EP0215911A1 - Selektive absorption von wasserstoffsulfid aus gasen enthaltend kohlenstoffdioxyd - Google Patents
Selektive absorption von wasserstoffsulfid aus gasen enthaltend kohlenstoffdioxydInfo
- Publication number
- EP0215911A1 EP0215911A1 EP86902174A EP86902174A EP0215911A1 EP 0215911 A1 EP0215911 A1 EP 0215911A1 EP 86902174 A EP86902174 A EP 86902174A EP 86902174 A EP86902174 A EP 86902174A EP 0215911 A1 EP0215911 A1 EP 0215911A1
- Authority
- EP
- European Patent Office
- Prior art keywords
- carbon dioxide
- hydrogen sulfide
- absorption solution
- gas stream
- amine compound
- 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.)
- Withdrawn
Links
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 title claims abstract description 148
- 238000010521 absorption reaction Methods 0.000 title claims abstract description 77
- 229910002092 carbon dioxide Inorganic materials 0.000 title claims abstract description 76
- 239000001569 carbon dioxide Substances 0.000 title claims abstract description 75
- 239000007789 gas Substances 0.000 title claims abstract description 49
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 title description 2
- UCKMPCXJQFINFW-UHFFFAOYSA-N Sulphide Chemical compound [S-2] UCKMPCXJQFINFW-UHFFFAOYSA-N 0.000 title 1
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 claims abstract description 73
- 229910000037 hydrogen sulfide Inorganic materials 0.000 claims abstract description 66
- 150000001412 amines Chemical class 0.000 claims abstract description 40
- 239000003085 diluting agent Substances 0.000 claims abstract description 28
- 150000003512 tertiary amines Chemical class 0.000 claims abstract description 9
- 238000000034 method Methods 0.000 claims description 41
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 34
- -1 amine compound Chemical class 0.000 claims description 32
- 229910001868 water Inorganic materials 0.000 claims description 32
- 230000002745 absorbent Effects 0.000 claims description 25
- 239000002250 absorbent Substances 0.000 claims description 25
- 239000000203 mixture Substances 0.000 claims description 17
- LYCAIKOWRPUZTN-UHFFFAOYSA-N ethylene glycol Natural products OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 claims description 16
- 150000002334 glycols Chemical class 0.000 claims description 16
- GSEJCLTVZPLZKY-UHFFFAOYSA-N Triethanolamine Chemical compound OCCN(CCO)CCO GSEJCLTVZPLZKY-UHFFFAOYSA-N 0.000 claims description 11
- WGCNASOHLSPBMP-UHFFFAOYSA-N hydroxyacetaldehyde Natural products OCC=O WGCNASOHLSPBMP-UHFFFAOYSA-N 0.000 claims description 9
- SECXISVLQFMRJM-UHFFFAOYSA-N N-Methylpyrrolidone Chemical compound CN1CCCC1=O SECXISVLQFMRJM-UHFFFAOYSA-N 0.000 claims description 8
- CRVGTESFCCXCTH-UHFFFAOYSA-N methyl diethanolamine Chemical compound OCCN(C)CCO CRVGTESFCCXCTH-UHFFFAOYSA-N 0.000 claims description 8
- 230000007717 exclusion Effects 0.000 claims description 6
- 239000007788 liquid Substances 0.000 claims description 6
- 229910052739 hydrogen Inorganic materials 0.000 claims description 5
- 239000001257 hydrogen Substances 0.000 claims description 5
- 238000000926 separation method Methods 0.000 claims description 5
