WO2003011436A1 - Desulphurisation - Google Patents
Desulphurisation Download PDFInfo
- Publication number
- WO2003011436A1 WO2003011436A1 PCT/GB2002/003112 GB0203112W WO03011436A1 WO 2003011436 A1 WO2003011436 A1 WO 2003011436A1 GB 0203112 W GB0203112 W GB 0203112W WO 03011436 A1 WO03011436 A1 WO 03011436A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- units
- process according
- hydrolysis catalyst
- absorbent
- sulphide
- Prior art date
Links
- 238000006460 hydrolysis reaction Methods 0.000 claims abstract description 26
- 230000007062 hydrolysis Effects 0.000 claims abstract description 25
- 239000003054 catalyst Substances 0.000 claims abstract description 24
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 claims abstract description 23
- JJWKPURADFRFRB-UHFFFAOYSA-N carbonyl sulfide Chemical compound O=C=S JJWKPURADFRFRB-UHFFFAOYSA-N 0.000 claims abstract description 22
- 230000002745 absorbent Effects 0.000 claims abstract description 20
- 239000002250 absorbent Substances 0.000 claims abstract description 20
- 238000000034 method Methods 0.000 claims abstract description 15
- 239000012530 fluid Substances 0.000 claims abstract description 13
- 239000002245 particle Substances 0.000 claims abstract description 7
- 239000011872 intimate mixture Substances 0.000 claims abstract description 4
- 239000000203 mixture Substances 0.000 claims description 13
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 claims description 6
- 239000011230 binding agent Substances 0.000 claims description 5
- RYGMFSIKBFXOCR-UHFFFAOYSA-N Copper Chemical compound [Cu] RYGMFSIKBFXOCR-UHFFFAOYSA-N 0.000 claims description 4
- 229910052802 copper Inorganic materials 0.000 claims description 4
- 239000010949 copper Substances 0.000 claims description 4
- 150000004649 carbonic acid derivatives Chemical class 0.000 claims description 3
- 150000004679 hydroxides Chemical class 0.000 claims description 3
- 235000014692 zinc oxide Nutrition 0.000 claims description 2
- RNWHGQJWIACOKP-UHFFFAOYSA-N zinc;oxygen(2-) Chemical class [O-2].[Zn+2] RNWHGQJWIACOKP-UHFFFAOYSA-N 0.000 claims description 2
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 6
- 239000008187 granular material Substances 0.000 description 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 5
- 229910002092 carbon dioxide Inorganic materials 0.000 description 4
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 description 3
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical class [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 3
- HCHKCACWOHOZIP-UHFFFAOYSA-N Zinc Chemical compound [Zn] HCHKCACWOHOZIP-UHFFFAOYSA-N 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 3
- XFWJKVMFIVXPKK-UHFFFAOYSA-N calcium;oxido(oxo)alumane Chemical compound [Ca+2].[O-][Al]=O.[O-][Al]=O XFWJKVMFIVXPKK-UHFFFAOYSA-N 0.000 description 3
- 239000001569 carbon dioxide Substances 0.000 description 3
- 229910002090 carbon oxide Inorganic materials 0.000 description 3
- 239000004568 cement Substances 0.000 description 3
- 239000007789 gas Substances 0.000 description 3
- 239000001257 hydrogen Substances 0.000 description 3
- 229910052739 hydrogen Inorganic materials 0.000 description 3
- 238000003786 synthesis reaction Methods 0.000 description 3
- 239000011701 zinc Substances 0.000 description 3
- 229910052725 zinc Inorganic materials 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical class [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 description 2
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 2
- 239000005864 Sulphur Substances 0.000 description 2
- 238000006243 chemical reaction Methods 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 239000008188 pellet Substances 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- PWHULOQIROXLJO-UHFFFAOYSA-N Manganese Chemical compound [Mn] PWHULOQIROXLJO-UHFFFAOYSA-N 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 150000001399 aluminium compounds Chemical class 0.000 description 1
- 229940077746 antacid containing aluminium compound Drugs 0.000 description 1
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 229910052799 carbon Inorganic materials 0.000 description 1
- NKCVNYJQLIWBHK-UHFFFAOYSA-N carbonodiperoxoic acid Chemical compound OOC(=O)OO NKCVNYJQLIWBHK-UHFFFAOYSA-N 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 229910052742 iron Inorganic materials 0.000 description 1
- 229910052748 manganese Inorganic materials 0.000 description 1
- 239000011572 manganese Substances 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 150000002816 nickel compounds Chemical class 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- -1 oxides Chemical class 0.000 description 1
- 239000001301 oxygen Substances 0.000 description 1
- 229910052760 oxygen Inorganic materials 0.000 description 1
- 239000002574 poison Substances 0.000 description 1
- 231100000614 poison Toxicity 0.000 description 1
- 238000011144 upstream manufacturing Methods 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
- B01D53/34—Chemical or biological purification of waste gases
- B01D53/74—General processes for purification of waste gases; Apparatus or devices specially adapted therefor
- B01D53/86—Catalytic processes
- B01D53/8603—Removing sulfur compounds
- B01D53/8606—Removing sulfur compounds only one sulfur compound other than sulfur oxides or 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
- B01D53/02—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 adsorption, e.g. preparative gas chromatography
Definitions
- This invention relates to desulphurisation and in particular to the removal of sulphur compounds from fluid streams containing carbonyl sulphide.
