EP4332423B1 - Système de stockage de gaz combustible - Google Patents

Système de stockage de gaz combustible

Info

Publication number
EP4332423B1
EP4332423B1 EP23188888.4A EP23188888A EP4332423B1 EP 4332423 B1 EP4332423 B1 EP 4332423B1 EP 23188888 A EP23188888 A EP 23188888A EP 4332423 B1 EP4332423 B1 EP 4332423B1
Authority
EP
European Patent Office
Prior art keywords
fuel gas
storage system
heat exchanger
gas storage
refrigerant
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.)
Active
Application number
EP23188888.4A
Other languages
German (de)
English (en)
Other versions
EP4332423C0 (fr
EP4332423A1 (fr
Inventor
Simon SCHMIDT
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
RWE Gas Storage West GmbH
Original Assignee
RWE Gas Storage West GmbH
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 RWE Gas Storage West GmbH filed Critical RWE Gas Storage West GmbH
Publication of EP4332423A1 publication Critical patent/EP4332423A1/fr
Application granted granted Critical
Publication of EP4332423B1 publication Critical patent/EP4332423B1/fr
Publication of EP4332423C0 publication Critical patent/EP4332423C0/fr
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D1/00—Pipe-line systems
    • F17D1/02—Pipe-line systems for gases or vapours
    • F17D1/04—Pipe-line systems for gases or vapours for distribution of gas
    • 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
    • F17C1/00—Pressure vessels, e.g. gas cylinder, gas tank, replaceable cartridge
    • 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
    • F17C1/00—Pressure vessels, e.g. gas cylinder, gas tank, replaceable cartridge
    • F17C1/007—Underground or underwater storage
    • 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
    • F17C2201/00—Vessel construction, in particular geometry, arrangement or size
    • F17C2201/05—Size
    • F17C2201/052—Size large (>1000 m3)
    • 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
    • F17C2221/00—Handled fluid, in particular type of fluid
    • F17C2221/03—Mixtures
    • F17C2221/032—Hydrocarbons
    • F17C2221/033—Methane, e.g. natural gas, CNG, LNG, GNL, GNC, PLNG
    • 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
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/01—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the phase
    • F17C2223/0107—Single phase
    • F17C2223/0123—Single phase gaseous, e.g. CNG, GNC
    • 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
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/03—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the pressure level
    • F17C2223/035—High pressure (>10 bar)
    • 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
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/03—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the pressure level
    • F17C2223/036—Very high pressure (>80 bar)
    • 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
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0302—Heat exchange with the fluid by heating
    • F17C2227/0309—Heat exchange with the fluid by heating using another 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
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0302—Heat exchange with the fluid by heating
    • F17C2227/0325—Heat exchange with the fluid by heating by expansion using "Joule-Thompson" effect
    • 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
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0337—Heat exchange with the fluid by cooling
    • F17C2227/0358—Heat exchange with the fluid by cooling by expansion
    • F17C2227/0362—Heat exchange with the fluid by cooling by expansion in a turbine
    • 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
    • F17C2265/00—Effects achieved by gas storage or gas handling
    • F17C2265/07—Generating electrical power as side effect
    • 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
    • F17C2270/0142—Applications for fluid transport or storage placed underground
    • 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
    • F17C2270/0142—Applications for fluid transport or storage placed underground
    • F17C2270/0144—Type of cavity
    • F17C2270/0149—Type of cavity by digging cavities
    • F17C2270/0152—Salt caverns

Definitions

  • the application relates to a fuel gas storage system, comprising at least one fuel gas connection configured to provide a fuel gas from a fuel gas distribution network, at least one fuel gas compression arrangement configured to compress the provided fuel gas, at least one fuel gas storage device (e.g., a cavity artificially created in salt rock) configured to store the compressed fuel gas, and at least one fuel gas expansion arrangement configured to expand the fuel gas extracted from the fuel gas storage device, wherein the fuel gas connection is configured to feed the expanded fuel gas into the (public) fuel gas distribution network. Furthermore, the application relates to a method for operating a fuel gas storage system.
  • fuel gases include natural gas, biogas, and hydrogen.
  • the fuel gas is transported via a pipeline network or fuel gas distribution network and regularly stored using fuel gas storage systems.
  • Known fuel gas storage systems comprise at least one fuel gas storage unit in which the fuel gas is temporarily stored.
