CN104069716A - Solvent for removing CO2 and sulfides in acidic airflow, and application thereof - Google Patents
Solvent for removing CO2 and sulfides in acidic airflow, and application thereof Download PDFInfo
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- CN104069716A CN104069716A CN201410333175.4A CN201410333175A CN104069716A CN 104069716 A CN104069716 A CN 104069716A CN 201410333175 A CN201410333175 A CN 201410333175A CN 104069716 A CN104069716 A CN 104069716A
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- solvent
- sulfide
- acid gas
- gas stream
- remove
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- 239000002904 solvent Substances 0.000 title claims abstract description 90
- 230000002378 acidificating effect Effects 0.000 title abstract description 6
- 150000003568 thioethers Chemical class 0.000 title abstract description 6
- MTHSVFCYNBDYFN-UHFFFAOYSA-N diethylene glycol Chemical compound OCCOCCO MTHSVFCYNBDYFN-UHFFFAOYSA-N 0.000 claims abstract description 21
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 claims abstract description 20
- CRVGTESFCCXCTH-UHFFFAOYSA-N methyl diethanolamine Chemical compound OCCN(C)CCO CRVGTESFCCXCTH-UHFFFAOYSA-N 0.000 claims abstract description 18
- HXJUTPCZVOIRIF-UHFFFAOYSA-N sulfolane Chemical compound O=S1(=O)CCCC1 HXJUTPCZVOIRIF-UHFFFAOYSA-N 0.000 claims abstract description 18
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 13
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 6
- 239000002253 acid Substances 0.000 claims description 46
- UCKMPCXJQFINFW-UHFFFAOYSA-N Sulphide Chemical compound [S-2] UCKMPCXJQFINFW-UHFFFAOYSA-N 0.000 claims description 41
- 239000012535 impurity Substances 0.000 claims description 11
- 230000008929 regeneration Effects 0.000 claims description 9
- 238000011069 regeneration method Methods 0.000 claims description 9
- 239000012190 activator Substances 0.000 claims description 7
- 239000000654 additive Substances 0.000 claims description 6
- 230000000996 additive effect Effects 0.000 claims description 6
- 238000007701 flash-distillation Methods 0.000 claims description 5
- 102000018779 Replication Protein C Human genes 0.000 claims description 4
- 108010027647 Replication Protein C Proteins 0.000 claims description 4
- 238000005260 corrosion Methods 0.000 claims description 2
- 230000007797 corrosion Effects 0.000 claims description 2
- 239000013530 defoamer Substances 0.000 claims description 2
- 239000003112 inhibitor Substances 0.000 claims description 2
- 238000000034 method Methods 0.000 abstract description 16
- -1 amine compound Chemical class 0.000 abstract description 7
- 230000008901 benefit Effects 0.000 abstract description 5
- 239000000126 substance Substances 0.000 abstract description 5
- 230000002745 absorbent Effects 0.000 abstract description 4
- 239000002250 absorbent Substances 0.000 abstract description 4
- 230000000694 effects Effects 0.000 abstract description 3
- 230000003213 activating effect Effects 0.000 abstract 3
- 125000004122 cyclic group Chemical group 0.000 abstract 1
- 238000006477 desulfuration reaction Methods 0.000 abstract 1
- 230000023556 desulfurization Effects 0.000 abstract 1
- 239000007789 gas Substances 0.000 description 74
- 238000010521 absorption reaction Methods 0.000 description 9
- 239000007788 liquid Substances 0.000 description 7
- 239000000203 mixture Substances 0.000 description 6
- 239000000243 solution Substances 0.000 description 6
- 150000001412 amines Chemical class 0.000 description 5
- 125000001741 organic sulfur group Chemical group 0.000 description 5
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
- 239000003960 organic solvent Substances 0.000 description 4
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 description 3
- LVTYICIALWPMFW-UHFFFAOYSA-N diisopropanolamine Chemical compound CC(O)CNCC(C)O LVTYICIALWPMFW-UHFFFAOYSA-N 0.000 description 3
- 229940043276 diisopropanolamine Drugs 0.000 description 3
- 238000002474 experimental method Methods 0.000 description 3
- 238000012545 processing Methods 0.000 description 3
- HZAXFHJVJLSVMW-UHFFFAOYSA-N 2-Aminoethan-1-ol Chemical compound NCCO HZAXFHJVJLSVMW-UHFFFAOYSA-N 0.000 description 2
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- LSDPWZHWYPCBBB-UHFFFAOYSA-N Methanethiol Chemical compound SC LSDPWZHWYPCBBB-UHFFFAOYSA-N 0.000 description 2
