. Process for the purification of an alkanolamine
GB2375544A (en) * 2001-02-02 2002-11-20 Inst Francais Du Petrole Process for deacidification of natural gas comprising two-stage removal process and flashing
WO2004047955A1 (en) * 2002-11-28 2004-06-10 Shell Internationale Research Maatschappij B.V. Process for removing sulphur compounds including hydrogen sulphide and mercaptans from gas streams
EP2482959A1 (en) * 2009-09-29 2012-08-08 Fluor Technologies Corporation Gas purification configurations and methods
EP3628393A1 (en) * 2016-02-08 2020-04-01 Basf Se Method for separating carbon monoxide and acid gases from a fluid stream comprising carbon monoxide

Families Citing this family (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
IT1132170B (en) * 1980-07-04 1986-06-25 Snam Progetti SELECTIVE SEPARATION PROCESS OF HYDROGEN SULFURATED FROM GASEOUS MIXTURES CONTAINING ALSO CARBON DIOXIDE
IT1177324B (en) * 1984-11-26 1987-08-26 Snam Progetti PROCEDURE FOR SELECTIVELY REMOVING HYDROGEN SULFUR FROM GASEOUS MIXTURES CONTAINING ALSO CARBON DIOXIDE
JPH01135518A (en) * 1987-11-20 1989-05-29 Seitetsu Kagaku Co Ltd Absorptive inhibition process employing sulfolane
CN101873991A (en) * 2007-09-20 2010-10-27 斯瓦普索尔公司 Process for destroying carbonaceous materials and composition and system thereof
DE102008043329B3 (en) * 2008-10-30 2010-06-24 Helmholtz-Zentrum Für Umweltforschung Gmbh - Ufz Apparatus and method for remediation and separation of gas accumulations in waters

Family Cites Families (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3242640A (en) * 1962-12-27 1966-03-29 Union Oil Co Removal of acid constituents from gas mixtures
DE1494809C3 (en) * 1966-10-25 1974-01-17 Metallgesellschaft Ag, 6000 Frankfurt Process for scrubbing carbon dioxide from low-sulfur or sulfur-free gases
US3770622A (en) * 1970-12-28 1973-11-06 Fluor Corp Treatment of wet natural gas mixtures to recover liquid hydrocarbons
DE2226215C3 (en) * 1972-05-30 1975-09-25 Metallgesellschaft Ag, 6000 Frankfurt Process for the regeneration of a loaded absorbent which is obtained when acidic components are washed out of gases
US4025322A (en) * 1975-05-19 1977-05-24 Shell Oil Company Removal of hydrocarbons and water from acid gas streams
GB1589231A (en) * 1977-04-21 1981-05-07 Shell Int Research Process for the removal of acidic gases

Cited By (22)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4714480A (en) * 1986-01-09 1987-12-22 Shell Oil Company Removal of acid gases from a gas mixture
EP0375077A2 (en) * 1988-12-23 1990-06-27 Shell Internationale Researchmaatschappij B.V. Removing hydrogen sulphide from a gas mixture
EP0375077B1 (en) * 1988-12-23 1993-06-02 Shell Internationale Researchmaatschappij B.V. Removing hydrogen sulphide from a gas mixture
WO1994013579A1 (en) * 1992-12-16 1994-06-23 The Regents Of The University Of California Process for recovery of sulfur from acid gases
US5397556A (en) * 1992-12-16 1995-03-14 The Regents Of The Unviversity Of California Process for recovery of sulfur from acid gases
US5347003A (en) * 1993-03-05 1994-09-13 Quaker Chemical Corporation Methods for regenerating a sulfur scavenging compound from a product of a sulfur scavenging reaction
US5508012A (en) * 1993-03-05 1996-04-16 Quaker Chemical Corporation Methods for recovering sodium sulfides from a sulfur scavenging reaction
WO1996002461A1 (en) * 1994-07-19 1996-02-01 Quaker Chemical Corporation Methods for recovering sodium sulfides from a sulfur scavenging reaction
US5698171A (en) * 1996-01-10 1997-12-16 Quaker Chemical Corporation Regenerative method for removing sulfides from gas streams
US5885538A (en) * 1997-07-02 1999-03-23 Quaker Chemical Corporation Method and composition for the regeneration of an aminal compound
WO1999021821A1 (en) * 1997-10-27 1999-05-06 Shell Internationale Research Maatschappij B.V. Process for the purification of an alkanolamine
EP0918049A1 (en) * 1997-10-27 1999-05-26 Shell Internationale Researchmaatschappij B.V. Process for the purification of an alkanolamine
US6152994A (en) * 1997-10-27 2000-11-28 Shell Oil Company Process for the purification of an alkanolamine
GB2375544A (en) * 2001-02-02 2002-11-20 Inst Francais Du Petrole Process for deacidification of natural gas comprising two-stage removal process and flashing
GB2375544B (en) * 2001-02-02 2004-08-18 Inst Francais Du Petrole Process for deacidizing a gas with washing of the hydrocarbons desorbed upon regeneration of the solvent
WO2004047955A1 (en) * 2002-11-28 2004-06-10 Shell Internationale Research Maatschappij B.V. Process for removing sulphur compounds including hydrogen sulphide and mercaptans from gas streams
EA009588B1 (en) * 2002-11-28 2008-02-28 Шелл Интернэшнл Рисерч Маатсхаппий Б.В. Process for removing sulphur compounds including hydrogen sulphide and mercaptans from gas streams
AU2003298333B2 (en) * 2002-11-28 2008-05-01 Shell Internationale Research Maatschappij B.V. Process for removing sulphur compounds including hydrogen sulphide and mercaptans from gas streams
US7425314B2 (en) 2002-11-28 2008-09-16 Shell Oil Company Process for removing sulphur compounds including hydrogen sulphide and mercaptans from gas streams
EP2482959A1 (en) * 2009-09-29 2012-08-08 Fluor Technologies Corporation Gas purification configurations and methods
EP2482959A4 (en) * 2009-09-29 2013-11-06 Fluor Tech Corp Gas purification configurations and methods
EP3628393A1 (en) * 2016-02-08 2020-04-01 Basf Se Method for separating carbon monoxide and acid gases from a fluid stream comprising carbon monoxide