  • the fuel gas supplied via the fuel gas distribution network is first compressed by a compression arrangement.
  • the compressed fuel gas is then stored in the fuel gas storage unit.
  • the fuel gas is withdrawn from the storage unit via an expansion arrangement.
  • the expanded fuel gas is then fed back into the fuel gas distribution network.
  • at least one further process plant can be used for the specification-compliant processing of the stored fuel gas before a A return line to the fuel gas distribution network must be provided, such as a fuel gas dryer or similar.
  • the document US 9803803 B1 discloses fuel gas storage system.
  • the Figure 1 shows an exemplary prior art fuel gas storage system 100.
  • the fuel gas storage system 100 includes a fuel gas compression assembly 104, a fuel gas storage 106, and a fuel gas expansion assembly 108. Furthermore, an internal fuel gas distribution network 126 in the form of a plurality of pipes is provided.
  • the fuel gas storage system 100 is coupled to a public fuel gas distribution network 102 via a fuel gas connection 122.
  • the fuel gas connection 122 is configured to provide fuel gas from the fuel gas distribution network 102. This fuel gas is provided or supplied, in particular, to the fuel gas compression arrangement 104. It should be noted that the flow direction of the fuel gas in the internal fuel gas distribution network 126 is indicated by arrows.
  • the fuel gas provided through the fuel gas connection 122 normally has a temperature between approximately 8° C and 15° C before the first compression stage 114.1.
  • the compressor 110 of the first compression stage 114.1 increases the temperature of the fuel gas to approximately 50° C to 150° C.
  • the work performed on the fuel gas by the compressor 110 increases the internal energy of the fuel gas and thus its temperature.
  • each compressor 110 is followed by an air cooler 112.
  • the fuel gas heated to a temperature of up to approximately 150°C can be cooled back down to approximately 45°C by a downstream air cooler 112.
  • the fuel gas After the fuel gas has been compressed by the last compression stage 114.x and subsequently cooled down, it is fed into the fuel gas storage 106 through a storage connection 124 of the fuel gas storage 106 and stored there, in particular temporarily stored.
  • the stored fuel gas is withdrawn from the fuel gas storage 106 via the storage connection 124 and, in particular, provided to a fuel gas expansion arrangement 108.
  • the prior art initially involves heating the withdrawn natural gas via a heating device 116 of the fuel gas expansion arrangement 108.
  • the preheated natural gas is then expanded via a control valve 118 or expansion valve 118.
  • the expanded natural gas is fed to a gas treatment unit 120 and fed into the fuel gas distribution network 102 via the fuel gas connection.
  • the fuel gas is hydrogen
  • it is pre-cooled by a cooling device 116 of the fuel gas expansion arrangement 108.
  • the pre-cooled hydrogen is then expanded via the control valve 118 or expansion valve 118.
  • the expanded hydrogen is fed to a gas treatment unit 120 and fed into the fuel gas distribution network 102 via the fuel gas connection.
  • the application is based on the object of providing a fuel gas storage system in which the need for energy from external energy sources is at least reduced.
  • the fuel gas storage system is used to store a fuel gas, in particular for temporary storage of the fuel gas.
  • a fuel gas is understood, in particular, to be a combustible useful gas that is burned or oxidized in an electrochemical converter (e.g., a combustion device, a fuel cell, etc.) of a fuel gas consumer to provide, for example, thermal energy and/or electrical energy.
  • the fuel gas can be selected from the group comprising: natural gas, biogas, and hydrogen.
  • the fuel gas storage system is particularly configured for storing and retrieving natural gas or hydrogen.
  • a fuel gas is transported, in particular, via an (external and especially public) fuel gas distribution network from a fuel gas source to a fuel gas consumer (e.g. gas power plant, gas heating of a building, etc.).
  • a fuel gas distribution network or fuel gas transport network usually comprises a number of Transport network pipes or transport network lines through which the fuel gas is transported.
  • the fuel gas storage system can be operated essentially seasonally. This means, in particular, that fuel gas is stored during the warm months and removed during the cold months.
  • the fuel gas storage system can in particular follow the availability of electrical energy from so-called renewable energy sources (e.g. sun, wind, etc.).
  • the fuel source can in particular be an electrically operated electrolysis plant.