- SECXISVLQFMRJM-UHFFFAOYSA-N N-Methylpyrrolidone Chemical compound CN1CCCC1=O SECXISVLQFMRJM-UHFFFAOYSA-N 0.000 description 2
- GSEJCLTVZPLZKY-UHFFFAOYSA-N Triethanolamine Chemical compound OCCN(CCO)CCO GSEJCLTVZPLZKY-UHFFFAOYSA-N 0.000 description 2
- 239000007864 aqueous solution Substances 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 230000006837 decompression Effects 0.000 description 2
- ZBCBWPMODOFKDW-UHFFFAOYSA-N diethanolamine Chemical compound OCCNCCO ZBCBWPMODOFKDW-UHFFFAOYSA-N 0.000 description 2
- 229940043237 diethanolamine Drugs 0.000 description 2
- 239000003915 liquefied petroleum gas Substances 0.000 description 2
- 239000003345 natural gas Substances 0.000 description 2
- 238000012805 post-processing Methods 0.000 description 2
- 229910001220 stainless steel Inorganic materials 0.000 description 2
- 239000010935 stainless steel Substances 0.000 description 2
- 238000003786 synthesis reaction Methods 0.000 description 2
- 239000004372 Polyvinyl alcohol Substances 0.000 description 1
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 1
- 150000001408 amides Chemical class 0.000 description 1
- 229910002092 carbon dioxide Inorganic materials 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- 239000013043 chemical agent Substances 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- 238000005261 decarburization Methods 0.000 description 1
- 150000001983 dialkylethers Chemical class 0.000 description 1
- PCHPORCSPXIHLZ-UHFFFAOYSA-N diphenhydramine hydrochloride Chemical group [Cl-].C=1C=CC=CC=1C(OCC[NH+](C)C)C1=CC=CC=C1 PCHPORCSPXIHLZ-UHFFFAOYSA-N 0.000 description 1
- 239000003344 environmental pollutant Substances 0.000 description 1
- 239000004615 ingredient Substances 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 231100000719 pollutant Toxicity 0.000 description 1
- 229920002451 polyvinyl alcohol Polymers 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 238000000746 purification Methods 0.000 description 1
- 239000002994 raw material Substances 0.000 description 1
- 230000000630 rising effect Effects 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 229910052717 sulfur Inorganic materials 0.000 description 1
- 239000011593 sulfur Substances 0.000 description 1
Classifications
-
- 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
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A50/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE in human health protection, e.g. against extreme weather
- Y02A50/20—Air quality improvement or preservation, e.g. vehicle emission control or emission reduction by using catalytic converters
-
- 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
- Gas Separation By Absorption (AREA)
- Treating Waste Gases (AREA)
Abstract
The invention discloses a solvent for removing CO2 and sulfides in an acidic airflow, and application thereof, and aims to provide a solvent capable of removing CO2 and the sulfides in high removal rate. The solvent comprises the following components in percentage by weight: 20-60% of an amine compound, 1-10% of an activating agent, and the balance of water, wherein the activating agent comprises tetramethylene sulfone and diethylene glycol, and the amine compound is N-methyldiethanolamine. The solvent provided by the invention can remove CO2 and the sulfides from acidic gas, adopts the amine compound as a main absorbent, is supplemented with the activating agent consisting of tetramethylene sulfone and diethylene glycol, and can improve the removal rate of the CO2 and the sulfides through mutual synergy. Compared with a conventional desulfurization method, the solvent can effectively remove acidic substances such as H2S, CO2, COS and mercaptans, so that the treatment processes are reduced, and a higher economic value is provided. Meanwhile, the solvent further has the advantages of being renewable, low in cost and good in effect, can realize cyclic utilization, and has an important significance of reducing treatment cost of the acidic gas.
Description
Technical field
The present invention relates to gas purification field, especially the de-CO of gas
2and sulfide field, be specially a kind of CO that removes from acid gas stream
2and the solvent of sulfide and application thereof, this solvent can be used for the de-CO of the acid gas streams such as natural gas, synthesis gas, refinery gas, liquefied petroleum gas
2and sulfide.
