CN116059811A - Methane escape treatment method and treatment system - Google Patents
Methane escape treatment method and treatment system Download PDFInfo
- Publication number
- CN116059811A CN116059811A CN202211529164.4A CN202211529164A CN116059811A CN 116059811 A CN116059811 A CN 116059811A CN 202211529164 A CN202211529164 A CN 202211529164A CN 116059811 A CN116059811 A CN 116059811A
- Authority
- CN
- China
- Prior art keywords
- flue gas
- methane
- sulfur
- oxidation reactor
- catalytic oxidation
- 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.)
- Pending
Links
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 168
- 238000011282 treatment Methods 0.000 title claims abstract description 39
- 238000000034 method Methods 0.000 title claims abstract description 32
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 claims abstract description 84
- 239000003546 flue gas Substances 0.000 claims abstract description 84
- 230000003197 catalytic effect Effects 0.000 claims abstract description 56
- 238000006243 chemical reaction Methods 0.000 claims abstract description 53
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 claims abstract description 43
- 229910052717 sulfur Inorganic materials 0.000 claims abstract description 43
- 239000011593 sulfur Substances 0.000 claims abstract description 43
- 230000003009 desulfurizing effect Effects 0.000 claims abstract description 38
- 238000007254 oxidation reaction Methods 0.000 claims abstract description 36
- 230000003647 oxidation Effects 0.000 claims abstract description 35
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 33
- NUJOXMJBOLGQSY-UHFFFAOYSA-N manganese dioxide Chemical compound O=[Mn]=O NUJOXMJBOLGQSY-UHFFFAOYSA-N 0.000 claims abstract description 28
- 238000006477 desulfuration reaction Methods 0.000 claims abstract description 13
- 230000023556 desulfurization Effects 0.000 claims abstract description 13
- 238000010438 heat treatment Methods 0.000 claims description 29
- 238000012806 monitoring device Methods 0.000 claims description 19
- 239000007789 gas Substances 0.000 claims description 12
- 238000005067 remediation Methods 0.000 claims description 7
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Chemical compound O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 7
- 239000002245 particle Substances 0.000 claims description 5
- 238000003795 desorption Methods 0.000 claims 1
- 239000003054 catalyst Substances 0.000 abstract description 22
- 231100000572 poisoning Toxicity 0.000 abstract description 4
- 230000000607 poisoning effect Effects 0.000 abstract description 4
- 230000002035 prolonged effect Effects 0.000 abstract description 3
- 239000003949 liquefied natural gas Substances 0.000 description 12
- RAHZWNYVWXNFOC-UHFFFAOYSA-N Sulphur dioxide Chemical compound O=S=O RAHZWNYVWXNFOC-UHFFFAOYSA-N 0.000 description 10
- 230000000694 effects Effects 0.000 description 10
- 239000000446 fuel Substances 0.000 description 8
- KDLHZDBZIXYQEI-UHFFFAOYSA-N Palladium Chemical compound [Pd] KDLHZDBZIXYQEI-UHFFFAOYSA-N 0.000 description 6
- 238000005265 energy consumption Methods 0.000 description 6
- 238000006555 catalytic reaction Methods 0.000 description 4
- BASFCYQUMIYNBI-UHFFFAOYSA-N platinum Chemical compound [Pt] BASFCYQUMIYNBI-UHFFFAOYSA-N 0.000 description 4
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 description 3
- 229910052799 carbon Inorganic materials 0.000 description 3
- 238000005056 compaction Methods 0.000 description 3
- 229940099596 manganese sulfate Drugs 0.000 description 3
- 235000007079 manganese sulphate Nutrition 0.000 description 3
- 239000011702 manganese sulphate Substances 0.000 description 3
- SQQMAOCOWKFBNP-UHFFFAOYSA-L manganese(II) sulfate Chemical compound [Mn+2].[O-]S([O-])(=O)=O SQQMAOCOWKFBNP-UHFFFAOYSA-L 0.000 description 3
- 238000012544 monitoring process Methods 0.000 description 3
- 229910000510 noble metal Inorganic materials 0.000 description 3
- 229910052763 palladium Inorganic materials 0.000 description 3
- 230000008929 regeneration Effects 0.000 description 3
- 238000011069 regeneration method Methods 0.000 description 3
- 239000003344 environmental pollutant Substances 0.000 description 2
- 229910052697 platinum Inorganic materials 0.000 description 2
- 231100000719 pollutant Toxicity 0.000 description 2
- 238000001179 sorption measurement Methods 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 1
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000018109 developmental process Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000009792 diffusion process Methods 0.000 description 1
