WO2022191390A1 - Station de ravitaillement en hydrogène sur site à base d'ammoniac - Google Patents

Station de ravitaillement en hydrogène sur site à base d'ammoniac Download PDF

Info

Publication number
WO2022191390A1
WO2022191390A1 PCT/KR2021/019753 KR2021019753W WO2022191390A1 WO 2022191390 A1 WO2022191390 A1 WO 2022191390A1 KR 2021019753 W KR2021019753 W KR 2021019753W WO 2022191390 A1 WO2022191390 A1 WO 2022191390A1
Authority
WO
WIPO (PCT)
Prior art keywords
ammonia
hydrogen
unit
storage tank
site
Prior art date
Application number
PCT/KR2021/019753
Other languages
English (en)
Korean (ko)
Inventor
조병옥
김영래
정석용
이성훈
박새미
Original Assignee
(주)원익머트리얼즈
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by (주)원익머트리얼즈 filed Critical (주)원익머트리얼즈
Publication of WO2022191390A1 publication Critical patent/WO2022191390A1/fr

Links

Images

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C5/00—Methods or apparatus for filling containers with liquefied, solidified, or compressed gases under pressures
    • F17C5/06—Methods or apparatus for filling containers with liquefied, solidified, or compressed gases under pressures for filling with compressed gases
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B3/00—Hydrogen; Gaseous mixtures containing hydrogen; Separation of hydrogen from mixtures containing it; Purification of hydrogen
    • C01B3/02—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen
    • C01B3/04—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by decomposition of inorganic compounds, e.g. ammonia
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B3/00—Hydrogen; Gaseous mixtures containing hydrogen; Separation of hydrogen from mixtures containing it; Purification of hydrogen
    • C01B3/02—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen
    • C01B3/04—Production of hydrogen or of gaseous mixtures containing a substantial proportion of hydrogen by decomposition of inorganic compounds, e.g. ammonia
    • C01B3/047—Decomposition of ammonia
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01C—AMMONIA; CYANOGEN; COMPOUNDS THEREOF
    • C01C1/00—Ammonia; Compounds thereof
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01C—AMMONIA; CYANOGEN; COMPOUNDS THEREOF
    • C01C1/00—Ammonia; Compounds thereof
    • C01C1/003—Storage or handling of ammonia
    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01M—PROCESSES OR MEANS, e.g. BATTERIES, FOR THE DIRECT CONVERSION OF CHEMICAL ENERGY INTO ELECTRICAL ENERGY
    • H01M10/00—Secondary cells; Manufacture thereof
    • H01M10/42—Methods or arrangements for servicing or maintenance of secondary cells or secondary half-cells
    • H01M10/44—Methods for charging or discharging
    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01M—PROCESSES OR MEANS, e.g. BATTERIES, FOR THE DIRECT CONVERSION OF CHEMICAL ENERGY INTO ELECTRICAL ENERGY
    • H01M8/00—Fuel cells; Manufacture thereof
    • H01M8/04—Auxiliary arrangements, e.g. for control of pressure or for circulation of fluids
    • H01M8/04082—Arrangements for control of reactant parameters, e.g. pressure or concentration
    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01M—PROCESSES OR MEANS, e.g. BATTERIES, FOR THE DIRECT CONVERSION OF CHEMICAL ENERGY INTO ELECTRICAL ENERGY
    • H01M8/00—Fuel cells; Manufacture thereof
    • H01M8/04—Auxiliary arrangements, e.g. for control of pressure or for circulation of fluids
    • H01M8/04082—Arrangements for control of reactant parameters, e.g. pressure or concentration
    • H01M8/04201—Reactant storage and supply, e.g. means for feeding, pipes
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2221/00—Handled fluid, in particular type of fluid
    • F17C2221/01—Pure fluids
    • F17C2221/012—Hydrogen
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2250/00—Accessories; Control means; Indicating, measuring or monitoring of parameters
    • F17C2250/06—Controlling or regulating of parameters as output values
    • F17C2250/0605—Parameters
    • F17C2250/0626—Pressure
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2250/00—Accessories; Control means; Indicating, measuring or monitoring of parameters
    • F17C2250/06—Controlling or regulating of parameters as output values
    • F17C2250/0605—Parameters
    • F17C2250/0631—Temperature
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2260/00—Purposes of gas storage and gas handling
    • F17C2260/03—Dealing with losses
    • F17C2260/035—Dealing with losses of fluid
    • F17C2260/037—Handling leaked fluid
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2260/00—Purposes of gas storage and gas handling
    • F17C2260/03—Dealing with losses
    • F17C2260/035—Dealing with losses of fluid
    • F17C2260/038—Detecting leaked fluid
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2270/00—Applications
    • F17C2270/01—Applications for fluid transport or storage
    • F17C2270/0134—Applications for fluid transport or storage placed above the ground
    • F17C2270/0139—Fuel stations
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2270/00—Applications
    • F17C2270/01—Applications for fluid transport or storage
    • F17C2270/0165—Applications for fluid transport or storage on the road
    • F17C2270/0184—Fuel cells
    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01M—PROCESSES OR MEANS, e.g. BATTERIES, FOR THE DIRECT CONVERSION OF CHEMICAL ENERGY INTO ELECTRICAL ENERGY
    • H01M2250/00—Fuel cells for particular applications; Specific features of fuel cell system
    • H01M2250/20—Fuel cells in motive systems, e.g. vehicle, ship, plane

