CN117463121A - Efficient absorbent for capturing carbon dioxide after combustion of natural gas power plant and application thereof - Google Patents
Efficient absorbent for capturing carbon dioxide after combustion of natural gas power plant and application thereof Download PDFInfo
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- CN117463121A CN117463121A CN202311441214.8A CN202311441214A CN117463121A CN 117463121 A CN117463121 A CN 117463121A CN 202311441214 A CN202311441214 A CN 202311441214A CN 117463121 A CN117463121 A CN 117463121A
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- carbon dioxide
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- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 title claims abstract description 88
- 230000002745 absorbent Effects 0.000 title claims abstract description 63
- 239000002250 absorbent Substances 0.000 title claims abstract description 63
- 229910002092 carbon dioxide Inorganic materials 0.000 title claims abstract description 44
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 40
- 239000001569 carbon dioxide Substances 0.000 title claims abstract description 24
- 239000003345 natural gas Substances 0.000 title claims abstract description 20
- 238000002485 combustion reaction Methods 0.000 title claims abstract description 19
- 238000010521 absorption reaction Methods 0.000 claims abstract description 42
- 239000007788 liquid Substances 0.000 claims abstract description 20
- 239000007789 gas Substances 0.000 claims abstract description 17
- 239000003963 antioxidant agent Substances 0.000 claims abstract description 11
- 230000003078 antioxidant effect Effects 0.000 claims abstract description 11
- 238000005260 corrosion Methods 0.000 claims abstract description 10
- 230000007797 corrosion Effects 0.000 claims abstract description 10
- 238000003795 desorption Methods 0.000 claims abstract description 7
- 239000003112 inhibitor Substances 0.000 claims abstract description 7
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 7
- 230000003213 activating effect Effects 0.000 claims abstract description 5
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 5
- 230000008929 regeneration Effects 0.000 claims description 16
- 238000011069 regeneration method Methods 0.000 claims description 16
- 239000003546 flue gas Substances 0.000 claims description 15
- 238000006243 chemical reaction Methods 0.000 claims description 13
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 claims description 12
- 239000006096 absorbing agent Substances 0.000 claims description 12
- 230000007246 mechanism Effects 0.000 claims description 8
- 150000001412 amines Chemical class 0.000 claims description 6
- PVXVWWANJIWJOO-UHFFFAOYSA-N 1-(1,3-benzodioxol-5-yl)-N-ethylpropan-2-amine Chemical compound CCNC(C)CC1=CC=C2OCOC2=C1 PVXVWWANJIWJOO-UHFFFAOYSA-N 0.000 claims description 3
- BFSVOASYOCHEOV-UHFFFAOYSA-N 2-diethylaminoethanol Chemical compound CCN(CC)CCO BFSVOASYOCHEOV-UHFFFAOYSA-N 0.000 claims description 3
- HXMVNCMPQGPRLN-UHFFFAOYSA-N 2-hydroxyputrescine Chemical compound NCCC(O)CN HXMVNCMPQGPRLN-UHFFFAOYSA-N 0.000 claims description 3
- PQUCIEFHOVEZAU-UHFFFAOYSA-N Diammonium sulfite Chemical compound [NH4+].[NH4+].[O-]S([O-])=O PQUCIEFHOVEZAU-UHFFFAOYSA-N 0.000 claims description 3
- QMMZSJPSPRTHGB-UHFFFAOYSA-N MDEA Natural products CC(C)CCCCC=CCC=CC(O)=O QMMZSJPSPRTHGB-UHFFFAOYSA-N 0.000 claims description 3
- 239000012190 activator Substances 0.000 claims description 3
- PTYMQUSHTAONGW-UHFFFAOYSA-N carbonic acid;hydrazine Chemical compound NN.OC(O)=O PTYMQUSHTAONGW-UHFFFAOYSA-N 0.000 claims description 3