- 230000009977 dual effect Effects 0.000 description 1
- 239000005431 greenhouse gas Substances 0.000 description 1
- 230000005764 inhibitory process Effects 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 238000000691 measurement method Methods 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 238000000746 purification Methods 0.000 description 1
- 239000000376 reactant Substances 0.000 description 1
- 238000006479 redox reaction Methods 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 229910052815 sulfur oxide Inorganic materials 0.000 description 1
Images
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
- B01D53/46—Removing components of defined structure
- B01D53/48—Sulfur compounds
- B01D53/50—Sulfur oxides
- B01D53/508—Sulfur oxides by treating the gases with solids
-
- 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
- B01D53/81—Solid phase processes
- B01D53/82—Solid phase processes with stationary reactants
-
- 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
- B01D53/8668—Removing organic compounds not provided for in B01D53/8603 - B01D53/8665
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D2257/00—Components to be removed
- B01D2257/30—Sulfur compounds
- B01D2257/302—Sulfur oxides
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D2257/00—Components to be removed
- B01D2257/70—Organic compounds not provided for in groups B01D2257/00 - B01D2257/602
- B01D2257/702—Hydrocarbons
- B01D2257/7022—Aliphatic hydrocarbons
- B01D2257/7025—Methane
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D2258/00—Sources of waste gases
- B01D2258/02—Other waste gases
- B01D2258/0283—Flue gases
Landscapes
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- Environmental & Geological Engineering (AREA)
- Health & Medical Sciences (AREA)
- Biomedical Technology (AREA)
- Analytical Chemistry (AREA)
- General Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Exhaust Gas Treatment By Means Of Catalyst (AREA)
Abstract
The application discloses a methane escape treatment method and a treatment system. The treatment method comprises the following steps: desulfurizing the sulfur-containing flue gas through a reaction device, wherein a desulfurizing agent is filled in the reaction device, and the desulfurizing agent comprises manganese dioxide; the flue gas after desulfurization treatment is sent into a catalytic oxidation reactor, and methane is removed from the flue gas in the catalytic oxidation reactor. The treatment system comprises a reaction device, wherein the reaction device is used for removing sulfur in the sulfur-containing flue gas; the catalytic oxidation reactor is communicated with the air outlet of the reaction device and is used for removing methane in the flue gas. The sulfur-containing flue gas is subjected to desulfurization treatment, so that the purpose of preventing the poisoning of the methane catalyst is achieved, and the catalytic life of the methane catalyst is prolonged.
Description
Technical Field
The application belongs to the field of ship tail gas purification, and particularly relates to a methane escape treatment method and a treatment system.
Background
The use of low-carbon clean fuel as a ship power source has become a hot spot of current research, and LNG (liquefied natural gas), methanol, NH (liquefied natural gas) has been used in recent years 3 The representative new low carbon fuels have become an important trend in the development of marine engines. LNG (liquefied natural gas) is a clean fuel, which has great advantages in reducing emissions of atmospheric pollutants such as NOx, SOx and PM, but has obvious methane slip problems during the operation of common low-pressure injection LNG engines. Methane is a strong greenhouse gas with a greenhouse effect greater than that of CO 2 25 times stronger, despite the CO of the LNG powered dual fuel/gas engine 2 The emission is reduced by 20% compared with the traditional engine, but the contribution degree of the emission of the LNG power ship is reduced according to the contribution degree of the greenhouse effect, and the contribution degree of the emission of the LNG power ship to the greenhouse effect is higher than that of the traditional engine, so that along with popularization of the LNG power ship, the problem of methane escape is highly valued in society, and if the problem of methane escape in ship application cannot be effectively solved, the problem of methane escape becomes an important adverse factor for restricting further popularization and application of the dual-fuel/gas engine in the ship field.