Background technology
In industrial gasses, conventionally contain CO
2, H
2the objectionable impurities such as S and COS, various mercaptan, thioether, before further utilizing, must remove these carbon dioxide and sulfide impurities totally.Up to the present, the technology that is applied to gas sweetening decarburization is descended hundreds of, modal is that acid gas stream contacts in gas cleaning plant with organic solvent (or aqueous solution of organic solvent), by organic solvent (or aqueous solution of organic solvent) to the CO in gas
2, sulfide removes, and had lot of documents to carry out corresponding report.In general, for the de-CO of gas
2and the purifying solvent of sulfide mainly contains two kinds of physical solvent, chemical solvents.
Physical solvent mainly relies on Physical Absorption, and typical physical solvent has sulfolane and its derivative, straight chain acid amides, NMP(N-methyl pyrrolidone), the mixture of N-alkyl pyrrolidone, methyl alcohol and polyvinyl alcohol dialkyl ether.Chemical solvent is based on chemical reaction, makes sour gas generate the compound of easily removing, thereby reach, removes CO
2, sulfide object.For instance, industrial the most frequently used chemical agent is hydramine, because the salt generating easily decomposes or easily by steam stripping, therefore amine can recycle.From air-flow, removing the reasonable amine of acid ingredient mainly comprises: monoethanolamine (MEA), diethanol amine (DEA), triethanolamine (TEA), diisopropanolamine (DIPA) (DIPA), amido ethoxy ethanol (AEE), methyl diethanolamine (MDEA) and the MDEA that has added various activators.
For chemical field, how further to improve CO in acid gas stream
2and sulfide remove the degree of depth, be the focus that people study always.
Summary of the invention
Goal of the invention of the present invention is: for the problem of above-mentioned existence, provide a kind of CO that removes from acid gas stream
2and the solvent of sulfide and application thereof.Solvent of the present invention can be used in and from sour gas, removes CO
2, sulfide, it usings varies as main absorbent, is aided with the activator that sulfolane and diethylene glycol (DEG) form simultaneously, by the mutual coordinated between component, can effectively improve CO
2with sulfide removal efficiency.Compare energy deep removal H of the present invention with traditional sulfur method
2s, CO
2, the acidic materials such as COS, mercaptan, thereby reduced treatment process, thereby there is higher economic worth.Meanwhile, solvent of the present invention also has renewable, low cost and other advantages, significant for the processing cost that reduces sour gas.
To achieve these goals, the present invention adopts following technical scheme:
A kind of CO that removes from acid gas stream
2and the solvent of sulfide, comprise the component of following percentage by weight:
Varies 20～60%;
Activator 1～10%;
Water surplus;
Described activator is comprised of sulfolane and diethylene glycol (DEG);
Described varies is N methyldiethanol amine.
In described activator, the weight ratio of sulfolane and diethylene glycol (DEG) is 1:10 ~ 10:1.
The percentage by weight of described varies is 30～50%.
The percentage by weight of described N methyldiethanol amine is 35～45%.
Also comprise additive, described additive is one or more in corrosion inhibitor, defoamer, antisludging agent.
The component that comprises following percentage by weight:
Varies 20～60%;
Activator 1～10%;
Additive 0.01～5%;
Water surplus.
The aforementioned CO that removes from acid gas stream
2and the application of the solvent of sulfide, comprise the steps: solvent and acid gas stream counter current contacting, remove the CO in acid gas stream
2and sulfide.
The aforementioned CO that removes from acid gas stream
2and the application of the solvent of sulfide, comprise the steps: solvent to be divided into multiply, make solvent carry out repeatedly counter current contacting with acid gas stream from top to bottom, remove the CO in acid gas stream
2and sulfide.
The aforementioned CO that removes from acid gas stream
2and the application of the solvent of sulfide, comprise the steps:
(1) removal of impurities: by solvent and acid gas stream counter current contacting, remove the CO in acid gas stream
2and sulfide, respectively air-flow after removal of impurities and the solvent of rich sour gas;
(2) solvent reclamation: the solvent of rich sour gas is reduced pressure, and foreign gas is wherein overflowed, and obtains regenerated solvent, returns to regenerated solvent in step 1, to carry out removal of impurities.
In described step 2, first the solvent of rich sour gas is carried out to flash distillation, the regeneration of reducing pressure again of the solvent of the rich sour gas after flash distillation, obtains regenerated solvent, and regenerated solvent is returned and in step 1, carries out removal of impurities.
In described step 1, the solvent of rich sour gas adopts turbine mode to reclaim energy wherein.