- 238000010438 heat treatment Methods 0.000 claims description 3
- 150000001875 compounds Chemical class 0.000 claims description 2
- 238000004064 recycling Methods 0.000 claims 4
- 125000004435 hydrogen atom Chemical class [H]* 0.000 claims 3
- YSUIQYOGTINQIN-UZFYAQMZSA-N 2-amino-9-[(1S,6R,8R,9S,10R,15R,17R,18R)-8-(6-aminopurin-9-yl)-9,18-difluoro-3,12-dihydroxy-3,12-bis(sulfanylidene)-2,4,7,11,13,16-hexaoxa-3lambda5,12lambda5-diphosphatricyclo[13.2.1.06,10]octadecan-17-yl]-1H-purin-6-one Chemical compound NC1=NC2=C(N=CN2[C@@H]2O[C@@H]3COP(S)(=O)O[C@@H]4[C@@H](COP(S)(=O)O[C@@H]2[C@@H]3F)O[C@H]([C@H]4F)N2C=NC3=C2N=CN=C3N)C(=O)N1 YSUIQYOGTINQIN-UZFYAQMZSA-N 0.000 claims 1
- 239000002904 solvent Substances 0.000 abstract description 10
- 239000006096 absorbing agent Substances 0.000 abstract description 2
- 238000000605 extraction Methods 0.000 abstract 1
- 239000000243 solution Substances 0.000 description 33
- MTHSVFCYNBDYFN-UHFFFAOYSA-N diethylene glycol Chemical compound OCCOCCO MTHSVFCYNBDYFN-UHFFFAOYSA-N 0.000 description 10
- 238000006243 chemical reaction Methods 0.000 description 9
- BVKZGUZCCUSVTD-UHFFFAOYSA-M Bicarbonate Chemical class OC([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-M 0.000 description 4
- 239000000470 constituent Substances 0.000 description 4
- 239000000126 substance Substances 0.000 description 4
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 3
- 150000004649 carbonic acid derivatives Chemical class 0.000 description 3
- 238000011084 recovery Methods 0.000 description 3
- ARXJGSRGQADJSQ-UHFFFAOYSA-N 1-methoxypropan-2-ol Chemical compound COCC(C)O ARXJGSRGQADJSQ-UHFFFAOYSA-N 0.000 description 2
- 125000003277 amino group Chemical group 0.000 description 2
- 239000007864 aqueous solution Substances 0.000 description 2
- 150000004657 carbamic acid derivatives Chemical class 0.000 description 2
- 229910052799 carbon Inorganic materials 0.000 description 2
- 125000004432 carbon atom Chemical group C* 0.000 description 2
- 238000009833 condensation Methods 0.000 description 2
- 230000005494 condensation Effects 0.000 description 2
- WKFQMDFSDQFAIC-UHFFFAOYSA-N 2,4-dimethylthiolane 1,1-dioxide Chemical compound CC1CC(C)S(=O)(=O)C1 WKFQMDFSDQFAIC-UHFFFAOYSA-N 0.000 description 1
- VXQBJTKSVGFQOL-UHFFFAOYSA-N 2-(2-butoxyethoxy)ethyl acetate Chemical compound CCCCOCCOCCOC(C)=O VXQBJTKSVGFQOL-UHFFFAOYSA-N 0.000 description 1
- CUDYYMUUJHLCGZ-UHFFFAOYSA-N 2-(2-methoxypropoxy)propan-1-ol Chemical compound COC(C)COC(C)CO CUDYYMUUJHLCGZ-UHFFFAOYSA-N 0.000 description 1
- WAEVWDZKMBQDEJ-UHFFFAOYSA-N 2-[2-(2-methoxypropoxy)propoxy]propan-1-ol Chemical compound COC(C)COC(C)COC(C)CO WAEVWDZKMBQDEJ-UHFFFAOYSA-N 0.000 description 1
- JTXMVXSTHSMVQF-UHFFFAOYSA-N 2-acetyloxyethyl acetate Chemical compound CC(=O)OCCOC(C)=O JTXMVXSTHSMVQF-UHFFFAOYSA-N 0.000 description 1
- QTBSBXVTEAMEQO-UHFFFAOYSA-M Acetate Chemical compound CC([O-])=O QTBSBXVTEAMEQO-UHFFFAOYSA-M 0.000 description 1
- KMTRUDSVKNLOMY-UHFFFAOYSA-N Ethylene carbonate Chemical compound O=C1OCCO1 KMTRUDSVKNLOMY-UHFFFAOYSA-N 0.000 description 1
- 239000002202 Polyethylene glycol Substances 0.000 description 1