Definitions

  • the present invention relates to an ammonia-based on-site hydrogen charging station, and more particularly, to an ammonia-based on-site hydrogen charging station that can produce hydrogen using liquefied ammonia and supply it to a required place.
  • hydrogen production technology is representative of fossil fuel-based byproduct hydrogen, extracted hydrogen, and renewable energy-based water electrolysis hydrogen.
  • hydrogen charging stations can be largely divided into two types, off-site type and on-site type, depending on the method of supplying hydrogen.
  • the off-site hydrogen charging station is a method of transporting hydrogen produced in other regions to the hydrogen charging station and supplying it.
  • Off-site hydrogen charging stations are divided into pipeline supply type hydrogen charging stations and tube trailer supply type hydrogen charging stations according to the transport method.
  • the most common hydrogen refueling station is a tube trailer supply method, which incurs transportation costs, but has the advantage of not incurring equipment investment costs for transportation infrastructure, but requires a lot of space, and the hydrogen storage capacity is 200kg to 400kg. Since there is a limit to charging only 80 hydrogen vehicles per day, the hydrogen tank needs to be replaced frequently, which has a problem in that the operating cost of hydrogen transportation and replacement is high.
  • the on-site hydrogen refueling station produces and supplies hydrogen directly from the hydrogen refueling station.
  • On-site hydrogen refueling stations are divided into natural gas extraction (reforming) hydrogen refueling stations and water electrolysis hydrogen refueling stations according to the production method of hydrogen.
  • natural gas extraction hydrogen charging station hydrogen can be produced using the established natural gas supply line, so the transportation and storage cost of hydrogen is low.
  • ancillary costs are high to create a high-temperature environment, and since fossil fuels (natural gas) are used, CO2 is generated (safety costs and explosion risks exist as explosive gases).
  • An object of the present invention is to provide an ammonia-based on-site hydrogen charging station capable of producing hydrogen using ammonia and supplying it to a necessary place in order to solve the above problems.
  • the present invention was created to achieve the object of the present invention as described above, and an ammonia storage tank unit 100 for storing liquid ammonia, and hydrogen produced by using the liquid ammonia supplied from the ammonia storage tank unit 100
  • the hydrogen production unit 200, the hydrogen storage unit 300 for storing the hydrogen produced by the hydrogen production unit 200, and the hydrogen stored in the hydrogen storage unit 300 are connected to external equipment that requires hydrogen charging.
  • an ammonia-based on-site hydrogen charging station comprising a dispenser unit 400 for supplying external equipment.
  • the ammonia storage tank unit 100 may be installed in an underground space (B) separated from the ground by being surrounded by a protective wall (2) on all sides below the ground.
  • the ammonia storage tank unit 100 communicates with the storage tank 110 in which the liquid ammonia located in the underground space B is stored, and the liquid ammonia supply unit 10, and supplies the liquid ammonia to the storage tank 110. It may include a liquid ammonia inlet pipe 120 for introducing the liquid ammonia, and a liquid ammonia outlet pipe 130 communicating with the hydrogen production unit 200 and discharging the liquid ammonia from the storage tank 110 .
  • the ammonia storage tank unit 100 includes a leak detection unit 140 for detecting whether the storage tank 110 is leaking, and vapor phase ammonia to the underground space B when a leak occurs in the storage tank 110 . It may further include a solvent spraying unit 150 for spraying the solvent 23 that can be dissolved.
  • the ammonia storage tank unit 100 may further include at least one sensor 160 for measuring at least one of a temperature and a pressure inside the storage tank 110 .
  • the ammonia storage tank unit 100 may further include a temperature control unit 170 installed outside the storage tank 110 to control the temperature of the liquid ammonia.
  • the hydrogen production unit 200 includes a vaporizer 210 that receives liquid ammonia stored in the ammonia storage tank unit 100 and vaporizes it into vapor phase ammonia, and decomposes vapor phase ammonia vaporized in the vaporizer 210 into nitrogen and hydrogen.
  • a reactor 220, an adsorber 230 for adsorbing unreacted ammonia among the mixed gas passing through the reactor 220, and a separator 240 for separating hydrogen from the mixed gas passing through the adsorber 230. may include
  • the hydrogen production unit 200 is installed between a heating unit 250 for heating the gaseous ammonia in the reactor 220 and the reactor 220 and the adsorber 230 to recover the heat of the mixed gas.
  • a heat exchanger 260 may be further included.
  • the hydrogen production unit 200 includes an ammonia distributor 270 for distributing at least a portion of the vapor phase ammonia that has passed through the vaporizer 210 to the heating unit 250 and the reactor 220, respectively, and the separator 240 ) may further include a hydrogen distributor 280 for distributing at least a portion of the separated hydrogen to the heating unit 250 and the hydrogen storage unit 300 , respectively.
  • the hydrogen production unit 200, the ammonia and hydrogen supplied to the heating unit 250 through the ammonia distributor 270 and the hydrogen distributor 280 is burned, and then the generated exhaust gas is the heat source of the separator 240 . It may further include an exhaust gas transport line 292 for use as.
  • the vaporizer 210 includes a first flow path P1 through which a fluid exchanging heat with liquid ammonia passing through the vaporizer 210 flows, and the heat exchanger 260 passes through the heat exchanger 260 .
  • a second flow path P2 through which a fluid exchanging heat with the mixed gas flows may be included.
  • a circulation pump 296 installed in the line 294 may be further included.
  • the ammonia-based on-site hydrogen charging station uses ammonia to produce and supply hydrogen without CO 2 generation, thereby minimizing the transportation and storage cost of hydrogen and has the advantage of producing and supplying eco-friendly hydrogen.