- Carbonyl sulphide can be converted to hydrogen sulphide and carbon dioxide by hydrolysis with water.
- carbonyl sulphide is removed by passing the fluid (to which water has been added if necessary) through a bed of a suitable hydrolysis catalyst and then passing the effluent through a bed of a hydrogen sulphide absorbent or through an alternative hydrogen sulphide removal system. If the feedstock fluid contains hydrogen sulphide as well as carbonyl sulphide, in order to shift the equilibrium towards removal of the carbonyl sulphide, the fluid may be passed through a bed of a hydrogen sulphide absorbent prior to contact with the carbonyl sulphide hydrolysis catalyst.
- the present invention provides a process for the removal of carbonyl sulphide from a fluid stream comprising passing the fluid through a fixed bed of an intimate mixture of shaped units formed from particles of a carbonyl sulphide hydrolysis catalyst and shaped units formed from particles of an absorbent for hydrogen sulphide.
- Both types of shaped units in the mixture may be pellets, granules or extrudates having maxima and minima dimensions in the range 0.5 to 6 mm. They each preferably have an aspect ratio, i.e. the ratio of the maximum dimension to the minimum dimension, below 2. Preferably the maximum dimension of the absorbent units is 0.5 to 2 times the maximum dimension of the hydrolysis catalyst units.
- the relative proportions of the absorbent and hydrolysis catalyst units will depend on the activity of the hydrolysis catalyst units under the relevant process conditions. The greater the activity, the smaller is the proportion of hydrolysis catalyst units that is required, and hence the greater the overall sulphur removal capacity of the fixed bed.
- the use of a mixture of shaped units is advantageous compared to the use of shaped units formed from a mixture of particles of the hydrolysis catalyst and hydrogen sulphide absorbent as it is more versatile since the proportions of the units employed can be tailored to the specific application.
- the hydrolysis catalyst units form 5 to 50% by volume of the mixture of units.
- the hydrolysis catalyst units preferably comprise granules, pellets or extrudates of an activated alumina composition. They may contain 0% to 10% by weight of a suitable binder, for example calcium aluminate cement, to enable shaped units of adequate strength to be produced.
- the shaped units preferably have a BET surface area of above 50 m 2 /g, particularly over 00 m 2 /g, for example 150-400 m 2 /g.
- the hydrogen sulphide absorbent is preferably formed from a composition containing copper and/or zinc oxides, hydroxides, carbonates or hydroxycarbonates, and preferably has a BET surface area above 50 m 2 /g.
- the absorbent may also contain other components such as alumina and may contain up to about 10% by weight of a binder such as a calcium aluminate cement. Particularly suitable hydrogen sulphide absorbents are described in US 4871710.
- shaped units e.g. agglomerates, made from a precipitated composition containing copper, zinc and aluminium compounds and a binder can themselves be used for carbonyl sulphide removal
- the fluid stream being treated may be passed through the bed in the liquid or gaseous state at any convenient temperature ranging from ambient, i.e. about 20°C to about 200°C and at any convenient pressure, for example ranging from atmospheric to 100 bar abs.
- fluid streams to which the present invention may be applied include hydrocarbon streams such as natural gas; nitrogen and/or oxygen-containing streams such as air; carbon oxides streams such as carbon dioxide; and hydrogen-containing streams such as hydrogen/carbon oxides synthesis gas mixtures.
- the concentration of carbonyl sulphide in the fluid stream may vary within a wide range. Where it is more than about 100 ppm by weight, it may be desirable to decrease its concentration, prior to use as the feedstock to the process of the present invention, by an initial hydrolysis step followed by a hydrogen sulphide removal stage using for example a liquid absorbent.
- the feedstock also contains some water, preferably in an amount of at least three moles per mole of carbonyl sulphide.