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 150000001346 alkyl aryl ethers Chemical group 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- BVKZGUZCCUSVTD-UHFFFAOYSA-N carbonic acid Chemical compound OC(O)=O BVKZGUZCCUSVTD-UHFFFAOYSA-N 0.000 description 1
- 239000012159 carrier gas Substances 0.000 description 1
- 239000007795 chemical reaction product Substances 0.000 description 1
- 235000009508 confectionery Nutrition 0.000 description 1
- 150000001983 dialkylethers Chemical class 0.000 description 1
- UBPGILLNMDGSDS-UHFFFAOYSA-N diethylene glycol diacetate Chemical compound CC(=O)OCCOCCOC(C)=O UBPGILLNMDGSDS-UHFFFAOYSA-N 0.000 description 1
- 230000008030 elimination Effects 0.000 description 1
- 238000003379 elimination reaction Methods 0.000 description 1
- 150000002170 ethers Chemical class 0.000 description 1
- 150000002431 hydrogen Chemical class 0.000 description 1
- 239000012535 impurity Substances 0.000 description 1
- 230000014759 maintenance of location Effects 0.000 description 1
- 125000002496 methyl group Chemical group [H]C([H])([H])* 0.000 description 1
- WVDDGKGOMKODPV-ZQBYOMGUSA-N phenyl(114C)methanol Chemical compound O[14CH2]C1=CC=CC=C1 WVDDGKGOMKODPV-ZQBYOMGUSA-N 0.000 description 1
- 229920001223 polyethylene glycol Polymers 0.000 description 1
- 150000003141 primary amines Chemical class 0.000 description 1
- RUOJZAUFBMNUDX-UHFFFAOYSA-N propylene carbonate Chemical compound CC1COC(=O)O1 RUOJZAUFBMNUDX-UHFFFAOYSA-N 0.000 description 1
- 238000000746 purification Methods 0.000 description 1
- 239000000376 reactant Substances 0.000 description 1
- 238000005215 recombination Methods 0.000 description 1
- 230000006798 recombination Effects 0.000 description 1
- 150000003335 secondary amines Chemical group 0.000 description 1
- 229910052717 sulfur Inorganic materials 0.000 description 1
- 239000011593 sulfur Substances 0.000 description 1
- 238000003786 synthesis reaction Methods 0.000 description 1
- UWHCKJMYHZGTIT-UHFFFAOYSA-N tetraethylene glycol Chemical group OCCOCCOCCOCCO UWHCKJMYHZGTIT-UHFFFAOYSA-N 0.000 description 1
- ZUHZGEOKBKGPSW-UHFFFAOYSA-N tetraglyme Chemical compound COCCOCCOCCOCCOC ZUHZGEOKBKGPSW-UHFFFAOYSA-N 0.000 description 1
- 150000003568 thioethers Chemical class 0.000 description 1
- 231100000331 toxic Toxicity 0.000 description 1
- 230000002588 toxic effect Effects 0.000 description 1
- STCOOQWBFONSKY-UHFFFAOYSA-N tributyl phosphate Chemical compound CCCCOP(=O)(OCCCC)OCCCC STCOOQWBFONSKY-UHFFFAOYSA-N 0.000 description 1
- DQWPFSLDHJDLRL-UHFFFAOYSA-N triethyl phosphate Chemical compound CCOP(=O)(OCC)OCC DQWPFSLDHJDLRL-UHFFFAOYSA-N 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C01—INORGANIC CHEMISTRY
- C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
- C01B17/00—Sulfur; Compounds thereof
- C01B17/16—Hydrogen sulfides
- C01B17/167—Separation
-
- 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
-
- 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
Definitions
- the present invention is directed to an improved process for the selective absorption of hydrogen sulfide (H2S) from gas streams, such as natural or synthesis gas streams, which also contain carbon dioxide (CO2).