The invention provides a kind of CO that removes from acid gas stream
2and the solvent of sulfide and application thereof.Solvent of the present invention can be used in and from sour gas, removes CO
2, sulfide (comprises H
2s and organic sulfur), can be used for the sour gas such as natural gas, synthesis gas, refinery gas, liquefied petroleum gas.By contacting of this solvent and air-flow, remove the CO in acid gas stream
2and sulfide.Solvent of the present invention is usingd varies as main absorbent, is aided with the activator that sulfolane and diethylene glycol (DEG) form simultaneously, by the mutual coordinated between component, can effectively improve CO
2with sulfide removal efficiency.By contrast experiment, can find out, adopt separately MDEA, or adopt MDEA+ sulfolane, or adopt MDEA+ diethylene glycol (DEG), this three's effect is far away from solvent of the present invention.This is owing to having good synergy between component of the present invention, by organic cooperation of component, has obtained the effect that is significantly better than conventional amine method.Contrast experiment in embodiment proves, more conventional amine method is compared, and adopts solvent of the present invention to have higher CO
2with sulfide removal efficiency, can effectively reduce postprocessing working procedures.For chemical field, the minimizing for the treatment of process, means the reduction of production cost, and the minimizing of consumption of raw materials, and this has also further reduced the possibility that pollutant produces, and has significant economic benefit and social benefit.
Meanwhile, solvent of the present invention is renewable and recycle, and has advantages of that use cost is low, little to ambient influnence, significant for the processing cost that reduces sour gas.The using method of solvent of the present invention is simple, can adopt the mode of counter current contacting, makes the CO in air-flow that is:
2with sulfide by contacting and be removed with solvent of the present invention.Absorption process can adopt once and absorb, and also can adopt repeatedly and carry out continuously, and the latter can use the solvent of multiply to carry out gas-liquid contact from the order reducing successively by temperature to tower top at the bottom of tower.
After solvent and acid gas stream counter current contacting, the CO in acid gas stream
2and sulfide is removed, obtain the gas after removal of impurities, solvent becomes the solvent of rich sour gas simultaneously.The solvent liquid of rich sour gas is realized regeneration by decompression, and it can be realized by choke valve.The energy containing in rich acid gas solvent can reclaim by turbine.Meanwhile, before decompression regeneration, also can adopt one or many flash distillation, remove acid gas.
Between component of the present invention, there is good synergy, CO
2and the removal efficiency of sulfide is significantly higher than conventional amine method, can effectively reduce postprocessing working procedures, significant for the treatment cycle and the processing cost that reduce sour gas.
The specific embodiment
Disclosed all features in this description, or the step in disclosed all methods or process, except mutually exclusive feature and/or step, all can combine by any way.
Disclosed arbitrary feature in this description, unless narration especially all can be replaced by other equivalences or the alternative features with similar object.That is,, unless narration especially, each feature is an example in a series of equivalences or similar characteristics.
Embodiment 1
Take respectively 44kg MDEA(N-methyl diethanolamine), 5kg sulfolane, 4kg diethylene glycol (DEG), 47kg water, mix, obtain solvent.
Embodiment 2
(1) prepare solvent
Take respectively 38kgMDEA(N-methyl diethanolamine), 6kg sulfolane, 3kg diethylene glycol (DEG), 53kg water, mix, obtain solvent.
(2) measure
Configuration unstripped gas, contains 5% CO in unstripped gas
2, 1% H
2s.The unstripped gas preparing enters absorption tower bottom, and the solution counter current contacting entering with tower top, and the acid gas in unstripped gas is absorbed, and purified gas from tower top out, enters gas-liquid separator and reclaims emptying after the drop of carrying secretly.
After measured, in purified gas, CO
2content is 47ppmv, H
2s content is 3ppmv, and organic sulfur removal rate is 82.9%.
Embodiment 3
(1) prepare solvent
Take respectively 30kgMDEA, 5kg sulfolane, 5kg diethylene glycol (DEG), 55kg water, mix, obtain solvent.
(2) measure
Configuration unstripped gas, contains 5% CO in unstripped gas
2, 1% H
2s.The unstripped gas preparing enters absorption tower bottom, and the solution counter current contacting entering with tower top, and the acid gas in unstripped gas is absorbed, and purified gas from tower top out, enters gas-liquid separator and reclaims emptying after the drop of carrying secretly.
After measured, in purified gas, CO
2content is 50ppmv, H
2s content is 3ppmv, and organic sulfur removal rate is 82.6%.