  • FIG. 1 is a block diagram showing an ammonia-based on-site hydrogen charging station according to the present invention.
  • FIG. 2 is a conceptual view showing an ammonia storage tank unit of the hydrogen filling station of FIG. 1 .
  • FIG. 3 is a block diagram showing a hydrogen production unit of the hydrogen charging station of FIG. 1 .
  • FIG. 4 to 6 are conceptual views illustrating a part of the configuration of FIG. 3 .
  • FIG. 7 is a conceptual diagram showing a hydrogen storage unit and a dispenser unit of the hydrogen charging station of FIG. 1 .
  • the ammonia-based on-site hydrogen charging station includes an ammonia storage tank unit 100 for storing liquid ammonia, and the ammonia storage tank unit 100 supplied from A hydrogen production unit 200 for producing hydrogen using liquid ammonia, a hydrogen storage unit 300 for storing the hydrogen produced by the hydrogen production unit 200, and external equipment requiring hydrogen charging are connected to the hydrogen storage unit ( 300) and a dispenser unit 400 for supplying the hydrogen stored in the external equipment.
  • the ammonia storage tank unit 100 is configured to store liquid ammonia, and various configurations are possible.
  • Ammonia is toxic and is a substance that can have a fatal effect on the human body when leaked, so it is necessary to have a safety device for storing and handling liquid ammonia.
  • the ammonia storage tank unit 100 may be installed in an underground space (B) separated from the ground by being surrounded by a protective wall (2) on all sides below the ground (G) in order to safely store liquid ammonia, which is a liquid dangerous substance. have.
  • the ammonia storage tank unit 100 communicates with the storage tank 110 for storing liquid ammonia located in the underground space B, and the liquid ammonia supply unit 10, and the storage tank 110. It may include a liquid ammonia inlet pipe 120 for introducing liquid ammonia into the furnace, and a liquid ammonia outlet pipe 130 communicating with the hydrogen production unit 200 and draining the liquid ammonia from the storage tank 110 .
  • the storage tank 110 a tank for storing liquid ammonia, is located in the underground space B surrounded by the protective wall 2 and may be configured in various shapes and sizes according to specifications.
  • the storage tank 110 may be configured as a double jacket type for installing a temperature control unit 170 to be described later.
  • the liquid ammonia inlet pipe 120 is a pipe for supplying liquid ammonia to the storage tank 110 , and may communicate with the liquid ammonia supply unit 10 on the ground.
  • the liquid ammonia supply unit 10 is a facility for supplying liquid ammonia to the storage tank 110 , and as shown in FIG. 1 , may be configured as a transport vehicle using a tank lorry container.
  • liquid ammonia supply unit 10 is moved to the liquid ammonia supply position set on the ground above the underground space (B) where the storage tank 110 is installed, and the liquid ammonia inlet pipe 120 of the storage tank 110 is located. ) and then to provide liquid ammonia to the storage tank 110 .
  • One or more valves 12 for controlling the supply of liquid ammonia may be installed in the liquid ammonia inlet pipe 120 between the liquid ammonia supply 10 and the storage tank 110 .
  • the liquid ammonia outlet pipe 130 is a pipe for supplying the liquid ammonia stored in the storage tank 110 to the hydrogen production unit 200 to be described later.
  • Various configurations are possible, and the liquid ammonia supply to the hydrogen production unit 200 is provided.
  • One or more valves 132 for regulating may be installed.
  • ammonia storage tank unit 100 has a leak detection unit 140 for detecting whether the storage tank 110 is leaking, and when a leak occurs in the storage tank 110, the vapor rises to the underground space (B). It may further include a solvent spraying unit 150 for spraying a solvent capable of dissolving ammonia.
  • the leak detection unit 140 is configured to detect whether the storage tank 110 is leaking, and various configurations are possible.
  • the leak detection unit 140 may be an ammonia detector installed in the underground space (B) to detect the concentration of ammonia in the underground space (B). At this time, when the ammonia concentration detected by the leak detection unit 140 exceeds a preset standard, a leak occurs in the storage tank 110 and it may be determined that ammonia has leaked.
  • the solvent spraying unit 150 is configured to spray the solvent 23 capable of dissolving vapor phase ammonia into the underground space (B) when a leak occurs in the storage tank 110 , and various configurations are possible.
  • the solvent injection unit 150 includes a solvent storage unit 20 for storing the solvent 23 to be sprayed into the underground space B, and a flow path through which the solvent 23 flows, which is installed on the upper side of the underground space B. It may include a solvent flow path 152 to be formed, and one or more injection ports 154 provided in the solvent flow path 152 and through which a flow path flowing along the solvent flow path 152 is injected.
  • the solvent storage unit 20 is a storage unit in which the solvent 23 is stored, and various configurations are possible and may be installed on the ground.
  • the solvent flow path 152 is a flow path through which the solvent 23 communicates with the solvent storage unit 20 and the connection pipe 156, and can have various shapes and is installed in various patterns on the upper side of the underground space (B). can be
  • One or more valves 22 for controlling the flow of the solvent 23 may be installed between the solvent storage unit 20 and the solvent flow path 152 .
  • the injection holes 154 are preferably formed in a plurality of solvent passages 152 along the solvent passages 152 .
  • a nozzle for smoothly spraying the solvent 23 may be installed in the injection hole 154 .
  • the solvent 23 is a material for dissolving gaseous ammonia in the underground space B, and may be composed of various materials such as water or a neutralizing agent.
  • ammonia storage tank unit 100 may further include at least one sensor 160 for measuring at least one of temperature and pressure inside the storage tank 110 .