- gas streams such as natural or synthesis gas streams, which also contain carbon dioxide (CO2).
- a process for removal of hydrogen sulfide from gas streams comprising hydrogen sulfide and carbon dioxide by contacting the gas stream with a substantially anhydrous absorption solution comprising at least one amine compound selected from the group consisting of tertiary amines and hindered amines, present in an amount sufficient to absorb the hydrogen sulfide contained in the gas stream at a temperature above the dew point of water in the gas stream, to selectively remove hydrogen sulfide substantially to the essential exclusion of carbon dioxide, and stripping the absorbed hydrogen sulfide from the substantially anhydrous absorption solution to regenerate the amine for recycle.
- the process is carried out at ambient temperature and atmospheric pressure or above, with the temperature preferably ranging from ambient to about 15 ⁇ °F. If operated at elevated pressure, physically absorbed carbon dioxide can be desorbed effectively by pressure reduction after the absorption stage.
- the absorption solution may be 100% amine, it is convenient to provide a solution diluted with a low-cost diluent for the amine, which diluent has only physical absorptivity for carbon dioxide and other constituents of the gas such as COS, CS2 and mercaptans, and does not chemically bind carbon dioxide.
- the physical absorptivity of the diluent is preferably about 5 volumes or less carbon dioxide per volume of diluent at a temperature of 77°F and a partial pressure of CO2 of one atmosphere. However, if more removal of CO2 from the feed gas is desired, solvents of higher absorptivity for CO2 may be employed.
- the ratio of the amount of physical solvent in the mixture to the amount of amine in the mixture can be adjusted so that the required amount of CO2 and H2S are absorbed simultaneously from the gas undergoing treatment.
- the pressure of the treating solution is then reduced and the absorbed C0 2 and other physically absorbed gases are flashed from the absorbant solution.
- the absorbed H2 which is chemically bonded to the amine or other H2 reactant, is not desorbed until the solution is stripped in the heated stripping column.
- the H2 and CO2 are thereby effectively separated for more economical processing of the H2S in a Claus plant.
- the absorption solution can contain up to about 5% by weight water, for, at this concentration the rate of absorption of carbon dioxide by the water, for forming carbonates and bicarbonates, is very low.
- the small amount of water may be beneficially used as a stripping vapor in the stripping of hydrogen sulfide from the absorption solution.
- the amine chemically absorbs hydrogen sufide. Any carbon dioxide absorbed is, for all practical purposes, absorbed physically.
- the spent solution may first be formed to a pressure-reduction zone, where carbon dioxide and other physically absorbed constituents are removed by flashing, and then to a recovery zone, where the hydrogen sulfide is stripped from the solution by application of heat, with or without prior elimination of carbon dioxide.
- the stripping carrier gas may comprise the small amount of. water present in the solution, which water is condensed and recycled to maintain water balance in the solution.
- the hydrogen sulfide is extracted in a concentrated form for passage through a sulfur-recovery unit, such as a Claus plant.
- the object is to remove hydrogen sulfide substantially to the exclusion of carbon dioxide, as the former is highly toxic and the latter is innocuous.
- absorption tower i ⁇ a sour feed gas 12 containing hydrogen sulfide as the most undesirable impurity, but also containing carbon dioxide and other minor constituents such as COS, CS2 and mercap- tans.
- Absorber 10 is normally a multi-plate absorption column where, as shown, the absorption solution is intro ⁇ quizd by line 14 countercurrent to the flow of gas. Purified gas leaves by line 16 at the top of the column, and spent absorbent leaves by line 18 at the base of the column.