- AZQZJVVZBGCHSV-UHFFFAOYSA-N 2-(3,5-dimethylpyrazol-1-yl)-n-[2-(3,5-dimethylpyrazol-1-yl)ethyl]ethanamine Chemical compound N1=C(C)C=C(C)N1CCNCCN1C(C)=CC(C)=N1 AZQZJVVZBGCHSV-UHFFFAOYSA-N 0.000 claims description 2
- IOAOAKDONABGPZ-UHFFFAOYSA-N 2-amino-2-ethylpropane-1,3-diol Chemical compound CCC(N)(CO)CO IOAOAKDONABGPZ-UHFFFAOYSA-N 0.000 claims description 2
- UXFQFBNBSPQBJW-UHFFFAOYSA-N 2-amino-2-methylpropane-1,3-diol Chemical compound OCC(N)(C)CO UXFQFBNBSPQBJW-UHFFFAOYSA-N 0.000 claims description 2
- 101150035093 AMPD gene Proteins 0.000 claims description 2
- 102100033830 Amphiphysin Human genes 0.000 claims description 2
- RPNUMPOLZDHAAY-UHFFFAOYSA-N Diethylenetriamine Chemical compound NCCNCCN RPNUMPOLZDHAAY-UHFFFAOYSA-N 0.000 claims description 2
- 101000779845 Homo sapiens Amphiphysin Proteins 0.000 claims description 2
- UDMBCSSLTHHNCD-KQYNXXCUSA-N adenosine 5'-monophosphate Chemical compound C1=NC=2C(N)=NC=NC=2N1[C@@H]1O[C@H](COP(O)(O)=O)[C@@H](O)[C@H]1O UDMBCSSLTHHNCD-KQYNXXCUSA-N 0.000 claims description 2
- 235000015393 sodium molybdate Nutrition 0.000 claims description 2
- 239000011684 sodium molybdate Substances 0.000 claims description 2
- TVXXNOYZHKPKGW-UHFFFAOYSA-N sodium molybdate (anhydrous) Chemical compound [Na+].[Na+].[O-][Mo]([O-])(=O)=O TVXXNOYZHKPKGW-UHFFFAOYSA-N 0.000 claims description 2
- XMVONEAAOPAGAO-UHFFFAOYSA-N sodium tungstate Chemical compound [Na+].[Na+].[O-][W]([O-])(=O)=O XMVONEAAOPAGAO-UHFFFAOYSA-N 0.000 claims description 2
- 238000005406 washing Methods 0.000 claims description 2
- 238000000034 method Methods 0.000 abstract description 14
- 238000005265 energy consumption Methods 0.000 abstract description 12
- 230000008569 process Effects 0.000 abstract description 12
- 229910052799 carbon Inorganic materials 0.000 abstract description 8
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 abstract description 7
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 abstract description 4
- 238000000354 decomposition reaction Methods 0.000 abstract description 4
- 239000001301 oxygen Substances 0.000 abstract description 4
- 229910052760 oxygen Inorganic materials 0.000 abstract description 4
- 238000002360 preparation method Methods 0.000 abstract description 3
- 238000011084 recovery Methods 0.000 abstract description 3
- 239000002918 waste heat Substances 0.000 abstract description 3
- 230000007774 longterm Effects 0.000 abstract description 2
- 238000009472 formulation Methods 0.000 description 6
- 239000000203 mixture Substances 0.000 description 6
- 230000000052 comparative effect Effects 0.000 description 5
- 150000003512 tertiary amines Chemical class 0.000 description 5
- 150000003335 secondary amines Chemical class 0.000 description 4
- 238000012360 testing method Methods 0.000 description 4
- 238000005516 engineering process Methods 0.000 description 3
- 150000003141 primary amines Chemical class 0.000 description 3
- 239000000126 substance Substances 0.000 description 3
- BVKZGUZCCUSVTD-UHFFFAOYSA-M Bicarbonate Chemical compound OC([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-M 0.000 description 2
- KXDHJXZQYSOELW-UHFFFAOYSA-M Carbamate Chemical compound NC([O-])=O KXDHJXZQYSOELW-UHFFFAOYSA-M 0.000 description 2
- 125000003277 amino group Chemical group 0.000 description 2
- 238000001816 cooling Methods 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 125000004435 hydrogen atom Chemical group [H]* 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 1
- 235000008733 Citrus aurantifolia Nutrition 0.000 description 1
- 235000011941 Tilia x europaea Nutrition 0.000 description 1
- 238000007792 addition Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 150000004657 carbamic acid derivatives Chemical class 0.000 description 1