  • the ammonia storage tank unit 100 may include a sensor 160 for measuring the internal temperature of the storage tank 110 and a sensor 160 for measuring the internal pressure, respectively.
  • the sensor 160 it is possible to maintain the environment in the storage tank 110 so that the temperature and pressure inside the storage tank 110 are maintained in an appropriate state, thereby stably operating the facility, risk can be minimized.
  • the ammonia storage tank unit 100 may further include a temperature control unit 170 installed outside the storage tank 110 to control the temperature of the liquid ammonia.
  • the temperature control unit 170 is configured to control the temperature of the storage tank 110, and various configurations are possible.
  • the temperature control unit 170 may be a refrigerant passage that is installed in various shapes and patterns on the outer surface of the storage tank 110 and a refrigerant flows therein.
  • the temperature control unit 170 may be installed on the outer wall of the storage tank 110 when the storage tank 110 has a double jacket structure.
  • the temperature control unit 170 may allow ammonia to be stored in a liquid state at normal pressure through refrigerant circulation.
  • the temperature control unit 170 may be installed on the ground and coupled with the refrigerant circulation device 30 for refrigerant circulation.
  • the refrigerant circulation device 30 communicates with the temperature control unit 170 so that the refrigerant circulates along the temperature control unit 170 and includes a pair of circulation passages 34 through which the refrigerant flows in and out.
  • One or more valves 31 for controlling the circulation of the refrigerant may be provided in each of the circulation passages 34 .
  • the hydrogen production unit 200 is configured to produce hydrogen using the liquid ammonia supplied from the ammonia storage tank unit 100, and various configurations are possible.
  • the hydrogen production unit 200 may be installed on the ground, and between the hydrogen production unit 200 and the ammonia storage tank unit 100 is connected to the liquid ammonia outlet pipe 130 to store the liquid ammonia in the storage tank 110.
  • An ammonia transport pump 60 for transporting to the production unit 200 may be installed.
  • At least one valve 62 for controlling the transfer of liquid ammonia may be installed at at least one before and after the ammonia transfer pump 62 .
  • the hydrogen production unit 200 includes a vaporizer 210 that receives liquid ammonia stored in the ammonia storage tank unit 100 and vaporizes it into vapor phase ammonia, and a reactor that decomposes vapor phase ammonia vaporized in the vaporizer 210 into nitrogen and hydrogen. 220 , an adsorber 230 for adsorbing unreacted ammonia among the mixed gas passing through the reactor 220 , and a separator 240 for separating hydrogen from the mixed gas passing through the adsorber 230 . .
  • the vaporizer 210 may be configured in various configurations to vaporize the liquid ammonia transferred from the storage tank 110 into gaseous ammonia.
  • the liquid ammonia flowing into the vaporizer 210 may be vaporized into vapor phase ammonia by heating the liquid ammonia in the vaporizer 210 at a low temperature of 0°C to 3°C.
  • Liquid ammonia heating in the vaporizer 210 can be utilized in various ways, for example, the vaporizer 210, the vaporizer 210, the first flow path (P1) through which the fluid that exchanges heat with the liquid ammonia passing through the vaporizer 210 flows. ) may be included.
  • the high-temperature fluid may move along the first flow path P1 to vaporize the liquid ammonia in the vaporizer 210 .
  • Gas-phase ammonia vaporized through the vaporizer 210 may be injected into the reactor 220 .
  • the reactor 220 is configured to decompose gaseous ammonia vaporized in the vaporizer 210 into nitrogen and hydrogen, and various configurations are possible if hydrogen can be produced through ammonia.
  • the reactor 220 may include an ammonia decomposition catalyst layer 222 that decomposes ammonia into nitrogen and hydrogen.
  • the ammonia decomposition catalyst layer 222 may include both a metal and a non-metal catalyst, and is not limited to a specific material.
  • ammonia decomposition through the ammonia decomposition catalyst layer 222 is preferably performed in a rather high temperature environment.
  • the hydrogen production unit 200 may further include a heating unit 250 for heating the vapor phase ammonia in the reactor 220 .
  • the heating unit 250 various heat sources may be applied as long as the gaseous ammonia in the reactor 220 can be heated, and for example, may be configured as a combustor that generates heat by burning a raw material.
  • the heating unit 250 may be a combustor that is combusted using hydrogen as a raw material, but more specifically, may be a combustor using a gas in which hydrogen and ammonia are mixed for stable heat generation.
  • a fuel supply method to the heating unit 250 will be described later.
  • a mixed gas including nitrogen and oxygen in which ammonia is decomposed and unreacted ammonia that does not react with the ammonia decomposition catalyst layer 222 may be generated.
  • the mixed gas including nitrogen, oxygen, and unreacted ammonia that has passed through the reactor 220 may be injected into the adsorber 230 .
  • the adsorber 230 is configured to adsorb unreacted ammonia among the mixed gas that has passed through the reactor 220 , and various configurations are possible.
  • the mixed gas that has passed through the reactor 220 is in a high temperature state, but adsorption of unreacted ammonia through the adsorber 230 is not performed well in a high temperature environment.
  • the hydrogen production unit 200 is installed between the reactor 220 and the adsorber 230 to lower the temperature of the mixed gas that has passed through the reactor 220 to a temperature suitable for adsorption of unreacted ammonia. It may further include a heat exchanger 260 to recover the.
  • the mixed gas including nitrogen, oxygen, and unreacted ammonia that has passed through the reactor 220 is not directly injected into the adsorber 230 , but is injected into the heat exchanger 260 to complete heat exchange and then the adsorber 230 . ) is injected.
  • the heat exchanger 260 may use various heat exchange methods as long as the heat of the mixed gas can be recovered.