Landscapes
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- Environmental & Geological Engineering (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)
- Solid-Sorbent Or Filter-Aiding Compositions (AREA)
- Catalysts (AREA)
Abstract
A process for the removal of carbonyl sulphide from a fluid stream comprises passing the fluid through a fixed bed of an intimate mixture of shaped units formed from particles of a carbonyl sulphide hydrolysis catalyst and shaped units formed from particles of an absorbent for hydrogen sulphide.
Description
Desulphurisation
This invention relates to desulphurisation and in particular to the removal of sulphur compounds from fluid streams containing carbonyl sulphide.
Carbonyl sulphide can be converted to hydrogen sulphide and carbon dioxide by hydrolysis with water.
COS + H20 <===> C02 + H2S This reaction is catalysed by a hydrolysis catalyst such as activated alumina. The resultant hydrogen sulphide can be removed by absorption with a suitable absorbent such as a composition containing copper, zinc, iron, manganese and/or nickel compounds such as oxides, hydroxides, carbonates, or hydroxycarbonates.
Conventionally carbonyl sulphide is removed by passing the fluid (to which water has been added if necessary) through a bed of a suitable hydrolysis catalyst and then passing the effluent through a bed of a hydrogen sulphide absorbent or through an alternative hydrogen sulphide removal system. If the feedstock fluid contains hydrogen sulphide as well as carbonyl sulphide, in order to shift the equilibrium towards removal of the carbonyl sulphide, the fluid may be passed through a bed of a hydrogen sulphide absorbent prior to contact with the carbonyl sulphide hydrolysis catalyst.
In some circumstances, e.g. upstream of poison-sensitive catalysts, it is desirable to achieve the minimum possible carbonyl sulphide content in the product stream. We have realised that the equilibrium may be shifted further towards the conversion of the carbonyl sulphide if the hydrogen sulphide is removed as it is formed.
Accordingly the present invention provides a process for the removal of carbonyl sulphide from a fluid stream comprising passing the fluid through a fixed bed of an intimate mixture of shaped units formed from particles of a carbonyl sulphide hydrolysis catalyst and shaped units formed from particles of an absorbent for hydrogen sulphide.
Both types of shaped units in the mixture may be pellets, granules or extrudates having maxima and minima dimensions in the range 0.5 to 6 mm. They each preferably have an aspect ratio, i.e. the ratio of the maximum dimension to the minimum dimension, below 2. Preferably the maximum dimension of the absorbent units is 0.5 to 2 times the maximum dimension of the hydrolysis catalyst units.
The relative proportions of the absorbent and hydrolysis catalyst units will depend on the activity of the hydrolysis catalyst units under the relevant process conditions. The greater the activity, the smaller is the proportion of hydrolysis catalyst units that is required, and hence the greater the overall sulphur removal capacity of the fixed bed. The use of a mixture of shaped units is advantageous compared to the use of shaped units formed from a mixture of particles of the hydrolysis catalyst and hydrogen sulphide absorbent as it is more versatile since the proportions of the units employed can be tailored to the specific application.
Preferably the hydrolysis catalyst units form 5 to 50% by volume of the mixture of units.
The hydrolysis catalyst units preferably comprise granules, pellets or extrudates of an activated alumina composition. They may contain 0% to 10% by weight of a suitable binder, for example calcium aluminate cement, to enable shaped units of adequate strength to be produced. The shaped units preferably have a BET surface area of above 50 m2/g, particularly over 00 m2/g, for example 150-400 m2/g.
The hydrogen sulphide absorbent is preferably formed from a composition containing copper and/or zinc oxides, hydroxides, carbonates or hydroxycarbonates, and preferably has a BET surface area above 50 m2/g. The absorbent may also contain other components such as alumina and may contain up to about 10% by weight of a binder such as a calcium aluminate cement. Particularly suitable hydrogen sulphide absorbents are described in US 4871710.
Although that reference indicates that shaped units, e.g. agglomerates, made from a precipitated composition containing copper, zinc and aluminium compounds and a binder can themselves be used for carbonyl sulphide removal, we have found that the use of a mixture of a carbonyl sulphide hydrolysis catalyst units and hydrogen sulphide absorbent units is advantageous, particularly at process temperatures below 80°C.
The fluid stream being treated may be passed through the bed in the liquid or gaseous state at any convenient temperature ranging from ambient, i.e. about 20°C to about 200°C and at any convenient pressure, for example ranging from atmospheric to 100 bar abs. Examples of fluid streams to which the present invention may be applied include hydrocarbon streams such as natural gas; nitrogen and/or oxygen-containing streams such as air; carbon oxides streams such as carbon dioxide; and hydrogen-containing streams such as hydrogen/carbon oxides synthesis gas mixtures.
