NO166920B - PROCEDURE FOR AA REMOVE H2S AND CO2 FROM A GAS MIXTURE. - Google Patents
PROCEDURE FOR AA REMOVE H2S AND CO2 FROM A GAS MIXTURE. Download PDFInfo
- Publication number
- NO166920B NO166920B NO872756A NO872756A NO166920B NO 166920 B NO166920 B NO 166920B NO 872756 A NO872756 A NO 872756A NO 872756 A NO872756 A NO 872756A NO 166920 B NO166920 B NO 166920B
- Authority
- NO
- Norway
- Prior art keywords
- gas mixture
- absorbent
- pressure
- contact
- contact zone
- Prior art date
Links
- 239000000203 mixture Substances 0.000 title claims description 27
- 238000000034 method Methods 0.000 title claims description 12
- 239000002250 absorbent Substances 0.000 claims description 23
- 230000002745 absorbent Effects 0.000 claims description 23
- 239000000376 reactant Substances 0.000 claims description 18
- 239000000243 solution Substances 0.000 claims description 13
- 239000007864 aqueous solution Substances 0.000 claims description 12
- 150000004696 coordination complex Chemical class 0.000 claims description 12
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 claims description 11
- 229910052717 sulfur Inorganic materials 0.000 claims description 11
- 239000011593 sulfur Substances 0.000 claims description 11
- 239000007788 liquid Substances 0.000 claims description 9
- VTLYFUHAOXGGBS-UHFFFAOYSA-N Fe3+ Chemical compound [Fe+3] VTLYFUHAOXGGBS-UHFFFAOYSA-N 0.000 claims description 8
- QGZKDVFQNNGYKY-UHFFFAOYSA-O ammonium group Chemical group [NH4+] QGZKDVFQNNGYKY-UHFFFAOYSA-O 0.000 claims description 8
- CRVGTESFCCXCTH-UHFFFAOYSA-N methyl diethanolamine Chemical compound OCCN(C)CCO CRVGTESFCCXCTH-UHFFFAOYSA-N 0.000 claims description 5
- 150000003512 tertiary amines Chemical class 0.000 claims description 4
- CWYNVVGOOAEACU-UHFFFAOYSA-N Fe2+ Chemical compound [Fe+2] CWYNVVGOOAEACU-UHFFFAOYSA-N 0.000 claims description 3
- 150000002825 nitriles Chemical class 0.000 claims description 3
- ILJSQTXMGCGYMG-UHFFFAOYSA-N triacetic acid Chemical compound CC(=O)CC(=O)CC(O)=O ILJSQTXMGCGYMG-UHFFFAOYSA-N 0.000 claims description 3
- 150000007524 organic acids Chemical class 0.000 claims description 2
- 230000001590 oxidative effect Effects 0.000 claims description 2
- 239000002245 particle Substances 0.000 claims 1
- 239000007789 gas Substances 0.000 description 30
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 10
- 230000008929 regeneration Effects 0.000 description 7
- 238000011069 regeneration method Methods 0.000 description 7
- 229930195733 hydrocarbon Natural products 0.000 description 5
- 150000002430 hydrocarbons Chemical class 0.000 description 5
- 238000000605 extraction Methods 0.000 description 3
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- KCXVZYZYPLLWCC-UHFFFAOYSA-N EDTA Chemical compound OC(=O)CN(CC(O)=O)CCN(CC(O)=O)CC(O)=O KCXVZYZYPLLWCC-UHFFFAOYSA-N 0.000 description 2
- 230000002378 acidificating effect Effects 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical group C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 239000007800 oxidant agent Substances 0.000 description 2
- HXJUTPCZVOIRIF-UHFFFAOYSA-N sulfolane Chemical compound O=S1(=O)CCCC1 HXJUTPCZVOIRIF-UHFFFAOYSA-N 0.000 description 2
- VHUUQVKOLVNVRT-UHFFFAOYSA-N Ammonium hydroxide Chemical compound [NH4+].[OH-] VHUUQVKOLVNVRT-UHFFFAOYSA-N 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 239000003463 adsorbent Substances 0.000 description 1
- QGZKDVFQNNGYKY-UHFFFAOYSA-N ammonia Natural products N QGZKDVFQNNGYKY-UHFFFAOYSA-N 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 239000002904 solvent Substances 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
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
- B01D53/14—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
- B01D53/1468—Removing hydrogen sulfide
-
- 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
- B01D53/1406—Multiple stage absorption
-