Embodiment 4
(1) prepare solvent
Take respectively 47kgMDEA, 3kg sulfolane, 2kg diethylene glycol (DEG), 48kg water, mix, obtain solvent.
(2) measure
Configuration unstripped gas, contains 5% CO in unstripped gas
2, 1% H
2s.The unstripped gas preparing enters absorption tower bottom, and the solution counter current contacting entering with tower top, and the acid gas in unstripped gas is absorbed, and purified gas from tower top out, enters gas-liquid separator and reclaims emptying after the drop of carrying secretly.
After measured, in purified gas, CO
2content is 45ppmv, H
2s content is 3ppmv, and organic sulfur removal rate is 83.50%.
Embodiment 5
(1) prepare solvent
Take respectively 55kgMDEA(N-methyl diethanolamine), 3kg sulfolane, 1kg diethylene glycol (DEG), 41kg water, mix, obtain solvent.
(2) measure
Configuration unstripped gas, contains 5% CO in unstripped gas
2, 1% H
2s.The unstripped gas preparing enters absorption tower bottom, and the solution counter current contacting entering with tower top, and the acid gas in unstripped gas is absorbed, and purified gas from tower top out, enters gas-liquid separator and reclaims emptying after the drop of carrying secretly.
After measured, in purified gas, CO
2content is 44ppmv, H
2s content is 3ppmv, and organic sulfur removal rate is 83.10%.
Contrast experiment
Operating characteristics to concrete absorbent on experimental rig is directly tested.The absorption tower internal diameter of test use is 40mm, in-built Φ 25 stainless steel rectangular saddle rings, and regenerator internal diameter 50mm, in-built Φ 25 stainless steel rectangular saddle rings, reboiler is equipped with in regenerator bottom.
The unstripped gas preparing (contains 5% CO in this unstripped gas
2, 1% H
2s) enter absorption tower bottom, and the solution counter current contacting entering with tower top, the acid gas in unstripped gas is absorbed, and purified gas from tower top out, enters gas-liquid separator and reclaims emptying after the drop of carrying secretly.
The rich acid gas solvent that has absorbed acid gas leads to regenerator top at the bottom of absorbing tower, and in regenerator, contacts with the steam counter-flow rising and obtain regeneration.The lean solution that regeneration obtains is sent into absorption tower jacking row and is absorbed after cooling.From regeneration overhead gas out, enter regeneration gas cooler, the steam in gas is reclaimed, regeneration gas is emptying after separation.
Under the certain prerequisite of unstripped gas, the operating characteristics of different lyosoption agent to be tested, test result is as shown in table 1.
The operating characteristics of the different lyosoptions of table 1
In table 1: MDEA50% refers to the MDEA that this solvent contains 50%wt, the water of 50%wt; MDEA47%+ sulfolane 5% refers to the sulfolane of MDEA, 5%wt and the water of 48%wt that this solvent contains 47%wt; MDEA47%+ diethylene glycol (DEG) 5% refers to the diethylene glycol (DEG) of MDEA, 5%wt and the water of 48%wt that this solvent contains 47%wt; MDEA44%+ sulfolane 5%+ diethylene glycol (DEG) 4% is the solvent of the embodiment of the present invention 1 preparation.The determination data of table 1 shows: solvent of the present invention is to CO
2there is obviously higher removal efficiency with sulfide.
The present invention is not limited to the aforesaid specific embodiment.The present invention expands to any new feature or any new combination disclosing in this manual, and the arbitrary new method disclosing or step or any new combination of process.
Claims (10)
1. from acid gas stream, remove CO for one kind
2and the solvent of sulfide, it is characterized in that, comprise the component of following percentage by weight:
Varies 20～60%;
Activator 1～10%;
Water surplus;
Described activator is comprised of sulfolane and diethylene glycol (DEG);
Described varies is N methyldiethanol amine.
2. from acid gas stream, remove according to claim 1 CO
2and the solvent of sulfide, it is characterized in that, in described activator, the weight ratio of sulfolane and diethylene glycol (DEG) is 1:10 ~ 10:1.
3. from acid gas stream, remove according to claim 1 CO
2and the solvent of sulfide, it is characterized in that, the percentage by weight of described varies is 30～50%.
4. described in claim 1-3 any one, from acid gas stream, remove CO
2and the solvent of sulfide, it is characterized in that, the percentage by weight of described N methyldiethanol amine is 35～45%.