The exhaust temperature of the marine dual-fuel/gas engine is only 200-400 ℃, and as the engine is developed towards higher average effective pressure and thermal efficiency, the exhaust temperature is further reduced, so that the difficulty of methane catalytic oxidation is increased, and the requirement for the noble metal dosage in the catalyst is also increased. In addition, sulfur in exhaust gas of the dual-fuel/gas engine has a strong inhibition effect on the catalytic process, and practical problems such as reduced service life of the catalyst, frequent replacement and the like can be caused.
The main active components of the methane catalyst are noble metals such as platinum and palladium, and the higher sulfur content can form species with low activity such as palladium sulfate, so that the activity of the noble metals is greatly inhibited, the methane catalytic oxidation efficiency is greatly reduced, and the methane catalyst is a key problem to be solved in the current marine methane escape management.
Disclosure of Invention
The application aims to provide a methane escape control method and a methane escape control treatment system. The application can solve the technical problems by desulfurizing the flue gas.
The embodiment of the application provides a methane escape treatment method, which comprises the following steps:
desulfurizing sulfur-containing flue gas through a reaction device, wherein a desulfurizing agent is filled in the reaction device, and the desulfurizing agent comprises manganese dioxide;
and sending the flue gas subjected to desulfurization treatment into a catalytic oxidation reactor, and removing methane from the flue gas in the catalytic oxidation reactor.
In some embodiments, the linear velocity of the sulfur-containing flue gas is less than or equal to 2m/s, and the airspeed of the sulfur-containing flue gas is less than or equal to 20000 hours -1 。
In some embodiments, the number of channels of the desulfurizing agent in the reaction apparatus is between 200 and 300cpsi.
In some embodiments, the catalytic atmosphere within the reaction device is: the catalytic temperature is 500-600 ℃, and the content of water vapor in the catalytic atmosphere is 10-15%.
In some embodiments, the SO in the sulfur-containing flue gas 2 The content is less than or equal to 10ppm.
In some embodiments, the manganese dioxide has a particle size of 200nm to 500nm.
In some embodiments, the desulfurizing agent is charged into the reaction apparatusThe amount is 80-85 g/dm 3 。
In some embodiments, the desulfurized flue gas is heated by a heating device and then fed to the catalytic oxidation reactor.
In some embodiments, the flue gas after being treated by the catalytic oxidation reactor is analyzed by a monitoring device, and the monitoring device judges whether the content of methane in the flue gas after being treated exceeds a critical value: when the content of methane in the treated flue gas exceeds a critical value, the monitoring device transmits a treatment signal to a controller, and the controller adjusts the heating temperature of the heating device so as to improve the temperature of the flue gas.
Accordingly, the present application further provides a treatment system used in the above-mentioned methane escape control method, including:
the reaction device is used for removing sulfur in the sulfur-containing flue gas;
the catalytic oxidation reactor is communicated with the air outlet of the reaction device and is used for removing methane in the flue gas.
The beneficial effects of this application lie in: the application provides a methane escape treatment method and a treatment system. The methane escape control method comprises the following steps: desulfurizing the sulfur-containing flue gas through a reaction device, wherein a desulfurizing agent is filled in the reaction device, and the desulfurizing agent comprises manganese dioxide; the flue gas after desulfurization treatment is sent into a catalytic oxidation reactor, and methane is removed from the flue gas in the catalytic oxidation reactor. The sulfur-containing flue gas is subjected to desulfurization treatment, so that the purpose of preventing the poisoning of the methane catalyst is achieved, and the catalytic life of the methane catalyst is prolonged.
Drawings
In order to more clearly illustrate the technical solutions of the embodiments of the present application, the drawings that are needed in the description of the embodiments will be briefly introduced below, it being obvious that the drawings in the following description are only some embodiments of the present application, and that other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art.