- 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
-
- 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
Landscapes
- Chemical & Material Sciences (AREA)
- Engineering & Computer Science (AREA)
- Analytical Chemistry (AREA)
- General Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Health & Medical Sciences (AREA)
- Biomedical Technology (AREA)
- Environmental & Geological Engineering (AREA)
- Gas Separation By Absorption (AREA)
- Treating Waste Gases (AREA)
- Filtering Of Dispersed Particles In Gases (AREA)
Description
Den foreliggende oppfinnelse angår fjernelse av The present invention relates to the removal of
I^S. og CC>2 fra en gassblanding som innbefatter H2S og C02, spesielt fjernelse av disse sure komponenter fra en gassblanding inneholdende hydrocarboner, mellom 10 og 50 volum* I^S. and CC>2 from a gas mixture containing H2S and C02, in particular the removal of these acidic components from a gas mixture containing hydrocarbons, between 10 and 50 volumes*
CC>2 og bare en liten mengde H2S, hvor for eksempel volum-forholdet mellom E^S og C02 er mellom 10~^ og 0,1. Et eksempel på en slik gassblanding er naturgass. CC>2 and only a small amount of H2S, where, for example, the volume ratio between E^S and C02 is between 10~^ and 0.1. An example of such a gas mixture is natural gas.
Det tas ved oppfinnelsen sikte på å tilveiebringe en fleksibel prosess for sterk fjernelse av H2S og fjernelse av mesteparten av C02. The invention aims to provide a flexible process for strong removal of H2S and removal of most of the C02.
Den foreliggende fremgangsmåte for å fjerne H2S og The present method for removing H2S and
C02 fra en gassblanding som innbefatter H2S og C02»C02 from a gas mixture comprising H2S and C02'
er særpreget ved at den omfatter de trinn at is characterized by the fact that it includes the steps that
a) gassblandingen bringes i en første kontaktsone i kontakt med en vandig reaktantoppløsning som inneholder en effektiv a) the gas mixture is brought into contact in a first contact zone with an aqueous reactant solution containing an effective
mengde av et koordinasjonskompleks av Fe(III) med en egnet organisk syre som en oxyderende reaktant, for å danne en delvis renset gassblanding og en vandig oppløsning som omfatter svovel og redusert reaktant, og den delvis rensede gassblanding blir overført til en annen kontaktsone, og b) den delvis rensede gassblanding blir i den annen kontaktsone bragt i kontakt med en flytende og regenererbar absorbent i form av en vandig oppløsning av et tertiært amin, amount of a coordination complex of Fe(III) with a suitable organic acid as an oxidizing reactant, to form a partially purified gas mixture and an aqueous solution comprising sulfur and reduced reactant, and the partially purified gas mixture is transferred to another contact zone, and b) the partially purified gas mixture is in the second contact zone brought into contact with a liquid and regenerable absorbent in the form of an aqueous solution of a tertiary amine,
slik at det dannes en renset gassblanding og brukt absorbent. so that a purified gas mixture and used absorbent is formed.
Svovel som fås i trinn a) kan fjernes fra den vandige oppløsning dannet i trinn a) før eller efter regenerering av i det minste endel av den reduserte reaktant ved å Sulfur obtained in step a) can be removed from the aqueous solution formed in step a) before or after regeneration of at least part of the reduced reactant by
oxydere reaktanten. oxidize the reactant.
Den delvis rensede gassblanding blir uten ytterligere behandling eller omvandling ledet over i den annen kontaktsone selv om den delvis rensede gassblanding kan oppvarmes eller avkjøles dersom dette skulle være nødvendig. The partially purified gas mixture is led without further treatment or conversion into the second contact zone, although the partially purified gas mixture can be heated or cooled if this is necessary.