  • the electrolysis plant can in particular be operated with electrical energy to produce hydrogen when electrical energy from the renewable energy sources is available, for example when more electrical energy is generated by wind farms and/or photovoltaic parks due to the corresponding meteorological conditions (e.g. high wind speeds and/or high solar radiation) than is required by electrical consumers of an external (public) electricity distribution grid.
  • the hydrogen produced can be at least partially taken from the external fuel gas distribution grid in the form of a hydrogen distribution grid and (temporarily) stored in the fuel gas storage system.
  • stored hydrogen can be taken from the fuel gas storage system, fed into the hydrogen distribution grid and made available to a hydrogen power plant in order to generate electrical energy, in particular by burning the hydrogen provided.
  • the fuel gas connection (e.g., comprising a controllable valve arrangement) is fluidly coupled or connected to a fuel gas compression arrangement.
  • the fuel gas storage system can comprise an internal refrigerant distribution network (e.g., formed by a plurality of transport pipes). It is understood that additional modules, e.g., for fuel gas purification and/or treatment, can be arranged between the fuel gas connection and the fuel gas compression arrangement.
  • the fuel gas compression arrangement is configured to compress the provided fuel gas.
  • the fuel gas compression arrangement may comprise at least one compressor.
  • a compressor is configured to supply mechanical work to the (enclosed) fuel gas, thereby increasing, in particular, the pressure and density of the fuel gas.
  • a fuel gas compression arrangement can comprise a plurality of compression stages, each with a compressor, in order to effect a specific (predeterminable) compression of the fuel gas provided.
  • the fuel gas storage system comprises at least one fuel gas expansion assembly, which is fluidically connected, in particular, to the storage connection.
  • the fuel gas expansion assembly has at least one expansion machine configured to expand the fuel gas extracted from the fuel gas storage. Expansion refers, in particular, to reducing the pressure and density of the fuel gas.
  • a turbine device may comprise a turbine housing.
  • the turbine housing may be made of metal, in particular steel.
  • the turbine housing may have an inlet to which a pipe or line of the internal refrigerant distribution network can be connected.
  • the pipe may lead to the storage connection.
  • the turbine housing may have an outlet, particularly on the side of the turbine housing opposite the inlet, to which another pipe or a second line of the internal refrigerant distribution network can be connected.
  • the pipes may be flange-mounted, particularly at the inlet or outlet.
  • the turbine device comprises, in particular, at least one rotor arranged (or mounted) on a turbine shaft.
  • the turbine shaft is arranged, in particular, within the turbine housing.
  • the turbine shaft can thus be coupled (mechanically, in particular torque-locked) to the rotor.
  • the rotor comprises, in particular, an impeller with a plurality of impeller blades.
  • the fuel gas flowing from the inlet to the outlet of the turbine device causes, in particular, a mechanical movement of the rotor assembly. This leads to a relaxation of the fuel gas or the fuel gas pressure. Furthermore, the mechanical movement of the rotor assembly is transferred to the turbine shaft, in particular into a rotational movement of the turbine shaft. This rotational movement can be further utilized, as will be described below.
  • the expanded fuel gas is fed (again) into the external fuel gas distribution network via the fuel gas connection, if necessary after further fuel gas processing.
  • the at least one fuel gas storage device can be a cavern, in particular a salt cavern.
  • a salt cavern is, in particular, that additional lining is unnecessary due to the petrophysical properties of salt.
  • the expansion working machine can be a turbine device and comprise at least one generator.
  • the generator can be configured to generate electrical energy.
  • the turbine shaft is (mechanically) coupled to the at least one generator.
  • the generator is therefore particularly mounted on the turbine shaft arranged or mounted.
  • an indirect coupling may be provided, for example, a gearbox may be interposed.
  • the generator can, in particular, convert the rotational movement of the shaft or the rotational energy into electrical energy.
  • the at least one generator preferably coupled to the turbine shaft, is particularly configured to convert the mechanical energy generated during the relaxation process into electrical energy.
  • the generator can be an asynchronous machine, for example.
  • the at least one generator can be arranged, in particular, in a "floating" manner within the turbine housing.
  • the fuel gas can flow at least partially around the generator or the generator housing.
  • the at least one generator can be arranged upstream of the rotor assembly in the flow direction.
  • the at least one generator can be arranged downstream of the rotor assembly, or, in addition to the generator upstream of the rotor assembly in the flow direction, another generator can be arranged downstream of the rotor assembly.