5. described in claim 1-4 any one, from acid gas stream, remove CO
2and the solvent of sulfide, it is characterized in that, also comprise additive, described additive is one or more in corrosion inhibitor, defoamer, antisludging agent.
6. described in claim 1-5 any one, from acid gas stream, remove CO
2and the solvent of sulfide, it is characterized in that, comprise the component of following percentage by weight:
Varies 20～60%;
Activator 1～10%;
Additive 0.01～5%;
Water surplus.
7. described in claim 1-6 any one, from acid gas stream, remove CO
2and the application of the solvent of sulfide, it is characterized in that, comprise the steps: solvent and acid gas stream counter current contacting, remove the CO in acid gas stream
2and sulfide.
8. described in claim 1-6 any one, from acid gas stream, remove CO
2and the application of the solvent of sulfide, it is characterized in that, comprise the steps: solvent to be divided into multiply, make solvent carry out repeatedly counter current contacting with acid gas stream from top to bottom, remove the CO in acid gas stream
2and sulfide.
9. described in claim 1-6 any one, from acid gas stream, remove CO
2and the application of the solvent of sulfide, it is characterized in that, comprise the steps:
(1) removal of impurities: by solvent and acid gas stream counter current contacting, remove the CO in acid gas stream
2and sulfide, respectively air-flow after removal of impurities and the solvent of rich sour gas;
(2) solvent reclamation: the solvent of rich sour gas is reduced pressure, and foreign gas is wherein overflowed, and obtains regenerated solvent, returns to regenerated solvent in step 1, to carry out removal of impurities.
10. from acid gas stream, remove according to claim 9 CO
2and the application of the solvent of sulfide, it is characterized in that, in described step 2, first the solvent of rich sour gas is carried out to flash distillation, the regeneration of reducing pressure again of the solvent of the rich sour gas after flash distillation, obtains regenerated solvent, and regenerated solvent is returned and in step 1, carries out removal of impurities.
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| CN201410333175.4A CN104069716B (en) | 2014-07-14 | 2014-07-14 | Solvent for removing CO2 and sulfides in acidic airflow, and application thereof |
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Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN109420409A (en) * | 2017-08-22 | 2019-03-05 | 中国石油化工股份有限公司 | It is selectively removed from air-flow containing H2S and CO2Sour gas absorbent and method |
| WO2023125006A1 (en) * | 2021-12-27 | 2023-07-06 | 中国石油天然气股份有限公司 | Method and system for removing acid gas from ethylene cracking gas |
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| CN1615173A (en) * | 2002-01-14 | 2005-05-11 | 国际壳牌研究有限公司 | Process for removing carbon dioxide from gas mixtures |
| CN1546207A (en) * | 2003-12-09 | 2004-11-17 | 南化集团研究院 | Method for separating carbon dioxide dissolvent from gas mixture |
| CN101600488A (en) * | 2007-01-19 | 2009-12-09 | 道达尔公司 | Be used for the method that purifying contains the admixture of gas of sour gas |
| CN101062460A (en) * | 2007-06-07 | 2007-10-31 | 华东理工大学 | Method and device for removing hydrogen sulphide from mixture gas containing low-concentration hydrogen sulphide |
| WO2011121633A1 (en) * | 2010-03-29 | 2011-10-06 | 株式会社 東芝 | Acidic gas absorbent, acidic gas removal device, and acidic gas removal method |
| CN101822932A (en) * | 2010-06-12 | 2010-09-08 | 中国石油集团工程设计有限责任公司 | Composite decarbonization solvent for eliminating carbon dioxide in natural gases |
| CN102284229A (en) * | 2011-06-02 | 2011-12-21 | 大连理工大学 | Composite decarbonization solution for capturing carbon dioxide in mixed gas |
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| Publication number | Priority date | Publication date | Assignee | Title |
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| CN109420409A (en) * | 2017-08-22 | 2019-03-05 | 中国石油化工股份有限公司 | It is selectively removed from air-flow containing H2S and CO2Sour gas absorbent and method |
| CN109420409B (en) * | 2017-08-22 | 2021-08-06 | 中国石油化工股份有限公司 | Selective removal of H-containing compounds from gas streams2S and CO2And method for absorbing acid gas |
| WO2023125006A1 (en) * | 2021-12-27 | 2023-07-06 | 中国石油天然气股份有限公司 | Method and system for removing acid gas from ethylene cracking gas |
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