Ifølge en egnet utførelsesform av den foreliggende fremgangsmåte anvendes som den vandige reaktantoppløsning en oppløsning som omfatter et koordinasjonskompleks av Fe(III) med for eksempel nitriltrieddiksyre (NTA) eller ethylen-diamintetraeddiKsyre (EDTA). According to a suitable embodiment of the present method, a solution comprising a coordination complex of Fe(III) with, for example, nitrile triacetic acid (NTA) or ethylenediaminetetraacetic acid (EDTA) is used as the aqueous reactant solution.
Ifølge en foretrukken utførelsesform anvendes som den vandige reaktantoppløsning en oppløsning av en ammoniumform av et koordinasjonskompleks av Fe(III) med NTA og en ammoniumform av et koordinasjonskompleks av Fe(II) med NTA. Den vandige reaktantoppløsning kan dessuten inneholde vandig ammoniakk. Oppløsningens pH er med fordel mellom 5 og 8,5, og molforholdet mellom koordinasjonskomplekset av Fe(III) According to a preferred embodiment, a solution of an ammonium form of a coordination complex of Fe(III) with NTA and an ammonium form of a coordination complex of Fe(II) with NTA is used as the aqueous reactant solution. The aqueous reactant solution may also contain aqueous ammonia. The pH of the solution is advantageously between 5 and 8.5, and the molar ratio between the coordination complex of Fe(III)
med NTA og ammoniumformen av et koordinasjonskompleks av Fe (II) med NTA i oppløsningen er med fordel mellom 0,2 og 6. Den-vandige reaktantoppløsning omfatter 2-15 mol av en ammoniumform av et koordinasjonskompleks av Fe(III) med NTA pr. mol H2S som skal fjernes. with NTA and the ammonium form of a coordination complex of Fe (II) with NTA in the solution is advantageously between 0.2 and 6. The aqueous reactant solution comprises 2-15 mol of an ammonium form of a coordination complex of Fe (III) with NTA per moles of H2S to be removed.
Den delvis rensede gassblanding omfatter C02 som vil bli fjernet i trinn b) ved hjelp av den flytende og regenerer-bareadsorbent. For å fjerne C02 fra den brukte absorbent som fås i trinn b), blir den brukte absorbent "flashet" The partially purified gas mixture comprises C02 which will be removed in step b) by means of the liquid and regenerable adsorbent. To remove C02 from the spent absorbent obtained in step b), the spent absorbent is "flashed"
minst én gang ved å oppheve trykket til et nivå under partialtrykket for C02 ved den herskende temperatur. Dersom det er nødvendig å fjerne koabsorberte hydrocarboner, kan dette trinn gå forut for flashing av den belagte absorbent minst én gang ved å oppheve trykket inntil et nivå som ligger mellom det trykk som hersker ved kontakten i trinn at least once by depressurizing to a level below the partial pressure of C02 at the prevailing temperature. If it is necessary to remove coabsorbed hydrocarbons, this step may be preceded by flashing the coated absorbent at least once by depressurizing to a level intermediate to the pressure prevailing at the contact in step
b) og partialtrykket for C02 ved den herskende temperatur. b) and the partial pressure for C02 at the prevailing temperature.
I henhold til. oppfinnelsen er væsken og den regenererbare absorbent en vandig oppløsning av tertiært amin, som f.eks. methyldiethanolamin (MDEA). According to. invention, the liquid and the regenerable absorbent are an aqueous solution of tertiary amine, such as e.g. methyldiethanolamine (MDEA).
Væsken og den regenererbare absorbent kan dessuten omfatte et fysikalsk oppløsningsmiddel, for eksempel sulfolan. The liquid and the regenerable absorbent can also comprise a physical solvent, for example sulfolane.
Væsken og den regenererbare absorbent omfatter med fordel en vandig oppløsning med 10-60 vekt% MDEA, 15-55 vekt% sulfolan og 5-35 vekt% vann. The liquid and the regenerable absorbent advantageously comprise an aqueous solution with 10-60% by weight MDEA, 15-55% by weight sulfolane and 5-35% by weight water.