  • the heat exchanger 260 may include a second flow path P2 through which a fluid that exchanges heat with the mixed gas passing through the heat exchanger 260 flows.
  • the relatively low temperature fluid moves along the second flow path P2 , and heat of the mixed gas in the heat exchanger 260 may be recovered.
  • the hydrogen production unit 200 includes a fluid circulation line 294 and a fluid circulation line 294 for circulating communication between the first flow path P1 of the vaporizer 210 and the second flow path P2 of the heat exchanger 260 .
  • a circulation pump 296 installed in the fluid circulation line 294 to circulate the fluid along.
  • the high-temperature fluid eg, steam
  • the vaporizer 210 of liquid ammonia can be heated.
  • the fluid from which heat is recovered to liquid ammonia through the vaporizer 210 (eg, a state in which steam is deprived of heat and liquefied) is again transferred to the second flow path P2 along the fluid circulation line 294 and is a mixed gas of high temperature. of heat can be recovered.
  • the mixed gas (eg, 25° C. or less) from which heat is recovered by passing through the heat exchanger 260 may be injected into the above-described adsorber 230 .
  • the adsorber 230 may include two or more adsorption modules 230a and 230b connected in parallel to each other, as shown in FIG. 5 .
  • the adsorber 230 includes a first adsorption module 230a , a second adsorption module 230b connected in parallel, and a plurality of valves for controlling the flow direction of the mixed gas in the adsorber 230 . (V1, V2, V3, V4, V5, V6, V7, V8).
  • first adsorption module 230a and the second adsorption module 230b may be used alternately for continuous ammonia adsorption.
  • the other second adsorption module 230b is prepared for adsorption of unreacted ammonia. can be regenerated (or replaced) as
  • the first valve V1, the third valve V3, the fourth valve V4, and the sixth valve V6 are opened to open the first
  • the mixed gas passing through the adsorption module 230a may be injected into a separator 240 to be described later.
  • the second valve V2, the fifth valve V5, the seventh valve V7, and the eighth valve V8 may maintain a closed state.
  • the second valve V2 when the first adsorption module 230a is saturated after a certain time has elapsed, the second valve V2, the fifth valve V5, The seventh valve V7 and the eighth valve V8 may be opened to inject the mixed gas into the second adsorption module 230b.
  • the first valve V1, the third valve V3, the fourth valve V4, and the sixth valve V6 are closed, so that regeneration (or replacement) of the first adsorption module 230a may be performed.
  • the adsorber 230 has been described focusing on an embodiment including two adsorption modules 230a and 230b connected in parallel to each other, but the adsorber 230 includes a single adsorption module or system capacity.
  • the adsorber 230 includes a single adsorption module or system capacity.
  • the mixed gas (including nitrogen and hydrogen) passing through the first adsorption module 230a or the second adsorption module 230b may be injected into the separator 240 .
  • the mixed gas passing through the adsorber 230 may be compressed to a high pressure (eg, 20 bar) through the first compressor 70 and then injected into the separator 240 .
  • a high pressure eg, 20 bar
  • the separator 240 in order to prevent ammonia that has not been adsorbed in the adsorber 230 from being injected into the separator 240, it is installed in front of the separator 240, more specifically, in front of the first compressor 70, the separator It may further include an ammonia concentration sensor 92 for detecting the ammonia concentration in the mixed gas injected into the 240.
  • the ammonia concentration sensor 92 may check in real time whether or not the ammonia concentration in the mixed gas passing through deviates from a preset standard (eg, about 0.1 to 1 ppm) to check whether the facility operates normally.
  • a preset standard eg, about 0.1 to 1 ppm
  • the separator 240 is configured to separate hydrogen from the mixed gas that has passed through the adsorber 230 , and various configurations are possible.
  • the separator 240 may be a pressure swing absorption (PSA) or hydrogen separation membrane for nitrogen and hydrogen separation.
  • PSA pressure swing absorption
  • hydrogen separation membrane for nitrogen and hydrogen separation.
  • the separator 240 is formed of a PSA.
  • the separator 240 may be configured to separate hydrogen from the mixed gas by adsorbing nitrogen from the mixed gas injected under specific conditions (eg, 20 bar, 0° C. to 20° C.) and discharging only hydrogen.
  • the separator 240 may include a plurality of separation modules 240a and 240b connected in parallel to each other.
  • the separator 240 has been described focusing on an embodiment including two separation modules 240a and 240b connected in parallel to each other, but the separator 240 includes a single separation module or Of course, an embodiment including three or more separation modules connected in various ways, such as series and parallel, is also possible depending on the system capacity.
  • the separator 240 includes a first separation module 240a, a second separation module 240b connected in parallel, and a plurality of valves ( V11, V12, V21, V22) may be included.
  • first separation module 240a and the second separation module 240b may be used alternately for continuous hydrogen separation.
  • the other second separation module 240b is regenerated (or can be replaced).
  • valves V11 and V21 corresponding to the first separation module 240a are opened, and corresponding to the second separation module 240b The valves V12 and V22 are closed.
  • the hydrogen that has passed through the first separation module 240a may be injected into the hydrogen storage unit 300 to be described later through the V21 valve.
  • valves V11 and V21 are closed to regenerate the first separation module 240a (or replacement), the V12 and V22 valves are opened to inject the mixed gas into the second separation module 240b.
  • hydrogen separated by passing through the second separation module 240b may be injected into the hydrogen storage unit 300 to be described later through the V22 valve.
  • hydrogen separation can be continuously performed without interruption through the first separation module 240a and the second separation module 240b.