- 125000004432 carbon atom Chemical group C* 0.000 description 1
- JYYOBHFYCIDXHH-UHFFFAOYSA-N carbonic acid;hydrate Chemical compound O.OC(O)=O JYYOBHFYCIDXHH-UHFFFAOYSA-N 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 239000000571 coke Substances 0.000 description 1
- 230000010485 coping Effects 0.000 description 1
- 238000002425 crystallisation Methods 0.000 description 1
- 230000008025 crystallization Effects 0.000 description 1
- 125000004122 cyclic group Chemical group 0.000 description 1
- 239000000428 dust Substances 0.000 description 1
- 230000002708 enhancing effect Effects 0.000 description 1
- 235000013305 food Nutrition 0.000 description 1
- 239000002440 industrial waste Substances 0.000 description 1
- 239000004571 lime Substances 0.000 description 1
- 239000002075 main ingredient Substances 0.000 description 1
- 125000002496 methyl group Chemical group [H]C([H])([H])* 0.000 description 1
- 238000002156 mixing Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 125000004433 nitrogen atom Chemical group N* 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 230000009919 sequestration Effects 0.000 description 1
- 239000000779 smoke Substances 0.000 description 1
- 239000002904 solvent Substances 0.000 description 1
- 125000001424 substituent group Chemical group 0.000 description 1
- 239000002351 wastewater Substances 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
- B01D53/1493—Selection of liquid materials for use as absorbents
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/14—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
- B01D53/1418—Recovery of products
-
- 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
- B01D53/1425—Regeneration of liquid absorbents
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/14—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
- B01D53/1475—Removing carbon dioxide
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
- B01D2252/20—Organic absorbents
- B01D2252/204—Amines
-
- 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)
- Treating Waste Gases (AREA)
- Gas Separation By Absorption (AREA)
Abstract
The invention belongs to the technical field of absorbent preparation and application thereof, and particularly relates to a high-efficiency absorbent for capturing carbon dioxide after combustion of a natural gas power plant and application thereof. The absorbent comprises the following components in percentage by mass: 10-40% of main absorbent, 3-15% of auxiliary absorbent, 3-15% of activating agent, 0.5-1.5% of antioxidant, 0.5-1.5% of corrosion inhibitor and 50-70% of water. The application process of the absorbent is that a rich liquid reinjection process and a regenerated gas waste heat recovery process are added on the basis of a carbon capturing process, so that the absorption efficiency of the absorbent is improved, and the desorption energy consumption is reduced. In order to ensure the stability of the absorbent in long-term operation, reduce the decomposition of the main absorbent and the auxiliary absorbent in the oxygen-enriched operation environment, reduce the corrosion of the decomposition products to equipment, and add an antioxidant into the absorbent. The absorbent is ensured to have good absorption efficiency of 85% -92% in a low CO2 environment, and can stably operate for more than 2 years in an oxygen-enriched environment, and the annual average performance decay rate is less than or equal to 2%.
Description
Technical Field
The invention belongs to the technical field of absorbents and application thereof, and particularly relates to a high-efficiency absorbent for capturing carbon dioxide after combustion of a natural gas power plant and application thereof.