  • the arrangement of the at least one generator can depend, in particular, on the fuel gas to be expanded.
  • the fuel gas storage system can comprise an internal power grid.
  • the internal power grid can be formed from at least one electrically conductive line, in particular a plurality of lines. It is understood that additional components, such as fuses, switches, etc., can be provided.
  • the electrical energy generated by the at least one generator of the turbine device can be fed into the (external) electricity distribution network (via an electrical grid connection) if more electrical energy is generated by the generator than is required in the fuel gas storage system and/or if there is a high energy demand in the (external) electricity distribution network (or during peak load times).
  • the fuel gas storage system can comprise at least one rechargeable battery connected to the internal power grid.
  • the electrical energy demand of the fuel gas storage system during expansion of the fuel gas or during removal from storage is lower than the electrical energy generated by the at least one generator, excess electrical energy can be (at least partially) (temporarily) stored in the battery.
  • the at least one electrical consumer of the fuel gas compression arrangement can then preferably be supplied (at least partially) with the electrical energy stored in the battery.
  • the expansion machine in particular the turbine device, can comprise at least one first heat exchanger.
  • the at least one first heat exchanger can be configured to cool a fluid refrigerant.
  • two first heat exchangers can also be provided in the expansion machine.
  • a first heat exchanger is configured, in particular, to (partially) transfer the thermal energy of the fuel gas to the fluid refrigerant.
  • the fluid refrigerant can be selected from the group comprising R124a, CO 2 , and NH 3 . It is understood that in other variants of the application, a different refrigerant can also be used. In particular, partially halogenated hydrocarbons can be used as refrigerants.
  • the at least one first heat exchanger can be integrated in the turbine housing, in particular arranged behind the impeller as seen in the flow direction.
  • the generator can be arranged or mounted on the turbine shaft in the direction of flow upstream of the rotor assembly, and the first heat exchanger can be arranged or mounted on the turbine shaft in the direction of flow downstream of the rotor assembly.
  • the at least one first heat exchanger can also be arranged in the region of the outlet of the turbine housing or downstream of the outlet of the turbine housing.
  • the fuel gas is cooled by the expansion by means of the turbine device.
  • the cooled fuel gas can be used, in particular, to cool and condense the fluid refrigerant.
  • the fuel gas storage system may preferably comprise at least one internal refrigerant distribution network.
  • the refrigerant distribution network may comprise at least one pipe or line, in particular a plurality of pipes or lines.
  • the internal refrigerant distribution network may be configured to supply the at least one second heat exchanger at least partially with the fluid refrigerant cooled by the first heat exchanger.
  • At least the second heat exchanger must be connected to the first heat exchanger (directly or indirectly) via the internal refrigerant distribution network.
  • the at least one second heat exchanger can be arranged in the fuel gas compression arrangement such that the provided fuel gas is cooled (as viewed in the flow direction) upstream of the at least one compressor (or the first compression stage) of the fuel gas compression arrangement.
  • the at least one second heat exchanger can be positioned between the fuel gas connection and the first compression stage of the fuel gas compression arrangement.
  • the provided fuel gas can be cooled by the second heat exchanger to a temperature of at least less than 0°C, in particular less than -10°C, preferably less than -15°C, particularly preferably to at least (less than) -20°C.
  • a temperature of at least less than 0°C in particular less than -10°C, preferably less than -15°C, particularly preferably to at least (less than) -20°C.
  • the fuel gas in particular independent of the outside temperature
  • This temperature difference can extend through all compression stages. This makes it possible, in particular, to design the at least one compressor or the at least one compression system, in particular all compressors, with lower power compared to a fuel gas compression arrangement of the prior art.
  • the second heat exchanger can be supplied with cooled refrigerant from the first refrigerant reservoir.
  • the fuel gas storage system can comprise at least one second refrigerant storage unit.
  • the second refrigerant storage unit can be configured to store the fluid refrigerant heated by the at least one second heat exchanger.
  • the at least one second refrigerant storage unit can be connected to the internal refrigerant distribution network, in particular to the return channel.
  • the first heat exchanger can be supplied with the heated refrigerant from the second refrigerant storage device.
  • a guide device or steering device can be arranged upstream of the rotor assembly of the turbine device in the flow direction.
  • the guide device is particularly adapted to the rotor assembly.
  • the guide device is preferably configured to direct the fuel gas onto the rotor assembly in a specific direction.
  • the fuel gas storage system can preferably comprise a control device configured to control the fuel gas storage system.
  • the control device can be configured to control the storage process, i.e. in particular by correspondingly controlling the fuel gas connection (e.g. the valve arrangement), the fuel gas compression arrangement (e.g. the at least one compressor) and/or the storage connection (e.g. the valve arrangement).
  • the control device can be configured to control the removal process, i.e. in particular by correspondingly controlling the fuel gas connection (e.g. the valve arrangement), the Fuel gas expansion arrangement and/or the storage connection (e.g. the valve arrangement).
  • control device can comprise a communication module configured to receive an instruction message for storing and/or retrieving fuel gas. The control device can then control the fuel gas storage system accordingly.
  • the Figure 2 shows a schematic view of an embodiment of a fuel gas storage system 200 according to the present application.
  • the fuel gas storage system 200 serves for the temporary storage of a fuel gas, preferably natural gas or hydrogen.
  • the fuel gas storage system 200 comprises at least one fuel gas connection 222 (e.g., with a controllable valve arrangement (not shown)) configured to provide a fuel gas from an (external) fuel gas distribution network 202.
  • fuel gas can be withdrawn from the (external) fuel gas distribution network 202 through the fuel gas connection 222 and fed into the internal fuel gas distribution network 226 of the fuel gas storage system 200.
  • the flow direction of the fuel gas is indicated in the figures, in particular by the arrows.
  • the fuel gas storage system 200 comprises at least one fuel gas compression arrangement 204, in particular with at least one Compressor 210 or a compression system, equipped to compress the provided fuel gas.
  • the fuel gas storage system 200 comprises at least one fuel gas storage unit 206.
  • the fuel gas storage unit 206 can preferably be a salt cavern 206.
  • the compressed fuel gas can be fed into the fuel gas storage unit 206 via a storage connection 224 (e.g., with a controllable valve arrangement) of the fuel gas storage unit 206.
  • the fuel gas storage unit 206 is configured to store the compressed fuel gas.
  • the fuel gas storage system 200 comprises at least one fuel gas expansion arrangement 208, configured to expand the fuel gas withdrawn from the fuel gas storage 206.
  • the fuel gas can be withdrawn from the fuel gas storage 206 via the storage connection 224.
  • the fuel gas storage system 200 comprises at least one expansion machine 230.
  • the expansion machine 230 is a turbine device 230 configured to expand the fuel gas extracted from the fuel gas storage 206 and, in particular, still compressed.
  • the expansion machine can be a rotary piston device, a reciprocating piston device, or the like.
  • the fuel gas flowing from the inlet to the outlet of the turbine device 230 causes, in particular, a mechanical movement of a running device of the turbine device 230. This leads to a relaxation of the fuel gas or the fuel gas pressure.
  • FIG 3 shows a schematic view of another preferred embodiment of a fuel gas storage system 300 according to the present application. To avoid repetition, only the differences from the previous embodiment according to Figure 2 described and otherwise referred to the explanations for this embodiment.
  • the generator 334 is configured to generate electrical energy.
  • the generated electrical energy can be fed into an internal power grid 340 (formed by a plurality of electrically conductive lines) and/or into an external (public) power distribution grid 350.
  • the distribution of the electrical energy to the internal power grid 340 and/or the external power distribution grid 350 can be carried out, in particular, by a control device 348 of the fuel gas storage system 300. This can depend, in particular, on the internal power demand and/or the grid status of the external power distribution grid 350.
  • At least one electrical consumer 310, 348 (compressor 310 and control device 348 are shown as electrical consumers by way of example) of the fuel gas storage system 300 can be supplied with the electrical energy generated by the generator 334.
  • the Fuel gas storage system 300 may include at least one rechargeable battery (not shown).
  • the fuel gas storage system 300 in the present case comprises a refrigeration circuit 352.
  • the refrigeration circuit 352 comprises at least one first heat exchanger 336.
  • the first heat exchanger 336 is particularly designed for cooling or cooling a fluid refrigerant (in particular partially fluorinated hydrocarbons) of the refrigeration circuit 352.
  • the cooled refrigerant can be conducted via the internal refrigerant distribution network 342 of the refrigeration circuit 352 to at least one second heat exchanger 338.1, 338.2.
  • the fuel gas compression arrangement 304 comprises the at least one second heat exchanger 338.1, 338.2.
  • a second heat exchanger 338.1, 338.2 is particularly configured to cool the fuel gas flowing through the fuel gas compression arrangement 304.
  • the refrigeration circuit 352 can include at least one first refrigerant reservoir 344.
  • the cooled refrigerant can be temporarily stored in the first refrigerant reservoir 344. If cooling of the fuel gas by a second heat exchanger 338.1, 338.2 is then required (for example, because a fuel gas is currently being compressed), the refrigerant can be provided, in particular, by the first refrigerant reservoir 344 to the second heat exchanger 338.1, 338.2 (in particular, when no expansion of the fuel gas is currently taking place).
  • the refrigeration circuit 352 can include at least one second refrigerant reservoir 346.
  • the fluid refrigerant cannot be cooled by a first heat exchanger 336 at the moment (for example, because no fuel gas is being expanded at the moment)
  • the heated refrigerant can be temporarily stored in the second refrigerant reservoir 346.
  • the refrigerant can then be cooled by a first heat exchanger 336 (for example, because a fuel gas is being expanded at the moment)
  • the refrigerant can be provided, in particular, by the second refrigerant reservoir 346 to the first heat exchanger 336 (in particular, if the fuel gas is not being expanded at the moment).
  • the refrigeration circuit 352 may comprise further components, such as at least one refrigerant compressor (not shown), for example between the second refrigerant storage and the first heat exchanger.
  • the control of the refrigeration circuit 352, in particular the components 336, 344, 338.1, 338.2, 346 (or the various valves not shown) of the refrigeration circuit 352, can be carried out by the control device 348.
  • sensors not shown in the refrigeration circuit e.g. temperature sensors for detecting the Temperature in the refrigerant reservoirs 344, 346, level sensors for detecting the level in the refrigerant reservoirs 344, 346, etc.
  • the control of the refrigeration circuit 352 can depend on this sensor data.
  • control device 348 can be configured to control the storage process and/or the removal process, for example depending on a received control signal or instruction message, for example containing an instruction to store a specific amount of fuel gas, for example within a specific period of time, or to remove a specific amount of fuel gas, for example within a specific period of time.
  • a plurality of sequentially connected expansion working machines in particular turbine devices, can also be implemented in the fuel gas expansion arrangement, in particular in order to maintain a certain pressure level.
  • the Figure 4 shows a schematic view of a preferred embodiment of a turbine device 430 according to the present application for a fuel gas storage system according to the present application, for example as shown in the Figure 2 or Figure 3 is shown.
  • the turbine device 430 is used in particular to carry out a fuel gas pressure relief from a first fuel gas pressure level (upstream of the turbine device 430) to a second, lower fuel gas pressure level (downstream of the turbine device 430), wherein mechanical energy is preferably simultaneously converted into electrical energy by a generator 434 of the turbine device 430 and, in particular, a fluid coolant is cooled by a first heat exchanger 436.
  • the turbine device 430 shown comprises a turbine housing 456 (e.g., made of steel or another metal).
  • the turbine housing 456 is, in particular, substantially tubular. In variants of the application, a different shape may also be provided.
  • the turbine housing 456 has an inlet 468 and an outlet 470.
  • the arrow 472 indicates the flow direction of the fuel gas through the turbine device 430. As can be seen, the fuel gas flows through the turbine housing 456 from the inlet 468 to the outlet 470 essentially without a change in direction.
  • the illustrated turbine device 430 comprises at least one impeller 464 arranged on a turbine shaft 466.
  • the impeller 464 may in particular comprise an impeller having a plurality of impeller blades.
  • the turbine device 430 comprises at least one guide device 462 arranged upstream of the impeller device 464 in the flow direction 472.
  • the guide device 462 can in particular have a plurality of nozzle channels which can in particular impart a swirl to the fuel gas corresponding to the blading of the impeller 464 and preferably accelerate it.
  • the turbine device 430 shown comprises at least one generator 434 coupled to the turbine shaft 466, configured to convert mechanical energy into electrical energy.
  • the kinetic energy of the fuel gas flowing through the turbine device 430 is converted into electrical energy by the rotor device 464, the turbine shaft 466, and the generator 434.
  • the generated electrical energy can, for example, be fed into the described internal power grid or external power distribution grid.
  • the generator 434 is arranged in front of the guide device 462. As already described, the generator 434 can be held or mounted "floating" in the turbine housing 456 by a support 458.
  • the guide device 462 is integrated into the support 458 in this embodiment.
  • the first heat exchanger 436 is arranged downstream of the guide device 462 in the flow direction 472.
  • the thermal energy of the fuel gas flowing through the turbine device 430 is utilized by the first heat exchanger 436.
  • the fluid refrigerant can be cooled in a simple manner.
  • the first heat exchanger 436 can be held or mounted in the turbine housing 456 via a further support 458.
  • the Figure 5 shows a diagram of an embodiment of a method according to the present application.
  • the method is used in particular for operating a fuel gas storage system, as is described, for example, in Figure 2 or 3
  • the method can be carried out in particular under the control of a control device of the fuel gas storage system.
  • a fuel gas is provided from a fuel gas distribution network through at least one fuel gas connection, as previously described.
  • the provided fuel gas is compressed by at least one fuel gas compression arrangement, as previously described.
  • step 504 fuel gas can be removed from the fuel gas storage.
  • step 506 the expanded fuel gas is fed into the fuel gas distribution network through the fuel gas connection, as previously described.
  • Steps 504 to 506 are, in particular, steps of the storage process 508.

Landscapes

  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)

Claims (8)

  1. Système de stockage de gaz combustible (200, 300), comprenant :
    - au moins un raccordement de gaz combustible (222, 322), configuré pour fournir un gaz combustible provenant d'un réseau de distribution de gaz combustible (202, 302),
    - au moins un ensemble de compression de gaz combustible (204, 304) configuré à comprimer le gaz combustible fourni,
    - au moins un réservoir de gaz combustible (206, 306) configuré à stocker le gaz combustible comprimé,
    - au moins un dispositif de détente de gaz combustible (208, 308), configuré pour détendre le gaz combustible prélevé du réservoir de gaz combustible (206, 306),
    - où le raccord de gaz combustible (222, 322) est configuré pour alimenter le réseau de distribution de gaz combustible (202, 302) en gaz combustible détendu,
    - où le dispositif de détente de gaz combustible (208, 308) comprend au moins une machine à détente (230, 330, 430),
    - où la machine à détente (230, 330, 430) comprend au moins un premier échangeur de chaleur (336, 436) configuré pour refroidir un réfrigérant fluide,
    - où l'ensemble de compression de gaz combustible (204, 304) comprend au moins un deuxième échangeur de chaleur (338.1, 338.2) configuré à refroidir le gaz combustible, et
    - le système de stockage de gaz combustible (200, 300) comprend au moins un réseau interne de distribution de réfrigérant (342) configuré pour alimenter au moins partiellement l'au moins un deuxième échangeur de chaleur (338.1, 338.2) avec le réfrigérant fluide refroidi par le premier échangeur de chaleur (336), caractérisé en ce que
    - l'au moins un deuxième échangeur de chaleur (338.1, 338.2) est disposé dans le dispositif de compression de gaz combustible (204, 304) de telle sorte que le gaz combustible fourni est refroidi avant l'au moins un compresseur (310) du dispositif de compression de gaz combustible (204, 304).
  2. Système de stockage de gaz combustible (200, 300) selon la revendication 1,
    caractérisé en ce que
    - le gaz combustible est choisi dans le groupe comprenant : le gaz naturel, le biogaz et l'hydrogène.
  3. Système de stockage de gaz combustible (200, 300) selon la revendication 1 ou 2,
    caractérisé en ce que
    - la machine à détente (230, 330, 430) est un dispositif à turbine (230, 330, 430) et comprend au moins un générateur (334, 434) configuré pour produire de l'énergie électrique.
  4. Système de stockage de gaz combustible (200, 300) selon la revendication 3,
    caractérisé en ce que
    - le système de stockage de gaz combustible (200, 300) comprend un réseau électrique interne (340) configuré pour alimenter au moins partiellement au moins un consommateur électrique (310, 348) du système de stockage de gaz combustible (200, 300) avec de l'énergie électrique générée par le générateur (334, 434).
  5. Système de stockage de gaz combustible (200, 300) selon l'une des revendications précédentes, caractérisé en ce que
    - le deuxième échangeur de chaleur est configuré pour refroidir le gaz combustible fourni par le raccord de gaz combustible à une température d'au moins moins de -10 °C, de préférence inférieure à -15 °C, et de préférence d'au moins moins de - 20 °C.
  6. Système de stockage de gaz combustible (200, 300) selon l'une des revendications précédentes, caractérisé en ce que
    - le système de stockage de gaz combustible (200, 300) comprend au moins un premier accumulateur de réfrigérant (344), configuré pour stocker le réfrigérant fluide refroidi par le premier échangeur de chaleur (336).
  7. Système de stockage de gaz combustible (200, 300) selon l'une des revendications précédentes, caractérisé en ce que
    - le système de stockage de gaz combustible (200, 300) comprend au moins un deuxième accumulateur de réfrigérant fluide (346), configuré pour stocker le réfrigérant fluide chauffé par l'au moins un deuxième échangeur de chaleur (338.1, 338.2).
  8. Procédé d'exploitation d'un système de stockage de gaz combustible (200, 300), en particulier d'un système de stockage de gaz combustible (200, 300) selon l'une des revendications précédentes, comprenant:
    - fournir, par au moins un raccordement de gaz combustible (222, 322), d'un gaz combustible provenant d'un réseau de distribution de gaz combustible (202, 302),
    - comprimer, par au moins un dispositif de compression de gaz combustible (204, 304), le gaz combustible fourni,
    - stocker, par au moins un réservoir de gaz combustible (206, 306), le gaz combustible comprimé,
    - détendre, par au moins une machine de détente (230, 330, 430) d'au moins un ensemble de détente de gaz combustible (208, 308), le gaz combustible prélevé du réservoir de gaz combustible (206, 306), et
    - alimenter le réseau de distribution de gaz combustible (202, 302) en gaz combustible détendu par le raccord de gaz combustible (222, 322),
    - où le dispositif de détente de gaz combustible (208, 308) comprend au moins une machine à détente (230, 330, 430),
    - refroidir, par un premier échangeur de chaleur (336, 436) de la machine à détente (230, 330, 430), un réfrigérant fluide,
    - refroidir, par au moins un deuxième échangeur de chaleur (338.1, 338.2), le dispositif de compression de gaz combustible (204, 304) du gaz combustible, et
    - alimenter, par un réseau interne de distribution de réfrigérant (342) du système de stockage de gaz combustible (200, 300), le au moins un deuxième échangeur de chaleur (338.1, 338.2) au moins partiellement avec le réfrigérant fluide refroidi par le premier échangeur de chaleur (336),
    - où l'au moins un deuxième échangeur de chaleur (338.1, 338.2) est disposé dans le dispositif de compression de gaz combustible (204, 304) de telle sorte que le gaz combustible fourni est refroidi avant l'au moins un compresseur (310) du dispositif de compression de gaz combustible (204, 304).
EP23188888.4A 2022-08-31 2023-08-01 Système de stockage de gaz combustible Active EP4332423B1 (fr)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
DE102022122057.5A DE102022122057A1 (de) 2022-08-31 2022-08-31 Brenngasspeichersystem

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EP4332423A1 EP4332423A1 (fr) 2024-03-06
EP4332423B1 true EP4332423B1 (fr) 2025-10-01
EP4332423C0 EP4332423C0 (fr) 2025-10-01

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DE (1) DE102022122057A1 (fr)

Family Cites Families (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JP5839546B2 (ja) * 2011-06-30 2016-01-06 株式会社神戸製鋼所 水素ステーション
US9383105B2 (en) * 2012-07-30 2016-07-05 Apex Compressed Air Energy Storage, Llc Compressed air energy storage system having variable generation modes
US9803803B1 (en) * 2014-06-20 2017-10-31 Northwest Natural Gas Company System for compressed gas energy storage
EP3421865A4 (fr) * 2016-02-23 2019-10-30 Hitachi Plant Mechanics Co. Ltd. Turbine de détente et système de remplissage d'hydrogène haute pression de type compresseur, et procédé de commande pour celui-ci
WO2018161172A1 (fr) * 2017-03-09 2018-09-13 Hydrostor Inc. Appareil de stockage thermique pour système de stockage d'énergie à gaz comprimé

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EP4332423A1 (fr) 2024-03-06
DE102022122057A1 (de) 2024-02-29

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