  • the first separation module 240a or the second separation module 240b regeneration (nitrogen emission) requires a relatively high temperature environment.
  • the high-temperature exhaust gas discharged from the heating unit 250 may be utilized as a heat source for regeneration of the first separation module 240a or the second separation module 240b.
  • the high-temperature exhaust gas formed as a result of combustion through the heating unit 250 is moved along the outer walls of the first separation module 240a and the second separation module 240b, and the first separation module
  • the temperature of the 240a and the second separation module 240b may be raised to a temperature suitable for regeneration.
  • valves V41, V42, V51, V52 for controlling the flow direction of the exhaust gas of the heating unit 250 on the separator 240 side may be provided.
  • V51 and V41 are opened to increase the temperature of the first separation module 240a, and the exhaust gas flowing along the outer wall of the first separation module 240a is externally passed through V41. is exhausted (V, vent).
  • the nitrogen discharged from the first separation module 240a by the regeneration process is exhausted (V, vent) to the outside through the vacuum pump 80 riding the V31 valve. At this time, V52, V42, V32 of the second separation module 240b maintains the closed state.
  • V52 and V42 are opened to increase the temperature of the second separation module 240b, and the exhaust gas flowing along the outer wall of the second separation module 240b passes through V42. It is exhausted (V, vent) to the outside through the
  • the nitrogen discharged from the second separation module 240b by the regeneration process is exhausted (V, vent) to the outside through the vacuum pump 80 riding the V32 valve. At this time, V51, V41, V31 of the first separation module 240a maintains the closed state.
  • the exhaust gas of the heating unit 250 for heating the vaporizer 210 of the present invention has an advantage that can be utilized as a heat source for regeneration of the separator 240 .
  • Hydrogen that has passed through the first separation module 240a or the second separation module 240b may be injected into the hydrogen storage unit 300 .
  • a second compressor 40 for compressing the hydrogen that has passed through the separator 240 to a high pressure may be installed.
  • the separator 240 in order to check the hydrogen concentration of the gas that has passed through the separator 240 in real time, it is installed at the front end of the dispenser unit 400, more specifically, the front end of the second compressor 40 to detect the hydrogen concentration passing through.
  • a hydrogen concentration sensor 94 may be further included.
  • the hydrogen concentration sensor 94 may check whether the equipment is normally operated by detecting in real time whether the gas passing through meets a hydrogen concentration higher than a preset standard (eg, 99.995% or more).
  • a preset standard eg, 99.995% or more
  • the hydrogen storage unit 300 is configured to store hydrogen compressed at high pressure through the second compressor 40, and various configurations are possible if it is configured to store high-pressure hydrogen or liquid hydrogen.
  • the dispenser unit 400 is connected to external equipment that requires hydrogen charging, and various configurations are possible in a configuration for supplying hydrogen stored in the hydrogen storage unit 300 to the external equipment.
  • the external equipment may include all equipment using hydrogen as a fuel, and for example, as shown in FIG. 7 , may be a hydrogen vehicle 50 using a fuel cell.
  • the hydrogen production unit 200 includes an ammonia distributor 270 for distributing at least a portion of gaseous ammonia that has passed through the vaporizer 210 to the heating unit 250 and the reactor 220, respectively, and a separator.
  • a hydrogen distributor 280 for distributing at least a portion of the hydrogen separated in 240 to the heating unit 250 and the hydrogen storage unit 300 may be further included.
  • the ammonia distributor 270 is installed between the vaporizer 210 and the reactor 220 to inject the majority of gaseous ammonia that has passed through the vaporizer 210 into the reactor 220 and distributes at least a portion to the heating unit 250 .
  • a variety of configurations are possible.
  • the hydrogen distributor 280 is installed between the separator 240 and the hydrogen storage unit 300 (more specifically, the second compressor 40), the majority of the separated and discharged from the separator 240
  • the hydrogen distributor 280 is installed between the separator 240 and the hydrogen storage unit 300 (more specifically, the second compressor 40), the majority of the separated and discharged from the separator 240
  • the hydrogen distributor 280 is installed between the separator 240 and the hydrogen storage unit 300 (more specifically, the second compressor 40), the majority of the separated and discharged from the separator 240
  • various configurations are possible.
  • the heating unit 250 may receive ammonia and hydrogen respectively and utilize it as fuel for combustion.
  • the exhaust gas produced after the ammonia and hydrogen supplied to the heating unit 250 through the ammonia distributor 270 and the hydrogen distributor 280 is combusted can be utilized as a heat source of the separator 240 as described above. same.
  • the hydrogen production unit 200 is, the ammonia and hydrogen supplied to the heating unit 250 through the ammonia distributor 270 and the hydrogen distributor 280 is combusted, and then the generated exhaust gas is discharged to the separator ( 240) may include an exhaust gas transport line 292 for use as a heat source.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Organic Chemistry (AREA)
  • Inorganic Chemistry (AREA)
  • Manufacturing & Machinery (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Electrochemistry (AREA)
  • General Chemical & Material Sciences (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Sustainable Development (AREA)
  • Sustainable Energy (AREA)
  • Health & Medical Sciences (AREA)
  • General Health & Medical Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Hydrogen, Water And Hydrids (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)