Background
The adoption of a large-scale zero-carbon or carbon-negative technology to reduce the carbon emission of thermal power enterprises is an important measure for coping with climate change. Among the numerous carbon emission reduction technologies, the post-combustion carbon capture process based on the chemical absorption method is the technology with the most mature technical conditions and closest realization of large-scale commercial operation at present. The technical principle is that CO2 is separated from industrial waste gas by utilizing an alkaline absorbent under the low temperature condition, and the solution after CO2 absorption is desorbed under the high temperature condition; the desorbed solution can absorb CO2 again after cooling, the high-concentration CO2 generated by desorption is further cooled, purified and dehydrated to prepare CO2 with different purities such as industrial grade, food grade and the like for other industries, or geological sequestration is carried out after pressurization treatment.
In the prior art, single amine absorbent has advantages and disadvantages, and cannot fully meet the requirements of industrial application. Primary amine and secondary amine such as MEA, DEA and the like have high absorption rate and reasonable price, but have larger corrosiveness to equipment, and the solvent is easy to degrade and volatilize, so that the regeneration energy consumption is large. Tertiary amines such as MDEA, DEAE, etc. have low regeneration energy consumption and high chemical stability, but slow absorption rate. Hindered amines such as AMP have two methyl branches on adjacent carbon atoms of the amino group, so that the carbamate formed after CO2 absorption has low stability and is easily decomposed to form bicarbonate or carbonate. Thus by adjusting the proportions and formulation of the components, a higher rate of absorption of CO2, better selectivity, and faster desorption rate, lower energy consumption can be achieved.
Disclosure of Invention
The invention aims to provide a preparation method and application of a high-efficiency absorbent for capturing carbon dioxide after combustion in a natural gas power plant.
The invention aims to solve the technical problems: the performance of a single amine absorbent and the basic carbon capture process cannot fully meet the requirements of a carbon dioxide capture system on capture efficiency and energy consumption.
The aim of the invention can be achieved by the following technical scheme:
the preparation and application of the efficient absorbent for capturing carbon dioxide after combustion of a natural gas power plant are provided, wherein the absorbent comprises the following components in percentage by mass: 10-40% of main absorbent, 3-15% of auxiliary absorbent, 3-15% of activating agent, 0.5-1.5% of antioxidant, 0.5-1.5% of corrosion inhibitor and 50-70% of water.
The primary absorbent component includes one or both of AMP, BDEA, DEAE and AMPD.
The secondary absorbent component includes one or two of MDEA, AEPD, and AEEA.
The activator component comprises one or both of MEA, DETA and PZ.
The carbon dioxide trapping process flow is shown in figure 1, and a rich liquid reinjection process and a regeneration gas waste heat recovery process are added on the basis of the carbon trapping process.
The rich liquid reinjection process is to reinject part of rich liquid in the absorption tower to a lean liquid inlet pipeline of the absorption tower.
The regeneration gas waste heat recovery process refers to heat exchange between a part of rich liquid of the absorption tower and regeneration gas through a heat exchanger and then heat exchange between the part of rich liquid and lean liquid through a lean-rich liquid heat exchanger.
Further, the tertiary amine absorbent in the main absorbent component has large absorption capacity, low regeneration energy consumption and low corrosion to equipment. Tertiary amines have no active hydrogen atoms, are more stable in chemical properties, and are not easily degraded and oxidized during operation. Because tertiary amines have no active hydrogen atoms, they cannot react directly with CO2 to form carbamates, but can promote the reaction of CO2 with water to form bicarbonate. The reaction mechanism is as follows:
CO 2 +H 2 O＝H + +HCO 3 -
RR’R”N+H + ＝RR’R”NH + 。
further, in the main absorber component, the AMP molecule has a substituent on the alpha carbon adjacent to the nitrogen atom, which has a steric hindrance effect, so that AMP has a relatively high reaction rate similar to that of primary amine and secondary amine, and a relatively high absorption capacity similar to that of tertiary amine. The reaction mechanism is as follows:
CO 2 +2AMP＝AMPCOO - +AMPH +
AMPCOO - +H 2 O＝AMP+HCO 3 - 。
further, in the main absorbent component, primary amine and secondary amine absorbent react with CO2 to generate carbamate, the reaction rate is high, and the reaction mechanism is as follows:
CO 2 +RR’NH＝RR’NH + COO -
RR’NH + COO - +RR’NHRR’NH + +RR’NCOO - 。
further, PZ belongs to secondary amine, has two amino groups, has large theoretical CO2 absorption capacity and low absorption rich liquid desorption difficulty, but its cyclic structure can cause viscosity increase and crystallization easily when PZ concentration is high, which limits the application of high concentration PZ. Therefore, a low concentration of PZ is generally selected for mixing with other amines as an activator for the absorption process, enhancing the absorption efficiency of the mixed amine absorbent. The reaction mechanism is as follows:
CO 2 +PZ+B＝PZCOO - +B +
CO 2 +PZCOO - +B＝PZ(COO - ) 2 +B +
wherein the base B can be PZ or PZCOO - 、PZH + 、H 2 O and OH - 。
pZ and CO 2 The reaction generates unstable intermediate acid-base complex PZ (COO) 2 ，PZ(COO) 2 CO2 is transferred in the carbonic acid water solution, and the catalyst-like effect is achieved, so that the reaction rate of the mixed absorbent for absorbing CO2 is accelerated.