FIG. 1 is a schematic diagram of the structure of the methane slip treatment system of the present application;
FIG. 2 is a comparison of the effectiveness of the methane slip remediation process of the present application with prior art treatments;
in the figure, a 1-reaction device, a 2-catalytic oxidation reactor, a 3-heating device, a 4-monitoring device and a 5-controller.
Detailed Description
The following description of the embodiments of the present application will be made clearly and fully with reference to the accompanying drawings, in which it is evident that the embodiments described are only some, but not all, of the embodiments of the present application. All other embodiments, which can be made by those skilled in the art based on the embodiments herein without making any inventive effort, are intended to be within the scope of the present application. In addition, in the description of the present application, the term "comprising" means "including but not limited to". The terms first, second, third and the like are used merely as labels, and do not impose numerical requirements or on the order of construction. Various embodiments of the present application may exist in a range of forms; it should be understood that the description in a range format is merely for convenience and brevity and should not be construed as a rigid limitation on the scope of the application; it is therefore to be understood that the range description has specifically disclosed all possible sub-ranges and individual values within that range. For example, it should be considered that a description of a range from 1 to 6 has specifically disclosed sub-ranges, such as from 1 to 3, from 1 to 4, from 1 to 5, from 2 to 4, from 2 to 6, from 3 to 6, etc., as well as single numbers within the ranges, such as 1, 2, 3, 4, 5, and 6, wherever applicable. In addition, whenever a numerical range is referred to herein, it is meant to include any reference number (fractional or integer) within the indicated range.
In order to solve the influence of sulfur-containing flue gas on the activity of a methane catalyst, the application provides a methane escape treatment method, which comprises the following steps: desulfurizing the sulfur-containing flue gas by a reaction device 1, wherein the reaction device 1 is filled with a desulfurizing agent, and the desulfurizing agent comprises manganese dioxide; the flue gas after desulfurization treatment is sent into a catalytic oxidation reactor 2, and methane is removed from the flue gas in the catalytic oxidation reactor 2.
According to the methane escape treatment method, the manganese dioxide in the reaction device 1 is used for carrying out flue gas desulfurization reaction, and sulfur dioxide in the flue gas reacts with the manganese dioxide to generate manganese sulfate, so that sulfur dioxide is removed, and the purpose of preventing methane catalyst poisoning is achieved.
In order to further improve the treatment effect of the sulfur-containing flue gas, in the embodiment, the linear velocity of the sulfur-containing flue gas is less than or equal to 2m/s, and the airspeed of the sulfur-containing flue gas is less than or equal to 20000h -1 。
The sulfur-containing flue gas entering the reaction device 1 can fully react with the desulfurizing agent by controlling the speed and the volume of the sulfur-containing flue gas entering the reaction device 1, so that partial incomplete sulfur removal is avoided, and the sulfur-containing flue gas enters the catalytic oxidation reactor 2.
In this example, the number of channels of the desulfurizing agent in the reaction apparatus 1 is 200 to 300cpsi. Since a sufficient reaction surface is required between the desulfurizing agent and the sulfur-containing flue gas, the desulfurizing agent of the present application needs to maintain a certain number of channels for the sulfur-containing flue gas reaction, the number of channels being related to the linear velocity of the sulfur-containing flue gas of the present application and the space velocity of the sulfur-containing flue gas. When the number of the channels is too large, the filling volume of the desulfurizing agent is influenced, and the service life of the desulfurizing agent is influenced; when the number of channels is too small, the sulfur absorption effect of the desulfurizing agent is affected.
In a specific embodiment, the desulfurizing agent of the present application has a cell number of 200cpsi.
In this example, the catalytic atmosphere in the reaction apparatus 1 is: the catalytic temperature is 500-600 ℃, the content of water vapor in the catalytic atmosphere is 10-15%, and in the embodiment, "%" is the percentage of water vapor in the volume of gas in the reaction device 1.
In a specific embodiment, the catalytic atmosphere within the reaction device 1 is: the catalytic temperature is 520 ℃, and the water content in the catalytic atmosphere is 10%. The catalytic temperature and the moisture content in the reaction device 1 influence the removal rate of the desulfurizing agent, and in order to ensure the complete removal of sulfur dioxide in the sulfur-containing flue gas, the catalytic temperature and the moisture content in the reaction atmosphere are further defined.