Abstract

La présente invention concerne une station de ravitaillement en hydrogène sur site à base d'ammoniac et, plus particulièrement, une station de ravitaillement en hydrogène sur site à base d'ammoniac, qui utilise de l'ammoniac liquide pour produire de l'hydrogène et peut en fournir si nécessaire. L'invention concerne une station de ravitaillement en hydrogène sur site à base d'ammoniac comprenant : une partie réservoir de stockage d'ammoniac (100) pour stocker de l'ammoniac liquide ; une partie de production d'hydrogène (200) pour produire de l'hydrogène à l'aide de l'ammoniac liquide fourni à partir de la partie réservoir de stockage d'ammoniac (100) ; une partie de stockage d'hydrogène (300) pour stocker l'hydrogène produit au niveau de la partie de production d'hydrogène (200) ; et une partie de distribution (400) raccordée à un équipement externe, qui nécessite un ravitaillement en hydrogène, de façon à fournir l'hydrogène stocké dans la partie de stockage d'hydrogène (300) à l'équipement externe.
PCT/KR2021/019753 2021-03-12 2021-12-23 Station de ravitaillement en hydrogène sur site à base d'ammoniac WO2022191390A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
KR10-2021-0032961 2021-03-12
KR1020210032961A KR20220128567A (ko) 2021-03-12 2021-03-12 암모니아 기반의 On-site 수소충전소

Publications (1)

Publication Number Publication Date
WO2022191390A1 true WO2022191390A1 (fr) 2022-09-15

Family

ID=83227929

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/KR2021/019753 WO2022191390A1 (fr) 2021-03-12 2021-12-23 Station de ravitaillement en hydrogène sur site à base d'ammoniac