The antioxidant comprises one or two of hydrazine carbonate and ammonium sulfite; the corrosion inhibitor comprises one or two of sodium molybdate and sodium tungstate.
Further, the carbon dioxide capture process comprises the steps of:
cooling the flue gas from the flue by a washing tower, then entering the lower part of an absorption tower, and countercurrent contacting the flue gas with the lean absorbent liquid entering from the upper part of the absorption tower in the absorption tower, wherein CO in the flue gas 2 Reacts with the absorbent to be absorbed. CO absorption 2 Part of the rich liquid directly enters a lean-rich liquid heat exchanger, exchanges heat with lean liquid from a regeneration tower and then enters the regeneration tower for desorption; part of the solution is reinjected into a lean solution inlet pipeline of the absorption tower and is sent into the upper part of the absorption tower together with the desorbed lean solution to re-absorb CO 2 The method comprises the steps of carrying out a first treatment on the surface of the Part of regenerated gas CO desorbed from the heat exchanger and the regeneration tower 2 And after heat exchange, the waste water enters a lean-rich liquid heat exchanger.
Further, the flue gas flow is 1500-3000 NM 3 /h; the temperature of the flue gas at the inlet of the absorption tower is 32-46 ℃; the circulation flow of the absorbent is 4-6 m 3 /h; the operation pressure of the regeneration tower is 5-50 kPa; the pressure of steam in the reboiler is 0.3-0.5 MPa, the temperature of steam is 135-155 ℃, and the flow rate of steam is 200-400 kg/h.
The invention has the beneficial effects that:
1. according to the technical scheme, the stability of the absorbent in long-term operation is guaranteed, the decomposition of the main absorbent and the auxiliary absorbent in an oxygen-enriched operation environment is reduced, the corrosion of decomposition products to equipment is reduced, and an antioxidant is added into the absorbent, wherein the antioxidant comprises one or more of hydrazine carbonate and ammonium sulfite, and the mass content of the antioxidant is 0.5% -1.5%.
2. In the technical scheme of the invention, the absorbent is ensured to have good absorption efficiency of 85% -92% in a low CO2 environment, and can stably run for more than 2 years in an oxygen-enriched environment, the annual average performance decay rate is less than or equal to 2% (calculated by absorption efficiency), and in addition, the absorbent is also suitable for capturing carbon dioxide of industrial flue gases such as flue gases of coal-fired power plants, natural gas treatment, lime kiln flue gases, blast furnace gas, coke oven gas and the like.
Drawings
FIG. 1 is a flow chart of a carbon dioxide capture process.
Detailed Description
The technical solutions of the embodiments of the present invention will be clearly and completely described below in conjunction with the embodiments of the present invention, and it is apparent that the described embodiments are only some embodiments of the present invention, not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
Example 1
An efficient absorbent for capturing carbon dioxide after combustion of a natural gas power plant comprises the following components in percentage by mass: 20% of main absorbent, 5% of auxiliary absorbent, 4% of activating agent, 0.5% of antioxidant, 0.5% of corrosion inhibitor and 70% of water.