Oppfinnelsen vil nå bli nærmere beskrevet under hen-visning til den vedføyede Figur som skjematisk viser et apparat for utførelse av den foreliggende fremgangsmåte. The invention will now be described in more detail with reference to the attached Figure which schematically shows an apparatus for carrying out the present method.
Det viste apparat omfatter en første kontaktsone 1, The device shown comprises a first contact zone 1,
en svovelutvinningssone 3, en første regenereringssone 5, a sulfur extraction zone 3, a first regeneration zone 5,
en annen kontaktsone 6, en første flashbeholder 8 og en annen flashbeholder 9. another contact zone 6, a first flash container 8 and a second flash container 9.
En tilførselsledning 10 for en sur gass står i forbindelse med den første kontaktsone 1. Den første kontaktsone 1 står i forbindelse med svovelutvinningssonen 3 via en ledning 12 og med den annen kontaktsone 6 via en ledning 14. Svovelutvinningssonen 3 er forsynt med et svovelutløp 15, og sonen 3 står i forbindelse med den første regenereringssone 5 via en ledning 16. En ledning 17 for tilførsel av oxydasjonsmiddel og et utløp 19 for brukt gass står i forbindelse med den første regenereringssone 5, og denne står i forbindelse med den første kontaktsone 1 via en ledning 20. A supply line 10 for an acid gas is connected to the first contact zone 1. The first contact zone 1 is connected to the sulfur extraction zone 3 via a line 12 and to the second contact zone 6 via a line 14. The sulfur extraction zone 3 is provided with a sulfur outlet 15, and the zone 3 is connected to the first regeneration zone 5 via a line 16. A line 17 for the supply of oxidizing agent and an outlet 19 for used gas is connected to the first regeneration zone 5, and this is connected to the first contact zone 1 via a wire 20.
Den annen kontaktsone 6 har et utløp 21 for renset The second contact zone 6 has an outlet 21 for cleaning
gass, og sonen 6 står i forbindelse med den første flashbeholder 8 via en ledning 22 som er forsynt med en trykkreduk-sjonsventil 23. Den første flashbeholder 8 har et gassut- gas, and the zone 6 is connected to the first flash container 8 via a line 22 which is equipped with a pressure reduction valve 23. The first flash container 8 has a gas outlet
løp 25 og står via en ledning 26 som er forsynt med en trykk-reduksjonsventil 27, i forbindelse med den annen flashbeholder 9. Den annen flashbeholder 9 har et gassutløp 30 og står i forbindelse med den annen kontaktsone 6 via en ledning 31. barrel 25 and is connected via a line 26 which is equipped with a pressure-reducing valve 27, to the second flash container 9. The second flash container 9 has a gas outlet 30 and is connected to the second contact zone 6 via a line 31.
E ksempel Example
En hydrocarbonholdig sur ("sour") gassblanding som innbefatter 15 volum% CC>2 og 250 ppmv (deler pr. million, basert på volum) I^S blir tilført til den første kontaktsone 1 via tilførselsledningen 10 for sur gass. I den første kontaktsone 1 blir den sure gassblanding bragt i.kontakt med en vandig reaktantoppløsning som inneholder .0,65 mol/l av en ammoniumform av et koordinasjonskompleks av Fe(III) med NTA, for å danne en delvis renset gassblanding som inneholder 12 volum% CC>2 og 2 ppmv t^S, og en vandig oppløsning som omfatter svovel og redusert reaktant som omfatter en ytterligere mengde av en ammoniumform av et koordinasjonskompleks av Fe(II) med NTA. Den vandige oppløsning som omfatter svovel og redusert reaktant, blir via ledningen 12 overført til svovelfjernelsessonen 3 fra hvilken svovel blir fjernet via ledningen 15, og den i det vesentlige svovelfrie vandige oppløsning blir via ledningen 16 overført til den første regenereringssone 5 hvori minst endel av av den reduserte reaktant blir oxydert ved kontakt av den vandige oppløsning med luft som tilføres via ledningen 17 for tilførsel av oxydasjonsmiddel. Den. regenererte vandige reaktantoppløsning blir overført til den første kontaktsone 1 via ledningen 20, og brukt luft blir fjernet fra den første regenereringssone 5 via utløpet 19 for brukt gass. A hydrocarbon-containing sour gas mixture comprising 15% by volume CC>2 and 250 ppmv (parts per million, based on volume) I^S is supplied to the first contact zone 1 via the supply line 10 for sour gas. In the first contact zone 1, the acidic gas mixture is brought into contact with an aqueous reactant solution containing .0.65 mol/l of an ammonium form of a coordination complex of Fe(III) with NTA, to form a partially purified gas mixture containing 12 vol% CC>2 and 2 ppmv t^S, and an aqueous solution comprising sulfur and reduced reactant comprising an additional amount of an ammonium form of a coordination complex of Fe(II) with NTA. The aqueous solution comprising sulfur and reduced reactant is transferred via line 12 to the sulfur removal zone 3 from which sulfur is removed via line 15, and the substantially sulphur-free aqueous solution is transferred via line 16 to the first regeneration zone 5 in which at least part of the reduced reactant is oxidized by contact of the aqueous solution with air which is supplied via line 17 for supply of oxidizing agent. It. regenerated aqueous reactant solution is transferred to the first contact zone 1 via line 20, and spent air is removed from the first regeneration zone 5 via outlet 19 for spent gas.
Den delvis rensede gassblanding blir uten å bli be-handlet overført via ledningen 14 til den annen kontaktsone 6 hvori den blir bragt i kontakt med en flytende og regenererbar absorbent i form av en vandig oppløsning som inneholder The partially purified gas mixture is transferred without being treated via the line 14 to the second contact zone 6 in which it is brought into contact with a liquid and regenerable absorbent in the form of an aqueous solution containing
30 masse% MDEA, under slike betingelser at C02 blir fjernet fra den delvis rensede gassblanding slik at det dannes en renset gassblanding og brukt absorbent. Den rensede gassblanding som inneholder 1 volum% C02 og 1,5 ppmv H2S, blir fjernet fra den annen kontaktsone 7 via utløpet 21 for renset gass, og den brukte absorbent blir via ledningen 22 overført til den første flashbeholder 8. I den første flashbeholder 8 blir koabsorberte hydrocarboner fjernet ved å flashe av den brukte absorbent ved å oppheve trykket til et nivå som ligger mellom det trykk som hersker i den annen kontaktsone 6 og partialtrykket for C02 ved den herskende temperatur. Den desorberte hydrocarbonholdige gassblanding som er i det vesentlige fri for C02, blir fjernet fra den første flashbeholder 8 via gassutløpet 25. Den delvis brukte absorbent som fås i den første flashbeholder 8, blir via ledningen 2 6 overført til den annen flashbeholder 9. I 30 mass% MDEA, under such conditions that C02 is removed from the partially purified gas mixture so that a purified gas mixture and used absorbent are formed. The purified gas mixture containing 1% by volume C02 and 1.5 ppmv H2S is removed from the second contact zone 7 via the outlet 21 for purified gas, and the used absorbent is transferred via line 22 to the first flash container 8. In the first flash container 8 co-absorbed hydrocarbons are removed by flashing off the used absorbent by raising the pressure to a level that lies between the pressure prevailing in the second contact zone 6 and the partial pressure of CO 2 at the prevailing temperature. The desorbed hydrocarbon-containing gas mixture which is essentially free of C02 is removed from the first flash container 8 via the gas outlet 25. The partially used absorbent obtained in the first flash container 8 is transferred to the second flash container 9 via the line 26.
den annen flashbeholder 9 blir C02 fjernet fra den delvis brukte absorbent ved å oppheve trykket til et nivå under partialtrykket for C02 ved den herskende temperatur for å oppnå en regenerert absorbent som tilføres til en annen kontaktsone 6 via ledningen 31. Det desorberte C02 som er i det vesentlige fritt for H2S, blir fjernet fra den annen flashbeholder 9 via gassutløpet 30. the second flash container 9, C02 is removed from the partially used absorbent by depressurizing it to a level below the partial pressure of C02 at the prevailing temperature to obtain a regenerated absorbent which is supplied to another contact zone 6 via line 31. The desorbed C02 which is in the essentially free of H2S, is removed from the second flash container 9 via the gas outlet 30.
Den første kontaktsone 1 og den første regenereringssone 5 kan utgjøres av kolonner som er egnede for motstrøms-kontakt mellom gass og væske eller de kan være kolonner som er egnede for medstrømskontakt mellom gass og væske. The first contact zone 1 and the first regeneration zone 5 can be made up of columns which are suitable for counter-flow contact between gas and liquid or they can be columns which are suitable for co-flow contact between gas and liquid.
Claims (5)
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| GB8616508A GB2192347B (en) | 1986-07-07 | 1986-07-07 | Removing hydrogen sulphide and carbon dioxide from a gas mixture containing hydrogen sulphide and carbon dioxide. |
Publications (4)
| Publication Number | Publication Date |
|---|---|
| NO872756D0 NO872756D0 (en) | 1987-07-01 |
| NO872756L NO872756L (en) | 1988-01-08 |
| NO166920B true NO166920B (en) | 1991-06-10 |
| NO166920C NO166920C (en) | 1991-09-18 |
Family
ID=10600677
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| NO872756A NO166920C (en) | 1986-07-07 | 1987-07-01 | PROCEDURE FOR AA REMOVE H2S AND CO2 FROM A GAS MIXTURE. |
Country Status (9)
| Country | Link |
|---|---|
| CN (1) | CN1016166B (en) |
| AU (1) | AU590866B2 (en) |
| CA (1) | CA1296160C (en) |
| DE (1) | DE3721789A1 (en) |
| DK (1) | DK170394B1 (en) |
| GB (1) | GB2192347B (en) |
| IN (1) | IN169707B (en) |
| NL (1) | NL194362C (en) |
| NO (1) | NO166920C (en) |
Families Citing this family (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| NZ223528A (en) * | 1987-02-19 | 1991-08-27 | Dow Chemical Co | Process and scrubbing solution for removal of h 2 s and/or co 2 from gas streams |
| DE4014018A1 (en) * | 1990-05-01 | 1991-11-07 | Metallgesellschaft Ag | Gas purificn. using recyclable scrubber soln. - esp. for desulphurisation of fuel gas |
| GB9606685D0 (en) * | 1996-03-29 | 1996-06-05 | Boc Group Plc | Gas separation |
| DE102008052612A1 (en) * | 2008-10-21 | 2010-04-22 | Uhde Gmbh | Wash solution for gas scrubbing with amines in aqueous ammonia solution and use |
| CN102350174A (en) * | 2011-07-11 | 2012-02-15 | 中国石油化工集团公司 | Method for selective removal of H2S by dynamic wave scrubber |
| CN104667714A (en) * | 2013-12-03 | 2015-06-03 | 中国科学院过程工程研究所 | Device and method for deep removal of acid gas in industrial mixed gas |
| CN110218596B (en) * | 2019-05-30 | 2020-09-29 | 中石化石油机械股份有限公司研究院 | Deacidifying technological process of natural gas |
Family Cites Families (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4091073A (en) * | 1975-08-29 | 1978-05-23 | Shell Oil Company | Process for the removal of H2 S and CO2 from gaseous streams |
| US4359450A (en) * | 1981-05-26 | 1982-11-16 | Shell Oil Company | Process for the removal of acid gases from gaseous streams |
| US4409199A (en) * | 1981-12-14 | 1983-10-11 | Shell Oil Company | Removal of H2 S and COS |
-
1986
- 1986-07-07 GB GB8616508A patent/GB2192347B/en not_active Expired
-
1987
- 1987-05-22 NL NL8701225A patent/NL194362C/en not_active IP Right Cessation
- 1987-05-27 CA CA000538120A patent/CA1296160C/en not_active Expired - Fee Related
- 1987-06-30 CN CN87104539A patent/CN1016166B/en not_active Expired
- 1987-07-01 DE DE19873721789 patent/DE3721789A1/en not_active Withdrawn
- 1987-07-01 DK DK337487A patent/DK170394B1/en not_active IP Right Cessation
- 1987-07-01 NO NO872756A patent/NO166920C/en not_active IP Right Cessation
- 1987-07-01 IN IN473/MAS/87A patent/IN169707B/en unknown
- 1987-07-01 AU AU75007/87A patent/AU590866B2/en not_active Ceased
Also Published As
| Publication number | Publication date |
|---|---|
| GB2192347B (en) | 1989-12-13 |
| NL194362C (en) | 2002-02-04 |
| CN1016166B (en) | 1992-04-08 |
| AU7500787A (en) | 1988-01-14 |
| NO872756L (en) | 1988-01-08 |
| NL194362B (en) | 2001-10-01 |
| AU590866B2 (en) | 1989-11-16 |
| CN87104539A (en) | 1988-02-17 |
| DK337487A (en) | 1988-01-08 |
| NO872756D0 (en) | 1987-07-01 |
| NO166920C (en) | 1991-09-18 |
| GB8616508D0 (en) | 1986-08-13 |
| DK170394B1 (en) | 1995-08-21 |
| GB2192347A (en) | 1988-01-13 |
| IN169707B (en) | 1991-12-14 |
| CA1296160C (en) | 1992-02-25 |
| DK337487D0 (en) | 1987-07-01 |
| DE3721789A1 (en) | 1988-01-21 |
| NL8701225A (en) | 1988-02-01 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| JP5661681B2 (en) | Method for obtaining an acid gas stream under high pressure by removing acid gas from a fluid stream | |
| RU2239488C2 (en) | Absorbing compositions for removing acid gases from gas streams | |
| US20100310439A1 (en) | Process for removal of hydrogen sulphide and carbon dioxide from an acid gas stream | |
| US20060138384A1 (en) | Absorbing agent and method for eliminating acid gases from fluids | |
| JPS59168093A (en) | Removal of co2 and/or h2s from gas | |
| JPH048089B2 (en) | ||
| US7004997B2 (en) | Method for removal of acid gases from a gas flow | |
| US20110146489A1 (en) | Ammonia removal, following removal of co2, from a gas stream | |
| SU1577685A3 (en) | Method of removing carbon diaoxide in presence of hydrogen sulfide from gas | |
| US7695702B2 (en) | Optimization of amine regeneration system start-up using flash tank pressurization | |
| US4773921A (en) | Process and device for selective extraction of H2 S from an H2 S-containing gas | |
| KR101038764B1 (en) | Appraratus and method for solvent scrubbing co2 capture system | |
| NO166920B (en) | PROCEDURE FOR AA REMOVE H2S AND CO2 FROM A GAS MIXTURE. | |
| RU2012114920A (en) | METHOD AND INSTALLATION FOR REMOVING WATER FROM NATURAL GAS OR INDUSTRIAL GASES USING PHYSICAL SOLVENTS | |
| RU2080908C1 (en) | Method of isolating hydrogen sulfide from gas | |
| US20070284240A1 (en) | System and method for diagnosing and troubleshooting amine regeneration system | |
| US4714480A (en) | Removal of acid gases from a gas mixture | |
| JPS63500995A (en) | Method and apparatus for selectively extracting H↓2S from H↓2S-containing gas | |
| CA3026093C (en) | Novel process designs for increased selectivity and capacity for hydrogen sulfide capture from acid gases | |
| CA2814943A1 (en) | Use of 2-(3-aminopropoxy)ethan-1-ol as an absorbent to remove acidic gases | |
| GB2202522A (en) | Removing H2S and CO2 from a gas mixture including H2S and CO2 | |
| SU1715195A3 (en) | Absorbent for cleaning gas of acidic components | |
| EP2043762A2 (en) | System and method for diagnosing and troubleshooting amine regeneration system | |
| WO2007146611A2 (en) | Optimization of amine regeneration system start-up using flash tank pressurization | |
| JPH0557013B2 (en) |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| MM1K | Lapsed by not paying the annual fees |