- Spent absorbent after being heated in 'exchanger 20 with return stripped absorbent from heated stripping column 24, is passed by line 22 to the top of heated stripping column 24.
- Heat is applied at the base of the stripping column, conveniently through reboiler 26, to furnish the heat required to desorb the absorbed hydrogen sulfide and to vaporize water to act as carrier vapor for hydrogen sulfide.
- Pressure-reduction flash zone 30 may be employed ahead of heated stripping column 24, in cases where it is desired to release physically absorbed carbon dioxide and other physically dissolved constituents.
- Regenerated absorption solution from heated strip ⁇ ping column 24 is returned by pump 36 through cooler 38 to absorption tower 10, and condensate from knock-out drum 29 is returned by pump 32 to heated stripping column 24.
- a concentrated hydrogen sulfide stream is passed by ' line 34 to a sulfur-recovery system, such as a Claus plant.
- the absorption solution be water-free, or substantially water-free, with a water concentration of up to about 5% by volume being tolerable.
- the amine employed be a tertiary amine, a hindered amine, or mixtures thereof, and, if a diluent for the amine is employed, such diluent is no more than a physical absorbent for carbon dioxide, preferably a physical absorbent wherein the capacity is not more than about 5 volumes of gaseous carbon dioxide, at 77°F and one atmosphere partial pressure of carbon dioxide per liquid volume of physical absorbent. Solu ⁇ tions meeting such criteria are effectively precluded from enabling significant reaction of carbon dioxide with the amine. ,
- tertiary amines there may be mentioned triethanolamine, methyldiethanol- amine, and the like.
- a "sterically hindered amine” is a primary amine in which the amino group is attached to a tertiary carbon atom, or a secondary amine in which the amino group is attached to a secondary or tertiary carbon atom.
- the amine acts as a chemical absorbent for hydrogen sulfide, and strongly bonds hydrogen sulfide to the amine following the formation of hydrosulfides. Reaction is very rapid.
- the flow and concentration rates of the a ine are adjusted, in terms of the hydrogen sulfide con ⁇ centration of the stream to be purified, to essentially enable absorption equilibrium to be reached. This is accomplished by sufficient contact time with a solution sufficiently lean along the length of the column to substantially absorb all the hydrogen sulfide present in the sour gas stream, thereby yielding a sweet gas for further processing.
- an absorption solution of 100% amine may be employed, it is convenient to dilute the amine with a non- chemical absorbent for carbon dioxide.
- a non- chemical absorbent for carbon dioxide There may be employed, for instance, physical absorbents for carbon dioxide which, at the normal temperatures of operation, i.e., ambient or above, have a relatively low solubility for carbon dioxide, e.g., about 5 or less volumes (gas) per volume liquid. Lower-than-ambient temperatures may also be employed to increase the amount of carbon dioxide taken up by the physical absorbent that will become part of the hydrogen sulfide separated in the stripper 24. However, the CO2 can be separated from the H2S by flash ⁇ ing zone 30.
- glycols such as diethylene glycol, tri ⁇ ethylene glycol, and ethylene glycol
- glycol esters such as monoalkyl and dialkyl ethers of diethylene glycol, triethylene glycol ethers, polyethylene glycol ethers and the like.
- N-methyl pyrrolidone ethylene glycol diacetate, diethylene glycol diacetate, triethyl phosphate, butyl carbitol acetate, methyl cellusolve acetate, propylene glycol methyl ether.
- tributyl phosphate dipropylene glycol methyl ether, tripropylene glycol methyl ether, carbitol, diethyl ⁇ ene glycol diethyl ether, propylene carbonate, dimethyl sulfolane, dimethoxy tetraglycol, mixtures of ethylene carbonate, benzyl alcohol, and the like.