Also Published As

Publication number Publication date
NO154785C (en) 1986-12-29
NL193746C (en) 2000-09-04
DK266382A (en) 1982-12-16
PL236913A1 (en) 1983-02-14
CA1205276A (en) 1986-06-03
AU8484982A (en) 1982-12-23
NZ200951A (en) 1985-02-28
DK162192C (en) 1992-02-17
NO821968L (en) 1982-12-16
DK162192B (en) 1991-09-30
DE3222281A1 (en) 1982-12-30
IN156408B (en) 1985-07-20
IT1210895B (en) 1989-09-29
ES8303935A1 (en) 1983-02-16
JPH0221286B2 (en) 1990-05-14
ZA824163B (en) 1983-04-27
NL193746B (en) 2000-05-01
ES513052A0 (en) 1983-02-16
DZ429A1 (en) 2004-09-13
SU1577685A3 (en) 1990-07-07
AU546704B2 (en) 1985-09-12
BE893386A (en) 1982-12-02
FR2507498B1 (en) 1988-11-25
JPS57209626A (en) 1982-12-23
NO154785B (en) 1986-09-15
GB2103645B (en) 1984-03-21
FR2507498A1 (en) 1982-12-17
DE3222281C2 (en) 1997-10-23
NL8202061A (en) 1983-01-03
KR840000263A (en) 1984-02-18
IT8221849A0 (en) 1982-06-14
DD202129A5 (en) 1983-08-31
BR8203471A (en) 1983-06-07

Similar Documents

Publication Publication Date Title
US4397660A (en) Process for the removal of H2 S and CO2 from a gas mixture
US4372925A (en) Process for the removal of acid gases from gas mixtures containing methane
GB2103645A (en) Process for the removal of CO2 and, if present H2S from a gas mixture
US8926737B2 (en) Process for producing purified natural gas
KR100810188B1 (en) Treatment of a gas stream containing hydrogen sulphide
US7803271B2 (en) Method of extracting the hydrogen sulfide contained in a hydrocarbon gas
IE51368B1 (en) Selective separation of hydrogen sulphide from gaseous mixtures
JPS627960B2 (en)
US20180272269A1 (en) Acid gas removal with an absorption liquid that separates in two liquid phases
US4483834A (en) Gas treating process for selective H2 S removal
AU2013301899B2 (en) Method for selective desulphurisation of a synthetic raw gas
CA1183330A (en) Process for reducing the total sulphur content of a high co.sub.2-content feed gas
SU1530091A3 (en) Method of cleaning gases containing hydrogen sulfide and sulfur dioxide to obtain elemental sulfur
CA2243482A1 (en) Method for removing sulfur-containing contaminants, aromatics and hydrocarbons from gas
CA2241790A1 (en) Method for removing sulfur-containing contaminants, aromatics and hydrocarbons from gas
JPS6097028A (en) Treatment of exhaust gas
US3642431A (en) Method of removing hydrogen sulfide from gaseous mixtures
US4664903A (en) Removal of sulfur compounds from gases
US2992076A (en) Production of sulfur
Van Der et al. Process for the removal of H 2 S and CO 2 from a gas mixture
MXPA98005795A (en) Method for removing contaminants containing sulfur, aromatic compounds and hydrocarbons apparatus of a
MXPA98005793A (en) Method to remove contaminants containing azufre, aromatic substances and hydrocarbons, from a

Legal Events

Date Code Title Description
PG Patent granted