Country Status (2)

Country Link
KR (1) KR20220128567A (fr)
WO (1) WO2022191390A1 (fr)

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JP5457395B2 (ja) * 2005-04-18 2014-04-02 インテリジェント エナジー インコーポレイテッド 水素発生装置及び水素発生方法
JP2015074576A (ja) * 2013-10-08 2015-04-20 大陽日酸株式会社 アンモニア精製装置、及びアンモニア精製方法
JP2017107702A (ja) * 2015-12-08 2017-06-15 パナソニックＩｐマネジメント株式会社 水素供給システム
WO2017154732A1 (fr) * 2016-03-07 2017-09-14 昭和電工株式会社 Dispositif de décomposition de l'ammoniac et dispositif de production d'hydrogène gazeux
KR20190046081A (ko) * 2017-10-25 2019-05-07 두산중공업 주식회사 액화 천연 가스의 냉열을 이용한 복합 발전 시스템
KR102256907B1 (ko) * 2019-12-24 2021-05-27 (주)원익머트리얼즈 암모니아 기반의 On-site 수소충전소

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JP5457395B2 (ja) * 2005-04-18 2014-04-02 インテリジェント エナジー インコーポレイテッド 水素発生装置及び水素発生方法
JP2015074576A (ja) * 2013-10-08 2015-04-20 大陽日酸株式会社 アンモニア精製装置、及びアンモニア精製方法
JP2017107702A (ja) * 2015-12-08 2017-06-15 パナソニックＩｐマネジメント株式会社 水素供給システム
WO2017154732A1 (fr) * 2016-03-07 2017-09-14 昭和電工株式会社 Dispositif de décomposition de l'ammoniac et dispositif de production d'hydrogène gazeux
KR20190046081A (ko) * 2017-10-25 2019-05-07 두산중공업 주식회사 액화 천연 가스의 냉열을 이용한 복합 발전 시스템
KR102256907B1 (ko) * 2019-12-24 2021-05-27 (주)원익머트리얼즈 암모니아 기반의 On-site 수소충전소

Also Published As

Publication number Publication date
KR20220128567A (ko) 2022-09-21

Similar Documents

Publication Publication Date Title
KR102256907B1 (ko) 암모니아 기반의 On-site 수소충전소
WO2022145661A1 (fr) Procédé de préparation d'hydrogène de haute pureté à l'aide d'ammoniac, appareil de préparation associé et système de module de type sur site
US20050053878A1 (en) Device for combustion of a carbon containing fuel in a nitrogen free atmosphere and a method for operating said device
CN101501400B (zh) 燃烧装置、燃料处理装置及燃料电池发电系统
WO2009093852A1 (fr) Système de traitement de décomposition thermique de déchets inflammables et procédé de traitement des déchets utilisant le système
WO2013141453A1 (fr) Système et procédé de gestion de dioxyde de carbone
WO2017003066A1 (fr) Générateur d'hydrogène et procédé de production d'hydrogène, au moyen de plasma de vapeur
WO2022191390A1 (fr) Station de ravitaillement en hydrogène sur site à base d'ammoniac
WO2020189969A1 (fr) Appareil de production d'énergie combiné
WO2018062714A1 (fr) Module d'alimentation en gaz et équipement d'alimentation en gaz le comportant
EP2659949B1 (fr) Système de récupération de co2
WO2020085668A1 (fr) Système et procédé de production d'énergie à dioxyde de carbone supercritique par combustion directe
WO2013038051A1 (fr) Disposition et procédé de ventilation pour système de piles à combustible à haute température
KR20230090291A (ko) 수전해 폐열 활용 고순도 수소 생산 시스템
WO2017057942A1 (fr) Appareil et procédé de fabrication de monoxyde de carbone à l'aide d'un plasma à vapeur d'eau
WO2022034974A1 (fr) Système de gazéification à lit fluidisé de biomasse
CN114759309A (zh) 一种动力电池热失控被动安全系统
WO2016098916A1 (fr) Dispositif d'approvisionnement en eau de mer pour vaporisateur à ruissellement à eau
KR20230015868A (ko) 이산화탄소 회수단계를 포함하는 연료전지시스템의 작동방법과 이에 관련된 장치
WO2022092427A1 (fr) Dispositif de réductions d'émissions de gaz à effet de serre provenant d'un navire et navire le comprenant
WO2024219826A1 (fr) Système de traitement d'ammoniac et navire le comprenant
WO2024186172A1 (fr) Système de capture de dioxyde de carbone pour navire
JP5743097B2 (ja) 固体酸化物形燃料電池及び固体酸化物形燃料電池の停止時冷却方法
WO2019142967A1 (fr) Appareil de réduction d'oxyde de soufre pour navire et son procédé de fonctionnement
WO2015130095A1 (fr) Procédé de protection de pile en cas d'arrêt d'urgence ou d'extinction dans un système de pile à combustible à oxyde solide

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 21930490

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 21930490

Country of ref document: EP

Kind code of ref document: A1