- the amount of diluent solvent utilized may be up to about 90% by weight, based on the weight of the diluent solvent and the amine, and provide a combined solution which has a sufficiently low viscosity to enable flow through the absorption column at and below ambient temperatures. It may be desirable that the feed gas be pretreated with a dessicant to remove as much water vapor as possible. This is because it is desirable to operate the absorption column under substantially anhydrous conditions, and it is nor- mally inevitable that some moisture will be taken up by the solution, as the diluent for the amine will normally be hygroscopic, or some water condensation or retention may occur.
- the absorption column At a tem ⁇ perature above the dew point of water in the gas stream undergoing purification, to prevent condensation. This limits water take-up to that which may result in conse ⁇ quence of the hygroscopicity of the solution employed.
- maintaining a water-content level of about 5% by volume of absorption solution or less can be beneficial. This will essentially eliminate the formation of carbonates and bicarbonates, because the rate of reaction is low, yet there is a sufficient amount of water to enable its effective use in stripping hydrogen sulfide from the absorption solution.
- the advantage of the practice of the process of the instant invention is a materially sharper selectivity of hydrogen sulfide to the exclusion of chemically bound carbon dioxide.
- hydrogen sulfide beyond that which chemically bonds with the amine, is absorbed in the diluent solvent by physical solubility and may be recovered in the stripping column.
- the sweetened gas stream may, if desired, be separately processed for carbon dioxide removal using chemical solvents. What is unique, however, is the achievement of separation at extremely low cost using conventional absorbents and relying on substantially anhydrous conditions to achieve the desired result.
- the lean absorption solution contains 23.8% methyldiethanola- mine, the balance ' being anhydrous diethylene glycol.
- the absorption solution temperature is 40°C.
- the process gas stream is passed countercurrent to the absorption solution.
- the absorption solution is then passed to a flash zone, where the physically absorbed carbon dioxide is released through a reduction in pressure; the balance of the absorption solution is then passed through a stripping zone, where the absorbed hydrogen sulfide is released by heating as a concentrated hydrogen sulfide stream for processing to sulfur; and the lean absorption solution is recycled back to the absorption column.
Landscapes
- Chemical & Material Sciences (AREA)
- Organic Chemistry (AREA)
- Engineering & Computer Science (AREA)
- Analytical Chemistry (AREA)
- General Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Inorganic Chemistry (AREA)
- Gas Separation By Absorption (AREA)
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US71168085A | 1985-03-14 | 1985-03-14 | |
US711680 | 1985-03-14 |
Publications (1)
Publication Number | Publication Date |
---|---|
EP0215911A1 true EP0215911A1 (de) | 1987-04-01 |
Family
ID=24859069
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP86902174A Withdrawn EP0215911A1 (de) | 1985-03-14 | 1986-03-13 | Selektive absorption von wasserstoffsulfid aus gasen enthaltend kohlenstoffdioxyd |
Country Status (2)
Country | Link |
---|---|
EP (1) | EP0215911A1 (de) |
WO (1) | WO1986005474A1 (de) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US11383197B2 (en) | 2018-02-14 | 2022-07-12 | Taminco Bvba | Contaminant removal process |
Families Citing this family (19)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
JPS63111918A (ja) * | 1986-10-30 | 1988-05-17 | Toho Chem Ind Co Ltd | 酸性ガス吸収剤用組成物 |
US4770862A (en) * | 1987-05-26 | 1988-09-13 | Shell Oil Company | Removal of hydrogen sulfide from supercritical carbon dioxide |