At the bookIn the examples, SO in sulfur-containing flue gas 2 The content is less than or equal to 10ppm.
In order to improve the catalytic efficiency, in the embodiment, the particle size of the manganese dioxide as the desulfurizing agent is 200 nm-500 nm, and the loading amount of the desulfurizing agent is 80-85 g/dm 3 In a specific application, the loading of desulfurizing agent may be 85g/dm 3 . According to the method, the particle size of manganese dioxide is selected, the adsorption efficiency of the desulfurizing agent in the same time is guaranteed to be improved, meanwhile, the compaction density of the desulfurizing agent is limited through the filling amount, the influence of the too high compaction density on the diffusion of sulfur-containing flue gas in the reaction device is avoided, the fact that part of the desulfurizing agent cannot react with the sulfur-containing flue gas is avoided, and the influence of the too low compaction density of the desulfurizing agent in the reaction device 1 on the total adsorption amount of the desulfurizing agent is avoided.
According to the bench test result, under the catalysis condition that the catalysis temperature is 520 ℃ and the water vapor content is 10%, the linear velocity of sulfur-containing flue gas is controlled to be less than or equal to 2m/s, and the airspeed is controlled to be less than or equal to 20000h -1 Can contain SO 2 SO in flue gas below 10ppm 2 100% removal is obtained and can be used continuously for more than 2000 hours without changing the desulphurisation agent.
Further, as shown in fig. 2, SO in the exhaust gas of the dual-fuel engine 2 The content is generally in the range of 0-10ppm, and according to bench test result, the temperature is 520 ℃ for 20000h -1 Space velocity and 10% water content, in the absence of desulfurizing agent, 2ppmSO 2 The conversion of methane catalyst was reduced from 100% to 90% in 25 hours, indicating that the catalyst was in SO 2 The activity in the atmosphere with the concentration of 2ppm can be kept for 25 hours (the conversion rate is more than or equal to 90 percent), the flue gas subjected to desulfurization treatment by the reaction device 1 is continuously introduced, and the conversion rate of the methane catalyst is raised to a certain extent, but cannot return to a fresh state. It can be seen from the results of fig. 2 that the degree of poisoning of the methane catalyst can also be alleviated for the flue gas desulfurization treatment.
In this embodiment, the flue gas after desulfurization treatment is heated by the heating device 3 and then sent to the catalytic oxidation reactor 2. In specific embodiments, the heating device 3 is an electric heater, and because the exhaust temperature of the ship LNG power engine is low (200-300 ℃), the efficiency of methane catalytic oxidation is low, and in the embodiment of the application, the heating device 3 is adopted to improve the temperature of the flue gas to a proper temperature for methane catalytic oxidation, so that the catalytic oxidation reaction efficiency is improved, and the efficient catalytic conversion of methane is realized.
In a specific embodiment, after sulfur-containing flue gas is completely desulfurized in the reaction device 1, the sulfur-containing flue gas enters the catalytic reaction device 2, and the gas flow rate is controlled to 20000h -1 Within airspeed, CH 4 The concentration is below 2000ppm, the catalytic temperature is above 450 ℃, and the methane conversion rate can reach 100%.
In this embodiment, the flue gas after being treated by the catalytic oxidation reactor 2 is analyzed by the monitoring device 4, and the monitoring device 4 determines whether the content of methane in the flue gas after being treated exceeds a critical value: when the content of methane in the treated flue gas exceeds a critical value, the monitoring device 4 transmits a treatment signal to the controller 5, and the controller 5 adjusts the heating temperature of the heating device 3 so as to improve the flue gas temperature. In a specific embodiment, the monitoring device 4 is a flue gas online analyzer.
In particular embodiments, the threshold may be set at or below an upper line value for methane content specified in the emission standard.