Example 2
An efficient absorbent for capturing carbon dioxide after combustion of a natural gas power plant comprises the following components in percentage by mass: 30% of main absorbent, 5% of auxiliary absorbent, 4% of activating agent, 0.5% of antioxidant, 0.5% of corrosion inhibitor and 60% of water.
Carbon dioxide capturing engineering of a certain natural gas power plant in Beijing city, and the flue gas parameters are as follows:
| project | Numerical value |
| Density of flue gas kg/Nm 3 | 1.253 |
| Flue gas temperature DEG C | 79 |
| Flue gas pressure kPa | 101.33 |
| Flue gas flow velocity m/s | 23.1 |
| Mass flow of flue gas kg/s | 708.3 |
The smoke comprises the following components:
| project | Numerical value |
| Ar％ | 0.89 |
| CO 2 ％ | 4.6 |
| H 2 O％ | 8.23 |
| N 2 ％ | 74.71 |
| O 2 ％ | 11.96 |
| NOx mg/Nm 3 | 24.6 |
| SO 2 mg/Nm 3 | 0.53 |
| Dust mg/Nm 3 | 0 |
Example 3
The gas inlet amount of the trapping system is 2700Nm3/h, the CO2 content is 4.4%, the gas temperature at the inlet of the absorption tower is 40 ℃, the circulating flow of the absorbent is 5.0m3/h, the pressure of the regeneration tower is 7kPa, and the reheat steam parameter is 0.4MPa (g); 145 ℃;350kg/h; absorption tests were carried out using the absorbent formulation according to example 1, CO 2 The trapping rate of the trapping system is 85.90%, and CO 2 The trapping energy consumption is 3.84GJ/tCO 2 。
Example 4
The gas inlet amount of the trapping system is 2500Nm3/h, the CO2 content is 4.6%, the gas temperature at the inlet of the absorption tower is 37.8 ℃, the circulating flow of the absorbent is 5.8m3/h, the pressure of the regeneration tower is 9kPa, and the reheat steam parameter is 0.4MPa (g); 145 ℃;350kg/h; use of the absorbent of example 2The formulation was subjected to absorption testing, CO 2 The trapping rate of the trapping system is 90.90 percent, and CO 2 The energy consumption for trapping is 3.85GJ/tCO 2 。
Comparative example 1
The gas inlet amount of the trapping system is 2500Nm3/h, the CO2 content is 4.6%, the gas temperature at the inlet of the absorption tower is 37.8 ℃, the circulating flow of the absorbent is 5.8m3/h, the pressure of the regeneration tower is 9kPa, and the reheat steam parameter is 0.4MPa (g); 145 ℃;350kg/h; absorption test using an absorbent formulation containing AMP as the main ingredient, CO 2 The trapping rate of the trapping system is 86.50 percent, and CO 2 The energy consumption for trapping is 3.90GJ/tCO 2 。
Comparative example 2
The gas inlet amount of the trapping system is 2500Nm3/h, the CO2 content is 4.6%, the gas temperature at the inlet of the absorption tower is 37.8 ℃, the circulating flow of the absorbent is 5.8m3/h, the pressure of the regeneration tower is 9kPa, and the reheat steam parameter is 0.4MPa (g); 145 ℃; absorption test using an absorbent formulation based on AEEA, CO 2 The trapping rate of the trapping system is 91.71 percent, and CO 2 The energy consumption for trapping is 3.69GJ/tCO 2 。
As can be seen from examples 3-4 and comparative examples 1-2, the COs of examples 3-4 2 The trapping rate of the trapping system is lower than that of comparative examples 1-2, CO 2 The capture energy consumption was higher than that of comparative examples 1-2, demonstrating that by adjusting the proportions and formulation of the components, higher absorption rates, better selectivity, and faster desorption rates, lower energy consumption of CO2 can be achieved.