The concentration of carbonyl sulphide in the fluid stream may vary within a wide range. Where it is more than about 100 ppm by weight, it may be desirable to decrease its concentration, prior to use as the feedstock to the process of the present invention, by an initial hydrolysis step followed by a hydrogen sulphide removal stage using for example a liquid absorbent.
Although water may be formed when the hydrogen sulphide formed by the hydrolysis is absorbed, and so is available for further hydrolysis reaction, it is preferred that the feedstock also contains some water, preferably in an amount of at least three moles per mole of carbonyl sulphide.
As an example, if a typical synthesis gas containing hydrogen and carbon oxides, with a carbon dioxide content of 3.5% by volume and containing 200 ppb by volume of carbonyl sulphide, 200 ppb by volume H2S and 10 ppm by volume of water, is brought to equilibrium by passage through a bed of a hydrolysis catalyst at a specified temperature, the carbonyl sulphide content of the product is as shown in the following table.
In a sequential system wherein a hydrogen sulphide absorbent bed is disposed downstream of the bed of hydrolysis catalyst, the carbonyl sulphide content of the product will not be lower than the equilibrium concentration.
In contrast, we have found that passage of such a synthesis gas through an intimate mixture of 1 volume of granules of an activated alumina hydrolysis catalyst and 4 volumes of granules of a hydrogen sulphide absorbent, comprising zinc hydroxycarbonate and 10% by weight of a calcium aluminate cement binder, at about 75°C and about 50 bar abs. pressure, with a contact time of about 15 seconds gave a product containing no detectable carbonyl sulphide or hydrogen sulphide (detection limits 2 ppb by volume). Both the hydrolysis catalyst and the hydrogen sulphide absorbent were in the form of approximately spherical granules of diameter in the range 2.5 to 5 mm.
The process was found to be beneficial to the performance of a sulphur sensitive catalyst in a down-stream operation.
Claims
1. A process for the removal of carbonyl sulphide from a fluid stream comprising passing the fluid through a fixed bed of an intimate mixture of shaped units formed from particles of a carbonyl sulphide hydrolysis catalyst and shaped units formed from particles of an absorbent for hydrogen sulphide.
2. A process according to claim 1 wherein the shaped units have maxima and minima dimensions in the range 0.5 to 6 mm and an aspect ratio below 2.
3. A process according to claim 1 or claim 2 wherein the maximum dimension of the absorbent units is 0.5 to 2 times the maximum dimension of the hydrolysis catalyst units.
4. A process according to any one of claims 1 to 3 wherein the hydrolysis catalyst units form 5 to 50% by volume of the mixture of units.
5. A process according to any one of claims 1 to 4 wherein the hydrolysis catalyst units are formed from an activated alumina composition and contain 0 to 10% by weight of a binder.
6. A process according to claim 5 wherein the hydrolysis catalyst units have a BET surface area of above 50 m2/g.
7. A process according to any one of claims 1 to 6 wherein the hydrogen sulphide absorbent is formed from a composition containing copper and/or zinc oxides, hydroxides, carbonates or hydroxycarbonates.