Because traditional electrical heating method temperature is invariable, and the energy consumption is relatively higher, this application adopts monitoring devices 4 to carry out real-time supervision to the methane content in the flue gas after handling, realizes heating device 3's control through monitoring devices 4's feedback, and electric heater adopts timely heating to replace full load heating promptly, realizes flue gas temperature and adjusts in a flexible way, has solved the high problem of traditional electrical heating mode energy consumption, satisfies marine system low energy consumption's requirement.
In particular embodiments, the methane catalysts of the present application achieve flexible regeneration by: when the monitoring device 4 monitors CH 4 After the emission value exceeds the standard, the controller 5 starts the electric heater, and the temperature of the flue gas is heated to 550-600 ℃ and maintained for more than about 30 minutes, so that the regeneration after the catalyst is poisoned is realized.
The method can ensure that the methane emission after the medium-speed machine and the high-speed machine are processed is less than 1g/kWh, and meets the requirement of GB15097 emission limit of exhaust pollutants of ship engines and measurement method on the methane emission limit.
In the examples of the present application, the treatment system used in the methane slip remediation method includes a reaction device 1, a catalytic oxidation reactor 2, a heating device 3, a monitoring device 4, and a control device 5.
The reaction device 1 is filled with desulfurizer manganese dioxide for removing sulfur in sulfur-containing flue gas, in a specific embodiment, the number of pore canal after the desulfurizer is filled is 200 to 300cpsi, the particle size of the desulfurizer manganese dioxide is 200nm to 500nm, and the filling amount of the desulfurizer is 80 to 85g/dm 3 。
The air inlet of the catalytic oxidation reactor 2 is connected with the air outlet of the reaction device 1, a methane catalyst is filled in the catalytic oxidation reactor 2 for the catalytic reaction of methane, and methane in the flue gas is removed, in a specific embodiment, the methane catalyst can be any catalyst for realizing the catalytic oxidation reduction reaction of methane in the prior art, and in a specific application, the methane catalyst can be selected from catalysts containing palladium and platinum.
As described above, in the embodiment of the present application, the heating device 3 is disposed between the reaction device 1 and the catalytic oxidation reactor 2, and the flue gas subjected to desulfurization treatment is heated by the heating device 3 and then sent to the catalytic oxidation reactor 2.
In order to reduce the energy consumption of the system, in this embodiment, a monitoring device 4 is disposed at the air outlet of the catalytic oxidation reactor 2, the monitoring system 4 is in communication connection with a controller 5, the monitoring device 4 is an online flue gas analyzer in specific applications, the online flue gas analyzer is used for analyzing the methane content at the air outlet of the catalytic oxidation reactor 2, the monitoring device 4 transmits a processing signal to the controller 5, and the controller 5 is used for controlling the heating temperature of the heating device 3.
According to the method, the methane content in the flue gas is monitored by the monitoring system 4, so that the energy consumption of the controlled heating device can be reduced by more than 20% compared with full-load heating.
In the specific application, the methane-containing high-temperature ship tail gas firstly flows through the reaction device 1, sulfur dioxide in the flue gas reacts with manganese dioxide in the reaction device 1 to generate manganese sulfate, and the regeneration of the manganese sulfate is realized by periodically replacing desulfurization reactant blocks. The flue gas with sulfur dioxide removed is fed into a heating device 3, in the heating device 3, the flue gas is heated to a proper temperature for reaction, the heated flue gas is fed into a catalytic oxidation reactor 2 for removing methane, and the flue gas after removing methane is extracted into a monitoring device 4 for analyzing the methane content. When the methane content is unqualified, the monitoring equipment 4 sends out signal feedback, and the controller 5 adjusts the power of the heating device 3 so as to adjust the heating temperature of the heating device 3 and improve the flue gas temperature.
The methane escape treatment method and the treatment system have great significance for the treatment of the LNG power ship escape methane, the service life of the methane catalyst is prolonged, and the operation energy consumption of the whole system is reduced.
In the foregoing embodiments, the descriptions of the embodiments are emphasized, and for parts of one embodiment that are not described in detail, reference may be made to related descriptions of other embodiments.