In the description of the present specification, the descriptions of the terms "one embodiment," "example," "specific example," and the like, mean that a particular feature, structure, material, or characteristic described in connection with the embodiment or example is included in at least one embodiment or example of the present invention. In this specification, schematic representations of the above terms do not necessarily refer to the same embodiments or examples. Furthermore, the particular features, structures, materials, or characteristics described may be combined in any suitable manner in any one or more embodiments or examples.
The foregoing is merely illustrative and explanatory of the invention, as various modifications and additions may be made to the particular embodiments described, or in a similar manner, by those skilled in the art, without departing from the scope of the invention or exceeding the scope of the invention as defined in the claims.
Claims (10)
1. The efficient absorbent for capturing carbon dioxide after combustion of the natural gas power plant is characterized by comprising the following components in percentage by mass: 10-40% of main absorbent, 3-15% of auxiliary absorbent, 3-15% of activating agent, 0.5-1.5% of antioxidant, 0.5-1.5% of corrosion inhibitor and 50-70% of water.
2. A high efficiency absorbent for post-combustion carbon dioxide capture in a natural gas power plant as defined in claim 1, wherein the primary absorbent component comprises one or both of AMP, BDEA, DEAE and AMPD.
3. A high efficiency absorber for post-combustion carbon dioxide capture in a natural gas power plant according to claim 1, wherein the secondary absorber component comprises one or both of MDEA, AEPD and AEEA.
4. A high efficiency absorbent for post-combustion carbon dioxide capture in a natural gas power plant as defined in claim 1, wherein the activator component comprises one or both of MEA, DETA and PZ.
5. A high efficiency absorber for post-combustion carbon dioxide capture in a natural gas power plant according to claim 2, wherein the reaction mechanism in the main absorber component is:
CO 2 +H 2 O＝H + +HCO 3 -
RR’R”N+H + ＝RR’R”NH + 。
6. a high efficiency absorber for post-combustion carbon dioxide capture in a natural gas power plant according to claim 2, wherein the reaction mechanism in the main absorber component is:
CO 2 +2AMP＝AMPCOO - +AMPH +
AMPCOO - +H 2 O＝AMP+HCO 3 - 。
7. a high efficiency absorber for post-combustion carbon dioxide capture in a natural gas power plant according to claim 2, wherein the reaction mechanism in the main absorber component is:
CO 2 +RR’NH＝RR’NH + COO -
RR’NH + COO - +RR’NHRR’NH + +RR’NCOO - 。
8. a high efficiency absorber for post-combustion carbon dioxide capture in a natural gas power plant according to claim 4, wherein the PZ reaction mechanism is:
CO 2 +PZ+B＝PZCOO - +B +
CO 2 +PZCOO - +B＝PZ(COO - ) 2 +B +
wherein the base B is PZ, PZCOO - 、PZH + 、H 2 O and OH - One or more of the following.
9. A high efficiency absorbent for post-combustion carbon dioxide capture in a natural gas power plant according to claim 1, wherein the antioxidant comprises one or both of hydrazine carbonate, ammonium sulfite; the corrosion inhibitor comprises one or two of sodium molybdate and sodium tungstate.
10. A high efficiency absorber for post-combustion carbon dioxide capture in a natural gas power plant according to claim 1, wherein the application within the absorber tower comprises the steps of:
the flue gas from the flue is cooled to 40 ℃ by a water washing tower and then enters the lower part of an absorption tower, and enters the absorption tower from the upper part of the absorption towerCountercurrent contact of ternary mixed amine solution and CO in gas 2 Reacts with the absorbent to be absorbed. CO absorption 2 The rich liquid enters a lean-rich liquid heat exchanger from the bottom of the absorption tower, exchanges heat with the lean liquid from the regeneration tower, enters the regeneration tower for desorption, and the desorbed lean liquid is sent to the upper part of the absorption tower for re-absorption of CO after the heat exchange temperature of the lean-rich liquid heat exchanger reaches the requirement 2 。
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