EP0322924A1 (de) * | 1987-12-31 | 1989-07-05 | Union Carbide Corporation | Selektive H2S Entfernung von Fluidmischungen mit hochreinem Triethanolamin |
FR2631853B1 (fr) * | 1988-05-24 | 1992-01-24 | Elf Aquitaine | Liquide absorbant des gaz acides renfermant une composante alcanolamine tertiaire et un activateur d'absorption du co2 et son application a la desacidification de gaz contenant co2 et eventuellement d'autres gaz acides |
ES2054049T5 (es) * | 1988-05-24 | 1997-12-16 | Elf Aquitaine | Liquido absorbente de gases acidos que contiene una alcanol-amina terciaria y un activador de absorcion del co2, y su aplicacion a la desacidificacion de gas conteniendo co2 y eventualmente otros gases acidos. |
US5700438A (en) * | 1996-08-05 | 1997-12-23 | Miller; John C. | Process for removal of H2S from gas processing streams |
US7083662B2 (en) | 2003-12-18 | 2006-08-01 | Air Products And Chemicals, Inc. | Generation of elevated pressure gas mixtures by absorption and stripping |
US20120061613A1 (en) * | 2010-09-10 | 2012-03-15 | Battelle Memorial Institute | System and process for capture of acid gasses at elevated-pressure from gaseous process streams |
US8652237B2 (en) | 2010-12-17 | 2014-02-18 | Battelle Memorial Institute | System and process for capture of H2S from gaseous process streams and process for regeneration of the capture agent |
WO2015065839A1 (en) | 2013-10-30 | 2015-05-07 | Dow Globlal Technologies Llc | Hybrid solvent formulations for selective h2s removal |
CA2927937A1 (en) | 2013-10-30 | 2015-05-07 | Dow Global Technologies Llc | Hybrid solvent formulations for total organic sulfur removal and total acidic gas removal |
US10130907B2 (en) | 2016-01-20 | 2018-11-20 | Battelle Memorial Institute | Capture and release of acid gasses using tunable organic solvents with aminopyridine |
US10940432B2 (en) | 2016-04-27 | 2021-03-09 | Dow Global Technologies Llc | Process for selective removal of acid gases from fluid streams using a hybrid solvent mixture |
US10456739B2 (en) | 2016-11-14 | 2019-10-29 | Battelle Memorial Institute | Capture and release of acid gasses using tunable organic solvents with binding organic liquids |
US10933367B2 (en) | 2017-03-03 | 2021-03-02 | Dow Global Technologies Llc | Process for separating hydrogen sulfide from gaseous mixtures using a hybrid solvent mixture |
US11167241B2 (en) | 2017-03-06 | 2021-11-09 | Dow Global Technologies Llc | Energy efficient process for separating hydrogen sulfide from gaseous mixtures using a hybrid solvent mixture |
US11253811B2 (en) | 2017-03-07 | 2022-02-22 | Dow Global Technologies Llc | Process for reducing energy consumption in the regeneration of hybrid solvents |
US20220226769A1 (en) * | 2019-05-28 | 2022-07-21 | Kabushiki Kaisha Kobe Seiko Sho (Kobe Steel, Ltd.) | Gas treatment method, and gas treatment device |
CN118022517A (zh) * | 2022-11-07 | 2024-05-14 | 中国石油天然气股份有限公司 | 一种常压下吸收硫化氢和有机硫的脱硫剂及其制备方法与应用 |
Family Cites Families (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
FR2425886A1 (fr) * | 1978-05-16 | 1979-12-14 | Elf Aquitaine | Procede de purification de gaz residuaires industriels renfermant en faibles concentrations des composes soufres |
IT1132170B (it) * | 1980-07-04 | 1986-06-25 | Snam Progetti | Processo di separazione selettiva di idrogeno solforato da miscele gassose contenenti anche anidride carbonica |
US4539189A (en) * | 1984-01-23 | 1985-09-03 | Chevron Research Company | Method for removing sulfides from industrial gas |
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1986
- 1986-03-13 EP EP86902174A patent/EP0215911A1/de not_active Withdrawn
- 1986-03-13 WO PCT/US1986/000527 patent/WO1986005474A1/en unknown
Non-Patent Citations (1)
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US11383197B2 (en) | 2018-02-14 | 2022-07-12 | Taminco Bvba | Contaminant removal process |
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WO1986005474A1 (en) | 1986-09-25 |
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