The foregoing has described in detail a method and system for methane slip control provided by the embodiments of the present application, and specific examples have been used herein to illustrate the principles and embodiments of the present application, the description of the foregoing examples being merely intended to assist in understanding the methods and core ideas of the present application; meanwhile, those skilled in the art will have variations in the specific embodiments and application scope in light of the ideas of the present application, and the present description should not be construed as limiting the present application in view of the above.
Claims (10)
1. A method of methane slip remediation comprising the steps of:
desulfurizing the sulfur-containing flue gas through a reaction device (1), wherein a desulfurizing agent is filled in the reaction device (1), and the desulfurizing agent comprises manganese dioxide;
the flue gas after desulfurization treatment is sent into a catalytic oxidation reactor (2), and methane is removed from the flue gas in the catalytic oxidation reactor (2).
2. The methane slip remediation method of claim 1, wherein the sulfur-containing fumesThe linear velocity of the gas is less than or equal to 2m/s, and the airspeed of the sulfur-containing flue gas is less than or equal to 20000h -1 。
3. The methane slip control method according to claim 1, wherein the number of channels of the desulfurizing agent in the reaction apparatus (1) is 200 to 300cpsi.
4. The methane slip remediation method according to claim 1, characterized in that the catalytic atmosphere within the reaction device (1) is: the catalytic temperature is 500-600 ℃, and the content of water vapor in the catalytic atmosphere is 10-15%.
5. The methane slip remediation method of claim 1, wherein SO in the sulfur-containing flue gas 2 The content is less than or equal to 10ppm.
6. The method for controlling methane slip according to claim 1, wherein the particle size of the manganese dioxide is 200nm to 500nm.
7. The methane slip control method according to claim 1, characterized in that the loading amount of the desulfurizing agent in the reaction apparatus (1) is 80 to 85g/dm 3 。
8. The methane slip control method according to claim 1, characterized in that the desulphurized flue gas is fed into the catalytic oxidation reactor (2) after being heated by a heating device (3).
9. The methane slip control method according to claim 8, wherein the flue gas treated by the catalytic oxidation reactor (2) is analyzed by a monitoring device (4), and the monitoring device (4) judges whether the content of methane in the treated flue gas exceeds a critical value: when the content of methane in the treated flue gas exceeds a critical value, the monitoring device (4) transmits a treatment signal to the controller (5), and the controller (5) adjusts the heating temperature of the heating device (3) so as to improve the flue gas temperature.
10. A treatment system for use in the methane slip remediation method of claim 1, comprising:
a reaction device (1), wherein the reaction device (1) is used for removing sulfur in the sulfur-containing flue gas;
the catalytic oxidation reactor (2), catalytic oxidation reactor (2) with the gas outlet intercommunication of reaction unit (1), catalytic oxidation reactor (2) are used for the methane in desorption flue gas.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202211529164.4A CN116059811A (en) | 2022-11-30 | 2022-11-30 | Methane escape treatment method and treatment system |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202211529164.4A CN116059811A (en) | 2022-11-30 | 2022-11-30 | Methane escape treatment method and treatment system |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN116059811A true CN116059811A (en) | 2023-05-05 |
Family
ID=86175947
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202211529164.4A Pending CN116059811A (en) | 2022-11-30 | 2022-11-30 | Methane escape treatment method and treatment system |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN116059811A (en) |
Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101362587A (en) * | 2008-06-26 | 2009-02-11 | 中国石油化工股份有限公司 | Sulfur-containing methane is directly used in reaction absorption to strengthen methane steam reforming hydrogen production method |