8. A process according to claim 7 wherein the absorbent also contains alumina.
9. A process according to any one of claims 1 to 8 wherein the feedstock is passed through the bed at a temperature ranging from 20°C to 200°C.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| GB0118416.7 | 2001-07-30 | ||
| GB0118416A GB0118416D0 (en) | 2001-07-30 | 2001-07-30 | Desulphurisation |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| WO2003011436A1 true WO2003011436A1 (en) | 2003-02-13 |
Family
ID=9919352
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| PCT/GB2002/003112 WO2003011436A1 (en) | 2001-07-30 | 2002-07-08 | Desulphurisation |
Country Status (2)
| Country | Link |
|---|---|
| GB (1) | GB0118416D0 (en) |
| WO (1) | WO2003011436A1 (en) |
Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| WO2006008317A1 (en) * | 2004-07-22 | 2006-01-26 | Shell Internationale Research Maatschappij B.V. | Process for the removal of cos from a synthesis gas stream comprising h2s and cos |
| WO2006065459A1 (en) | 2004-12-17 | 2006-06-22 | Exxonmobil Research And Engineering Company | Systems and processes for reducing the sulfer content of hydrocarbon streams |
| WO2007082896A1 (en) * | 2006-01-18 | 2007-07-26 | Shell Internationale Research Maatschappij B.V. | Process for removing carbonyl sulphide and hydrogen sulphide from a synthesis gas stream |
| CN113426289A (en) * | 2021-06-29 | 2021-09-24 | 松山湖材料实验室 | Hydrolysis adsorbent, blast furnace gas desulfurization method and desulfurization equipment |
| EP4497805A1 (en) * | 2023-07-24 | 2025-01-29 | Bloom Energy Corporation | Mixed media desulfurization systems and fuel cell systems including the same |
Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| FR2574310A1 (en) * | 1984-12-12 | 1986-06-13 | Elf Aquitaine | Process for removing the compounds COS and CS2 contained in an industrial gas. |
| EP0218153A2 (en) * | 1985-09-28 | 1987-04-15 | BASF Aktiengesellschaft | Process for eliminating sulfur compounds from gas streams |
| EP0698577A1 (en) * | 1994-08-25 | 1996-02-28 | The Boc Group, Inc. | Process for the purification of carbon dioxide |
| US5853681A (en) * | 1994-03-17 | 1998-12-29 | Imperial Chemical Industries Plc | Absorbents |
-
2001
- 2001-07-30 GB GB0118416A patent/GB0118416D0/en not_active Ceased
-
2002
- 2002-07-08 WO PCT/GB2002/003112 patent/WO2003011436A1/en not_active Application Discontinuation
Patent Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| FR2574310A1 (en) * | 1984-12-12 | 1986-06-13 | Elf Aquitaine | Process for removing the compounds COS and CS2 contained in an industrial gas. |
| EP0218153A2 (en) * | 1985-09-28 | 1987-04-15 | BASF Aktiengesellschaft | Process for eliminating sulfur compounds from gas streams |
| US5853681A (en) * | 1994-03-17 | 1998-12-29 | Imperial Chemical Industries Plc | Absorbents |
| EP0698577A1 (en) * | 1994-08-25 | 1996-02-28 | The Boc Group, Inc. | Process for the purification of carbon dioxide |
Cited By (13)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| AU2005263776B2 (en) * | 2004-07-22 | 2008-07-31 | Shell Internationale Research Maatschappij B.V. | Process for the removal of COS from a synthesis gas stream comprising H2S and COS |
| US7846325B2 (en) | 2004-07-22 | 2010-12-07 | Shell Oil Company | Process for the removal of COS and H2S from a synthesis gas stream comprising H2S and COS |
| WO2006008317A1 (en) * | 2004-07-22 | 2006-01-26 | Shell Internationale Research Maatschappij B.V. | Process for the removal of cos from a synthesis gas stream comprising h2s and cos |
| EA010025B1 (en) * | 2004-07-22 | 2008-06-30 | Шелл Интернэшнл Рисерч Маатсхаппий Б.В. | Process for the removal of cos from a synthesis gas stream comprising hs and cos |
| US7427385B2 (en) | 2004-12-17 | 2008-09-23 | Exxonmobil Research And Engineering Company | Systems and processes for reducing the sulfur content of hydrocarbon streams |
| JP2008524377A (en) * | 2004-12-17 | 2008-07-10 | エクソンモービル リサーチ アンド エンジニアリング カンパニー | System and method for reducing the sulfur content of a hydrocarbon stream |
| WO2006065459A1 (en) | 2004-12-17 | 2006-06-22 | Exxonmobil Research And Engineering Company | Systems and processes for reducing the sulfer content of hydrocarbon streams |
| CN101080482B (en) * | 2004-12-17 | 2011-09-14 | 埃克森美孚研究工程公司 | Systems and processes for reducing the sulfer content of hydrocarbon streams |
| TWI382873B (en) * | 2004-12-17 | 2013-01-21 | Exxonmobil Res & Eng Co | Systems and processes for reducing the sulfur content of hydrocarbon streams |
| WO2007082896A1 (en) * | 2006-01-18 | 2007-07-26 | Shell Internationale Research Maatschappij B.V. | Process for removing carbonyl sulphide and hydrogen sulphide from a synthesis gas stream |
| US8043589B2 (en) | 2006-01-18 | 2011-10-25 | Shell Oil Company | Process for removing carbonyl sulphide and hydrogen sulphide from a synthesis gas stream |
| CN113426289A (en) * | 2021-06-29 | 2021-09-24 | 松山湖材料实验室 | Hydrolysis adsorbent, blast furnace gas desulfurization method and desulfurization equipment |
| EP4497805A1 (en) * | 2023-07-24 | 2025-01-29 | Bloom Energy Corporation | Mixed media desulfurization systems and fuel cell systems including the same |
Also Published As
| Publication number | Publication date |
|---|---|
| GB0118416D0 (en) | 2001-09-19 |
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