| WO2014009146A1 (en) * | 2012-07-09 | 2014-01-16 | Paul Scherrer Institut | A method for methanation of gasification derived producer gas on metal catalysts in the presence of sulfur |
| CN103525474A (en) * | 2013-10-30 | 2014-01-22 | 西南化工研究设计院有限公司 | Ultrafine desulfurization agent and preparation method thereof |
| CN103884016A (en) * | 2014-04-14 | 2014-06-25 | 重庆大学 | Efficient catalytic combustion device and method of dust-contained sulfur-contained low-concentration methane |
| CN208687750U (en) * | 2018-07-25 | 2019-04-02 | 上海兰宝环保科技有限公司 | A kind of vertical catalytic combustion device for organic waste gases |
| CN111664717A (en) * | 2020-05-25 | 2020-09-15 | 中钢集团天澄环保科技股份有限公司 | Intelligent catalytic denitration CO removal and waste heat utilization integrated device |
-
2022
- 2022-11-30 CN CN202211529164.4A patent/CN116059811A/en active Pending
Patent Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101362587A (en) * | 2008-06-26 | 2009-02-11 | 中国石油化工股份有限公司 | Sulfur-containing methane is directly used in reaction absorption to strengthen methane steam reforming hydrogen production method |
| WO2014009146A1 (en) * | 2012-07-09 | 2014-01-16 | Paul Scherrer Institut | A method for methanation of gasification derived producer gas on metal catalysts in the presence of sulfur |
| CN103525474A (en) * | 2013-10-30 | 2014-01-22 | 西南化工研究设计院有限公司 | Ultrafine desulfurization agent and preparation method thereof |
| CN103884016A (en) * | 2014-04-14 | 2014-06-25 | 重庆大学 | Efficient catalytic combustion device and method of dust-contained sulfur-contained low-concentration methane |
| CN208687750U (en) * | 2018-07-25 | 2019-04-02 | 上海兰宝环保科技有限公司 | A kind of vertical catalytic combustion device for organic waste gases |
| CN111664717A (en) * | 2020-05-25 | 2020-09-15 | 中钢集团天澄环保科技股份有限公司 | Intelligent catalytic denitration CO removal and waste heat utilization integrated device |
Non-Patent Citations (1)
| Title |
|---|
| 梁吉艳 等: "《环境工程学》", 31 October 2014, 北京：中国建材工业出版社, pages: 175 * |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| US7818959B2 (en) | Clean power system | |
| KR101290022B1 (en) | Electrochemical-catalytic converter for exhaust emission control | |
| CN103055694A (en) | Method for flue gas denitrification by organic waste gas | |
| US6878471B1 (en) | Process for the regeneration of reforming catalysts | |
| US20050178107A1 (en) | Plasma fuel converter NOx adsorber system for exhaust aftertreatment | |
| US7611793B2 (en) | Fuel cell system, hydrogen gas supply unit, and method of controlling fuel cell system | |
| CN113274840A (en) | Device and method for treating VOCs waste gas through activated carbon adsorption high-temperature desorption-catalytic oxidation | |
| US20110217622A1 (en) | Electrochemical-catalytic converter for exhaust emission control with power generation | |
| US7708966B2 (en) | Systems and methods for on-site selective catalytic reduction | |
| CN101649764A (en) | Device and method for reducing emission of tail gas | |
| US20060112678A1 (en) | Multiple reactant multiple catalyst selective catalytic reduction for NOx abatement in internal combustion engines | |
| CN116059811A (en) | Methane escape treatment method and treatment system | |
| CN102485326A (en) | Electrochemical Catalytic Converter | |
| CN212068341U (en) | High CO concentration flue gas coupling low temperature SCR's processing system | |
| US12292020B2 (en) | Supply system | |
| CN102335552A (en) | Electrochemical catalytic converters that control exhaust emissions and generate electricity | |
| CN102162389B (en) | Reformed-gas-based device and method for purifying engine tail gas | |
| CN113877553B (en) | Active carbon regeneration process for desulfurization of blast furnace gas | |
| CN201985205U (en) | Protection system of fuel cell | |
| CN117328973A (en) | Multi-effect coupling catalytic conversion system for exhaust aftertreatment of ammonia-hydrogen engine | |
| JP4318281B2 (en) | Nitrogen oxide removal system | |
| CN210934478U (en) | A system for flue gas desulfurization and denitrification with methane | |
| CN202921169U (en) | Reactor used for removing nitrogen oxides by utilizing electrically aided NO catalytic reduction | |
| KR20120012608A (en) | Aftertreatment of the engine | |
| US20240309790A1 (en) | Purification system |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination |