CN114423691A - System installed on board a ship for treating gas contained in tanks for storing and/or transporting liquid and gaseous gases - Google Patents

System installed on board a ship for treating gas contained in tanks for storing and/or transporting liquid and gaseous gases Download PDF

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Publication number
CN114423691A
CN114423691A CN202080066480.5A CN202080066480A CN114423691A CN 114423691 A CN114423691 A CN 114423691A CN 202080066480 A CN202080066480 A CN 202080066480A CN 114423691 A CN114423691 A CN 114423691A
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CN
China
Prior art keywords
gas
tank
heat exchanger
gaseous
natural gas
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Pending
Application number
CN202080066480.5A
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Chinese (zh)
Inventor
R.纳姆
B.奥恩
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.)
Gaztransport et Technigaz SA
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Gaztransport et Technigaz SA
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Filing date
Publication date
Application filed by Gaztransport et Technigaz SA filed Critical Gaztransport et Technigaz SA
Publication of CN114423691A publication Critical patent/CN114423691A/en
Pending legal-status Critical Current

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    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B25/00—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby
    • B63B25/02—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby for bulk goods
    • B63B25/08—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby for bulk goods fluid
    • B63B25/12—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby for bulk goods fluid closed
    • B63B25/16—Load-accommodating arrangements, e.g. stowing, trimming; Vessels characterised thereby for bulk goods fluid closed heat-insulated
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B65—CONVEYING; PACKING; STORING; HANDLING THIN OR FILAMENTARY MATERIAL
    • B65D—CONTAINERS FOR STORAGE OR TRANSPORT OF ARTICLES OR MATERIALS, e.g. BAGS, BARRELS, BOTTLES, BOXES, CANS, CARTONS, CRATES, DRUMS, JARS, TANKS, HOPPERS, FORWARDING CONTAINERS; ACCESSORIES, CLOSURES, OR FITTINGS THEREFOR; PACKAGING ELEMENTS; PACKAGES
    • B65D90/00—Component parts, details or accessories for large containers
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63B—SHIPS OR OTHER WATERBORNE VESSELS; EQUIPMENT FOR SHIPPING 
    • B63B11/00—Interior subdivision of hulls
    • B63B11/04—Constructional features of bunkers, e.g. structural fuel tanks, or ballast tanks, e.g. with elastic walls
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B63—SHIPS OR OTHER WATERBORNE VESSELS; RELATED EQUIPMENT
    • B63H—MARINE PROPULSION OR STEERING
    • B63H21/00—Use of propulsion power plant or units on vessels
    • B63H21/38—Apparatus or methods specially adapted for use on marine vessels, for handling power plant or unit liquids, e.g. lubricants, coolants, fuels or the like
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B65—CONVEYING; PACKING; STORING; HANDLING THIN OR FILAMENTARY MATERIAL
    • B65D—CONTAINERS FOR STORAGE OR TRANSPORT OF ARTICLES OR MATERIALS, e.g. BAGS, BARRELS, BOTTLES, BOXES, CANS, CARTONS, CRATES, DRUMS, JARS, TANKS, HOPPERS, FORWARDING CONTAINERS; ACCESSORIES, CLOSURES, OR FITTINGS THEREFOR; PACKAGING ELEMENTS; PACKAGES
    • B65D88/00—Large containers
    • B65D88/54—Large containers characterised by means facilitating filling or emptying
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B65—CONVEYING; PACKING; STORING; HANDLING THIN OR FILAMENTARY MATERIAL
    • B65D—CONTAINERS FOR STORAGE OR TRANSPORT OF ARTICLES OR MATERIALS, e.g. BAGS, BARRELS, BOTTLES, BOXES, CANS, CARTONS, CRATES, DRUMS, JARS, TANKS, HOPPERS, FORWARDING CONTAINERS; ACCESSORIES, CLOSURES, OR FITTINGS THEREFOR; PACKAGING ELEMENTS; PACKAGES
    • B65D88/00—Large containers
    • B65D88/74—Large containers having means for heating, cooling, aerating or other conditioning of contents
    • B65D88/744—Large containers having means for heating, cooling, aerating or other conditioning of contents heating or cooling through the walls or internal parts of the container, e.g. circulation of fluid inside the walls
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B67—OPENING, CLOSING OR CLEANING BOTTLES, JARS OR SIMILAR CONTAINERS; LIQUID HANDLING
    • B67D—DISPENSING, DELIVERING OR TRANSFERRING LIQUIDS, NOT OTHERWISE PROVIDED FOR
    • B67D9/00—Apparatus or devices for transferring liquids when loading or unloading ships
    • 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
    • F17C1/002—Storage in barges or on ships
    • 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
    • F17C13/00—Details of vessels or of the filling or discharging of vessels
    • F17C13/004—Details of vessels or of the filling or discharging of vessels for large storage vessels not under 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
    • F17C7/00—Methods or apparatus for discharging liquefied, solidified, or compressed gases from pressure vessels, not covered by another subclass
    • 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
    • F17C9/00—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure
    • F17C9/02—Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure with change of state, e.g. vaporisation
    • F17C9/04—Recovery of thermal energy
    • 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
    • F17D1/065—Arrangements for producing propulsion of gases or vapours
    • F17D1/07—Arrangements for producing propulsion of gases or vapours by compression
    • 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
    • F17D1/08—Pipe-line systems for liquids or viscous products
    • 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
    • F17D1/08—Pipe-line systems for liquids or viscous products
    • F17D1/16—Facilitating the conveyance of liquids or effecting the conveyance of viscous products by modification of their viscosity
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D3/00—Arrangements for supervising or controlling working operations
    • F17D3/01—Arrangements for supervising or controlling working operations for controlling, signalling, or supervising the conveyance of a product
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/0002—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the fluid to be liquefied
    • F25J1/0022—Hydrocarbons, e.g. natural gas
    • F25J1/0025—Boil-off gases "BOG" from storages
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/003—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production
    • F25J1/0032—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using the feed stream itself or separated fractions from it, i.e. "internal refrigeration"
    • F25J1/0045—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the kind of cold generation within the liquefaction unit for compensating heat leaks and liquid production using the feed stream itself or separated fractions from it, i.e. "internal refrigeration" by vaporising a liquid return stream
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F25J1/0201—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process using only internal refrigeration means, i.e. without external refrigeration
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F25J1/0228—Coupling of the liquefaction unit to other units or processes, so-called integrated processes
    • F25J1/0229—Integration with a unit for using hydrocarbons, e.g. consuming hydrocarbons as feed stock
    • F25J1/023—Integration with a unit for using hydrocarbons, e.g. consuming hydrocarbons as feed stock for the combustion as fuels, i.e. integration with the fuel gas system
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F25J1/0243—Start-up or control of the process; Details of the apparatus used; Details of the refrigerant compression system used
    • F25J1/0244—Operation; Control and regulation; Instrumentation
    • F25J1/0245—Different modes, i.e. 'runs', of operation; Process control
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
    • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
    • F25J1/0243—Start-up or control of the process; Details of the apparatus used; Details of the refrigerant compression system used
    • F25J1/0257—Construction and layout of liquefaction equipments, e.g. valves, machines
    • F25J1/0275—Construction and layout of liquefaction equipments, e.g. valves, machines adapted for special use of the liquefaction unit, e.g. portable or transportable devices
    • F25J1/0277—Offshore use, e.g. during shipping
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F28—HEAT EXCHANGE IN GENERAL
    • F28D—HEAT-EXCHANGE APPARATUS, NOT PROVIDED FOR IN ANOTHER SUBCLASS, IN WHICH THE HEAT-EXCHANGE MEDIA DO NOT COME INTO DIRECT CONTACT
    • F28D21/00—Heat-exchange apparatus not covered by any of the groups F28D1/00 - F28D20/00
    • 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
    • F17C2223/0146—Two-phase
    • F17C2223/0153—Liquefied gas, e.g. LPG, GPL
    • F17C2223/0161—Liquefied gas, e.g. LPG, GPL cryogenic, e.g. LNG, GNL, 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
    • F17C2223/0146—Two-phase
    • F17C2223/0153—Liquefied gas, e.g. LPG, GPL
    • F17C2223/0169—Liquefied gas, e.g. LPG, GPL subcooled
    • 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
    • F17C2223/033—Small pressure, e.g. for liquefied 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
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/04—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by other properties of handled fluid before transfer
    • F17C2223/042—Localisation of the removal point
    • F17C2223/043—Localisation of the removal point in the 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
    • F17C2223/00—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/04—Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by other properties of handled fluid before transfer
    • F17C2223/042—Localisation of the removal point
    • F17C2223/046—Localisation of the removal point in the liquid
    • F17C2223/047—Localisation of the removal point in the liquid with a dip tube
    • 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
    • F17C2225/00—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel
    • F17C2225/01—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel characterised by the phase
    • F17C2225/0107—Single phase
    • F17C2225/0123—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
    • F17C2225/00—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel
    • F17C2225/01—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel characterised by the phase
    • F17C2225/0146—Two-phase
    • F17C2225/0153—Liquefied gas, e.g. LPG, GPL
    • F17C2225/0161—Liquefied gas, e.g. LPG, GPL cryogenic, e.g. LNG, GNL, 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
    • F17C2225/00—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel
    • F17C2225/01—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel characterised by the phase
    • F17C2225/0146—Two-phase
    • F17C2225/0153—Liquefied gas, e.g. LPG, GPL
    • F17C2225/0169—Liquefied gas, e.g. LPG, GPL subcooled
    • 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
    • F17C2225/00—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel
    • F17C2225/03—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel characterised by the pressure level
    • F17C2225/033—Small pressure, e.g. for liquefied 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
    • F17C2225/00—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel
    • F17C2225/04—Handled fluid after transfer, i.e. state of fluid after transfer from the vessel characterised by other properties of handled fluid after transfer
    • F17C2225/042—Localisation of the filling point
    • F17C2225/046—Localisation of the filling point in the liquid
    • F17C2225/047—Localisation of the filling point in the liquid with a dip tube
    • 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
    • F17C2227/01—Propulsion of the fluid
    • F17C2227/0128—Propulsion of the fluid with pumps or compressors
    • F17C2227/0157—Compressors
    • 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
    • F17C2227/0306—Heat exchange with the fluid by heating using the same 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
    • F17C2227/0327—Heat exchange with the fluid by heating with recovery of heat
    • 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
    • F17C2227/0367—Localisation of heat exchange
    • F17C2227/0369—Localisation of heat exchange in or on a vessel
    • F17C2227/0374—Localisation of heat exchange in or on a vessel in the liquid
    • 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
    • F17C2227/0367—Localisation of heat exchange
    • F17C2227/0388—Localisation of heat exchange separate
    • 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
    • F17C2227/04—Methods for emptying or filling
    • F17C2227/047—Methods for emptying or filling by repeating a process cycle
    • 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
    • F17C2260/031—Dealing with losses due to heat transfer
    • 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
    • F17C2260/04—Reducing risks and environmental impact
    • F17C2260/046—Enhancing energy recovery
    • 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
    • F17C2265/03—Treating the boil-off
    • F17C2265/032—Treating the boil-off by recovery
    • F17C2265/033—Treating the boil-off by recovery with cooling
    • 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
    • F17C2265/03—Treating the boil-off
    • F17C2265/032—Treating the boil-off by recovery
    • F17C2265/037—Treating the boil-off by recovery with pressurising
    • 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
    • F17C2270/0102—Applications for fluid transport or storage on or in the water
    • F17C2270/0105—Ships
    • F17C2270/0107—Wall panels
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2205/00—Processes or apparatus using other separation and/or other processing means
    • F25J2205/90—Mixing of components
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
    • F25J2230/24—Multiple compressors or compressor stages in parallel
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
    • F25J2230/30—Compression of the feed stream
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2290/00—Other details not covered by groups F25J2200/00 - F25J2280/00
    • F25J2290/34—Details about subcooling of liquids
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2290/00—Other details not covered by groups F25J2200/00 - F25J2280/00
    • F25J2290/62—Details of storing a fluid in a tank
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02T—CLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO TRANSPORTATION
    • Y02T70/00—Maritime or waterways transport
    • Y02T70/50—Measures to reduce greenhouse gas emissions related to the propulsion system
    • Y02T70/5218—Less carbon-intensive fuels, e.g. natural gas, biofuels

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  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Thermal Sciences (AREA)
  • Physics & Mathematics (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Ocean & Marine Engineering (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Water Supply & Treatment (AREA)
  • Public Health (AREA)
  • Health & Medical Sciences (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)

Abstract

The invention relates to a system (100) for treating gas contained in a tank (200) for storing and/or transporting liquid and gaseous gas, said system being installed on a ship, said system (100) comprising at least: a heat exchanger (110) configured to exchange heat between gas withdrawn in a gaseous state from the tank (200) and compressed gas from the tank (200); a compression member (120) configured to compress the gaseous gas from the heat exchanger (110); a gas consumption device (130, 131) consuming gaseous gas and configured to be supplied with compressed gas; a first conduit (101) connecting the compression member (120) to a gas consumption device (130, 131) consuming gaseous gas; a second pipe (102) connecting the first pipe (101) to an inlet of the heat exchanger (110); a third conduit (103) connecting an outlet (116) of the heat exchanger (110) to a bottom of the tank (200); a frothing member (140) connected to the third conduit (103) and configured to distribute gaseous gas from the heat exchanger (110) into the bottom of the tank (200).

Description

System installed on board a ship for treating gas contained in tanks for storing and/or transporting liquid and gaseous gases
Technical Field
The invention relates to the field of ships whose propulsion engines are supplied with natural gas and which are also capable of containing or transporting liquefied natural gas.
Background
Such ships therefore usually comprise tanks filled with liquefied natural gas. Natural gas is liquid at temperatures below-160 ℃ when at atmospheric pressure. These tanks are never completely insulated, which means that at least some of the natural gas is vaporized therein. Thus, these tanks contain both liquid and gaseous natural gas. This gaseous natural gas forms a blanket over the top of the tank and the pressure at this top of the tank needs to be controlled to avoid damaging the tank. It is known that at least some of the natural gas present in gaseous form in the tanks is therefore used to supply the engines or the like that propel the ship.
However, when the ship is stationary, the consumption of gaseous natural gas by these engines is zero, or close to zero, and the natural gas present in the tank in the gaseous state is no longer consumed by these engines. A reliquefaction system allowing condensation of the boiled-off natural gas present in the tank is therefore installed on board the vessel in order to return the gas in liquid form to the tank.
The reliquefaction systems currently in use are very expensive and the present invention seeks to overcome this disadvantage by proposing a system for treating gases which comprises fewer components than the existing systems, so that the operating costs of such systems can be reduced while at least operating well.
Disclosure of Invention
One subject of the present invention is therefore a system for treating a gas contained in a tank for storing and/or transporting liquid and gaseous gases, the tank being installed on a ship, the system comprising at least:
-a heat exchanger configured to exchange heat between the gas withdrawn in the gaseous state from the tank and the compressed gas coming from the tank,
a compression member configured to compress the gaseous gas from the heat exchanger,
a gas consumption device, consuming gaseous gas and configured to be supplied with compressed gas,
a first conduit connecting the compression member to a gas consuming device consuming gaseous gas,
a second conduit connecting the first conduit to an inlet aperture of the heat exchanger,
a third conduit connecting the outlet opening of the heat exchanger to the bottom of the tank,
-a bubbling member connected to the third conduit and configured to distribute the gaseous gas from the heat exchanger to the bottom of the tank.
By "bottom of a can" is meant a portion of the can which extends from the bottom wall of the can and a plane parallel to the bottom wall and which is located at most 20% of the total height of the can, measured along a line perpendicular to the bottom wall of the can between two opposite ends of the can along the line. Advantageously, the plane parallel to the bottom wall and contributing to define the "bottom of the tank" may be located at 10% of the total height of the tank. Alternatively, the frothing member can be fixed to the bottom wall of the can. As can be understood from the above, the heat exchanger is configured to exchange heat between the boil-off gas withdrawn from the tank and the gas compressed by the compression member. In other words, the heat exchanger comprises at least one first channel and at least one second channel, the inlet opening of the first channel being connected to the tank, the outlet opening of the first channel being connected to the compression member, the inlet opening of the second channel being connected to the compression member, the outlet opening of the second channel being connected to the tank. According to the invention, the frothing member is more particularly configured to generate bubbles and to disperse these bubbles in the bottom of the tank. These bubbles then come into contact with the liquid gas in the tank. The temperature difference between these bubbles and the liquid gas present in the tank causes these bubbles to condense.
According to one feature of the invention, the gas treatment system comprises expansion means and a heat exchanger provided with at least one first channel supplied with the gas drawn out of the tank in liquid state and at least one second channel supplied with the gas drawn out of the tank in liquid state, and the expansion means are arranged between the tank and the first channel of the heat exchanger.
In other words, it will be understood that the liquid gas supplied to the first channel undergoes expansion, that is to say its pressure is reduced, before reaching this first channel, while the liquid gas fed into the second channel of the heat exchanger reaches this second channel immediately after leaving the tank, that is to say without undergoing any change in pressure or temperature, except for the changes associated with the pumping itself. In other words, it should be understood that the heat exchanger is configured to exchange heat between an expanded liquid gas and an unexpanded liquid gas. For example, the expanded liquid gas may be expanded to a pressure below atmospheric pressure. Advantageously, the pressure difference and the temperature difference between the liquid gas circulating in the first channel and the liquid gas circulating in the second channel allow the liquid gas circulating in the first channel to vaporize and the liquid gas circulating in the second channel to be cooled. For example, the outlet aperture of the second passage of the heat exchanger may be fluidly connected to the tank such that liquid gas cooled by the second passage of the heat exchanger may be returned to the tank. It will be appreciated that the injection of the liquid gas thus cooled helps to maintain a stable temperature in the tank, thus limiting the phenomenon of vaporization of the liquid gas contained in the tank.
According to the invention, the frothing member can comprise, for example, at least one boom provided with a hole for generating the gas bubble. Advantageously, the holes are distributed over the entire length of the boom, that is to say the longest dimension of the boom, allowing the bubbles produced to be distributed evenly in the bottom of the tank.
According to an exemplary embodiment of the invention, the holes of the hanger bar each have a diameter of 0.0078mm2To 315mm2Cross section in between. Advantageously, such a cross section enables the generation of bubbles small enough to condense rapidly, mixing rapidly with the liquid gas contained in the tank.
According to one feature of the invention, at least one expansion member is disposed on the first conduit. In other words, it will be appreciated that the gas leaving the compression member expands before reaching the heat exchanger, thereby significantly facilitating the heat exchange taking place in this heat exchanger. Alternatively, the natural gas may reach the heat exchanger without being expanded, that is, the natural gas then reaches the frothing member at a higher pressure than it undergoes expansion before reaching the heat exchanger.
According to the invention, the gas treatment system may comprise a compression device arranged in parallel with the compression member, the compression member being configured to compress a first portion of the gaseous gas from the heat exchanger, the compression device being configured to compress a second portion of the gaseous gas from the heat exchanger, the first portion of the gas from the heat exchanger being different from the second portion of the gas from the heat exchanger. Alternatively, compression is not available to mitigate potential failure of the compression member.
For example, the gas stored and/or transported in the tank is natural gas. Alternatively, the gas treatment system according to the invention may be used for other types of gas, such as gaseous hydrocarbons or hydrogen.
According to an exemplary embodiment of the invention, the gas treatment system comprises at least one first gas consumer and at least one second gas consumer, the first gas consumer being configured to be supplied with compressed gas at a first pressure, the second gas consumer being configured to be supplied with compressed gas at a second pressure, and the first pressure being lower than the second pressure. For example, the first gas consuming device is a generator of the DFDE (dual fuel diesel electric) type, which is a gas consuming device configured to provide electrical power to the ship, and the second gas consuming device may be an engine for propelling the ship, such as an ME GI or X DF engine.
The invention also relates to a ship for transporting liquefied gas, which ship comprises at least one tank for liquefied gas cargo, at least one gas consumption device for consuming vaporized gas, and at least one gas treatment system as described above.
The invention also relates to a system for loading or unloading liquid gas, which system incorporates at least one onshore device and at least one liquid gas carrier according to the invention.
The invention also relates to a method comprising at least the following steps:
-withdrawing gaseous gases from the tank,
-heating the gas withdrawn from the tank in gaseous state by heat exchange in a heat exchanger with the gas compressed by the compression means,
-compressing the heated gas using a compression member,
-supplying a first portion of the heated and compressed gas to at least one gas consuming device consuming boil-off gas,
-cooling the second part of the heated and compressed gas by heat exchange in a heat exchanger with the gas withdrawn in gaseous state from the tank,
-distributing the second portion of gas cooled by passing it through the heat exchanger to the bottom of the tank.
According to the invention, the step of dispensing the second portion of the cooling gas comprises bubbling the second portion of the cooling gas.
According to one feature of the invention, the pressure at the inlet of the third conduit is higher than the pressure measured at the bottom of the tank.
The gas treatment process according to the invention may also comprise at least one step of subcooling the natural gas withdrawn from the tank in the liquid state and at least one step of storing the subcooled natural gas in the bottom of the tank. According to the invention, the subcooling step is carried out by heat exchange between natural gas withdrawn from the tank in the liquid state and maintained at atmospheric pressure and natural gas withdrawn from the tank in the liquid state and expanded to below atmospheric pressure. In other words, as can be understood from the foregoing, the step of subcooling the natural gas withdrawn in liquid form from the tank is carried out in the above-mentioned heat exchanger.
Advantageously, the step of subcooling the natural gas withdrawn from the tank in the liquid state, the step of storing the subcooled natural gas in the bottom of the tank and the step of distributing at the bottom of the tank the second portion of the gas cooled by passing it through the heat exchanger are carried out at least twice in succession in this order. As previously mentioned, the steps of subcooling and storing the subcooled liquefied natural gas allow the temperature of the natural gas present in the liquid state in the tank to be reduced. The step of distributing the second portion of the cooled gas tends to increase the temperature of the natural gas present in liquid form in the tank. In other words, the steps of subcooling and storing the subcooled natural gas can be used to maintain the temperature of the liquid natural gas contained in the tank, in order to prevent the vaporization of too large an amount of this liquefied natural gas during the step of distributing the gas to the bottom of the tank, since too much vaporization would lead to an increase in the amount of gaseous natural gas present in the top of the tank and therefore to an increase in the pressure in the tank, which would eventually damage the tank. Thus, the steps of subcooling, storing and dispensing of the natural gas in the tank contribute to the stabilization of the pressure in the tank.
The invention finally relates to a method for loading or unloading liquid gas to or from a gas carrier according to the invention.
Drawings
Further features, details and advantages of the invention will become more apparent, on the one hand, from reading the following description and, on the other hand, from giving exemplary embodiments in a non-limiting manner with reference to the accompanying drawings, in which:
FIG. 1 schematically illustrates a gas treatment system according to the present invention;
FIG. 2 schematically illustrates a first mode of operation of the gas treatment system of FIG. 1;
FIG. 3 schematically illustrates a second mode of operation of the gas treatment system of FIG. 1;
FIG. 4 schematically illustrates a third mode of operation of the gas treatment system of FIG. 1;
fig. 5 is a schematic cross-sectional view of a tank of a methane carrier and a quay for loading and/or unloading the tank.
Detailed Description
For the remainder of the description, the terms "upstream" and "downstream" refer to the direction of circulation of a gas in liquid, gaseous or two-phase state through the relevant element. In fig. 2 to 4, a solid line indicates a circuit pipe through which gas flows in a liquid, gaseous or two-phase state, and a dotted line indicates a circuit pipe through which gas does not flow.
Fig. 1 to 4 show a system 100 for treating liquid and gaseous gases contained in a tank 200, and various modes of operation of the gas treatment system 100. In the following description, the space occupied by the gaseous gas in the tank 200 is referred to as "the top of the tank 201". The system 100 according to the invention will first be described with reference to fig. 1, the system 100 being in a state of rest, that is to say without gas circulation, whether in a gaseous, liquid or two-phase state. Three different modes of operation of the gas treatment system 100 according to the invention will then be described with reference to fig. 2 to 4, distinguishing a first mode of operation called "equilibrium", a second mode of operation called "forced vaporisation" and a third mode of operation called "reliquefaction". For the remainder of the description, the terms "gas treatment system 100" and "system 100" will be used indiscriminately.
The following description gives one specific example of an application of the invention, in which the tank 200 contains natural gas. It must be understood that this is only an example of an application and that the gas treatment system 100 according to the invention may be used for other types of gases, such as gaseous hydrocarbons or hydrogen.
Fig. 1 first schematically shows a system 100 according to the invention for treating a gas contained in a tank 200, the system being in a state of rest. According to the invention, the system 100 comprises at least one heat exchanger 110, at least one compression member 120, at least one gas consuming device 130 and at least one frothing member 140. According to the example shown here, the system 100 further comprises a compression device 121, a compression means 122, a heat exchanger 170 and another gas consuming apparatus 131.
As shown, at least a first conduit 101 is arranged between the compression member 120 and the gas consumer 130, at least a second conduit 102 is arranged between the first conduit 101 and the heat exchanger 110, and at least a third conduit 103 is arranged between the heat exchanger 110 and the bottom of the tank, that is to say the part of the tank extending from the bottom wall 202 of the tank 200 and a plane parallel to this bottom wall, and is positioned at most at 20% of the total height h of the tank, measured along a line perpendicular to the bottom wall of the tank between two opposite ends of the tank along this line. Advantageously, the plane parallel to the bottom wall of the tank, which helps to define the "bottom of the tank", may be located at 10% of the total height h of the tank. Alternatively, the frothing member can be fixed to the bottom wall 202 of the tank.
It must also be noted that the heat exchanger 110 comprises at least one first channel 111 connected on the one hand to the tank 200, more particularly to the top of the tank 201, and on the other hand to the compression member 120, and at least one second channel 112, itself connected on the one hand to the compression member 120 and on the other hand to the tank 200. More specifically, the inlet hole 113 of the first channel 111 is connected to the top of the tank 201 by the fourth pipe 104, the outlet hole 114 of the first channel 111 is connected to the compression member 120 by the fifth pipe 105, the inlet hole 115 of the second channel 112 is itself connected to the compression member 120 by the second pipe 102, and the outlet hole 116 of the second channel 112 is connected to the bottom of the tank 200 by the third pipe 103. in other words, it should be understood that the first channel 111 of the heat exchanger 110 passes gaseous natural gas extracted from the tank 200, more specifically from the top of the tank 201, and that the second channel 112 of the heat exchanger 110 passes natural gas extracted from the tank 200, more specifically from the top of the tank 201, which is then compressed by the compression member 120. In other words, the heat exchanger 110 is configured to exchange heat between the gas that is withdrawn in a gaseous state from the top of the tank 201 and is directly fed into the heat exchanger 110 and the gas that is withdrawn in a gaseous state from the top of the tank 201 and is at least partially compressed by the compression member 120 ". By feeding directly into heat exchanger 110 ", it is meant that the natural gas extracted in the gaseous state does not undergo other pressure or temperature changes than those associated with its extraction, before it reaches heat exchanger 110, and more particularly first passage 111 of heat exchanger 110. It will also be noted that there is a valve 150 on the second conduit 102, i.e. between the first conduit 101 and the heat exchanger 110. Alternatively, the valve 150 may be located downstream of the heat exchanger 110, that is to say arranged on the third conduit 103. The valve 150 thus controls the supply of gaseous natural gas to the second passage 112 of the heat exchanger 110.
Furthermore, the third tube 103 is connected to a frothing member 140, the frothing member 140 extending at the bottom of the tank. According to the example shown here, the frothing member 140 comprises a boom 141 provided with an aperture 142, the aperture 142 being configured to generate bubbles 143 of natural gas. For example, each of the holes 142 has 0.0078mm2To 315mm2Cross section in between. As will be described in greater detail hereinafter, in particular with reference to the third operating mode of the system 100 according to the invention, these natural gas bubbles 143 are therefore mixed with the liquid natural gas present in the tank 200, which allows the gaseous natural gas forming these bubbles 143 to condense and therefore return to the liquid state.
Both the compression member 120 and the compression means 121 are connected to the same elements of the system 100, that is to say they are connected to the first channel 111 of the heat exchanger 110 by means of a fifth conduit 105, on the one hand to a first gas consumer 130 by means of the first conduit 101 and on the other hand to a second gas consumer 131 by means of a sixth conduit 106. More specifically, it should be noted that the gaseous natural gas compressed by the compression member 120 and the gaseous natural gas compressed by the compression device 121 may be mixed in a single pipeline, which then separately reaches the first or second gas consuming apparatus 130, 131. For example, the first gas consumer 130 is a generator of the DFDE (dual fuel diesel electric) type, that is to say configured to provide electrical power to the ship, and the second gas consumer 131 may be an engine for propelling the ship, for example an ME GI or X DF engine. It must be understood that this is only an exemplary embodiment of the invention, and that different gas-consuming apparatuses may be installed without departing from the invention. In addition, a sixth conduit 106 is also fluidly connected to the second conduit 102. In other words, a portion of the compressed natural gas for supply to the second gas consuming device 131 may be diverted to be supplied to the second channel 112 of the heat exchanger 110. In order to control this transfer of compressed natural gas for supplying the second gas consumer 131, a valve 151 is installed between the sixth pipeline 106 and the heat exchanger 110.
According to various application examples of the present invention, it may be provided that only the compression member 120 is present, the compression means 121 providing redundancy, that is, if the compression member 120 fails, the compression means 121 can replace the compression member 120. Alternatively, it may be provided that the compression means 120 and the compression device 121 are present simultaneously, i.e. a first portion of the natural gas from the heat exchanger 110 is then compressed by the compression means and a second portion of the natural gas from the heat exchanger 110 is then compressed by the compression device 121, the first and second portions of the natural gas from the heat exchanger being different.
According to any of these application examples, the natural gas reaches the compression member 120 and/or the compression device 121 in gaseous state and at a pressure of about 1bar, and it leaves the compression member 120 and/or the compression device 121 in gaseous state and at high pressure, that is to say at a pressure of between 1bar and 400bar, advantageously between 1bar and 17bar, and more advantageously between 6bar and 17 bar. The compression level at the outlet of the compression member 120 and/or the compression means 121 is determined according to the type of gas consuming device to be supplied.
Furthermore, an expansion member 181 may be arranged on the first conduit 101, and more particularly between the compression member 120 and the second conduit 102, in order to expand the natural gas leaving the compression member 120 and/or the compression device 121 before it reaches the heat exchanger 110, in which heat exchanger 110, as will be described in more detail below, the compressed natural gas releases thermal energy to the gaseous natural gas sent directly to the heat exchanger 110 from the top of the tank 201. It will also be noted that the sixth conduit 106 is free of expansion members. In other words, when the valve 151 located between the sixth conduit 106 and the heat exchanger 110 is opened to feed the second passage 112 of the heat exchanger 110, the pressure of the natural gas fed to the second passage 112 is between 1bar and 400bar, advantageously between 1bar and 17bar, more advantageously between 6bar and 17 bar. In other words, the opening of the valve 151 located between the sixth pipeline 106 and the heat exchanger 110 allows the frothing member 140 to be supplied with high-pressure natural gas. Therefore, it should be understood that the valve 150 disposed on the second conduit 102 and the valve 151 disposed between the sixth conduit 106 and the heat exchanger 110 are never simultaneously opened.
The heat exchanger 170 itself also includes a first channel 171 and a second channel 172. As shown, the first channel 171 is connected on the one hand to a first pump 210 arranged in the bottom of the tank 200 and on the other hand to the compression means 122, and the second channel 172 is itself connected on the one hand to a second pump 220 arranged in the bottom of the tank 200 and on the other hand also to the tank 200, more precisely to a portion of the tank 200 in which the natural gas is stored in liquid form. More specifically, the inlet hole 173 of the first passage 171 is connected to the first pump 210, the outlet hole 174 of the first passage 171 is connected to the compression device 122, the inlet hole 175 of the second passage 172 is connected to the second pump 220, and the outlet hole 176 of the second passage 172 is connected to the tank 200. Here, "connected to the tank" means that the seventh pipe 107 is connected to the outlet hole of the second passage 172 of the heat exchanger 170, and the seventh pipe 107 is open to the tank 200. According to an exemplary embodiment not shown here, the first channel and the second channel of the heat exchanger may both be fed by one and the same pump, so that a bifurcation is formed between the single pump and the inlet orifices of the first channel and of the second channel of the heat exchanger.
Further, an expansion device 182 is disposed between the first pump 210 and the heat exchanger 170. In other words, the gas drawn in liquid form from the tank 200 by the first pump 210 is expanded before it reaches the first passage 171 of the heat exchanger 170. By "expanded" is meant that the pressure of the liquefied natural gas is reduced. In other words, the natural gas drawn from the tank in liquid form by the first pump 210 reaches the heat exchanger 170 at a pressure below atmospheric pressure. Note that, instead, the second pump 220 is configured to send the natural gas extracted in liquid form from the tank 200 directly into the second passage 172 of the heat exchanger 170, which means that the natural gas extracted in liquid form from the tank 200 does not undergo any temperature or pressure changes, other than the temperature or pressure changes associated with the pumping itself, before reaching the second passage 172 of the heat exchanger 170. The heat exchanger 170 is therefore configured to exchange heat between the gas withdrawn from the tank 200 in the liquid state and having undergone expansion and the gas withdrawn from the tank in the liquid state and not undergoing any pressure change. According to an embodiment not shown, in which the first and second channels of the heat exchanger are fed by the same pump, the expansion device is located downstream of the bifurcation, that is to say between the bifurcation and the first channel of the heat exchanger. Thus, as can be seen from the foregoing, the lng circulating in the first passage 171 is heated to the vaporization point, while the lng circulating in the second passage 172 is subcooled before returning to the bottom of the tank 200.
As described above, the liquefied natural gas circulates in the first passage 171 of the heat exchanger 170 at a pressure lower than atmospheric pressure. Thus, to ensure that the liquefied natural gas does flow, the compression device 122 located between the heat exchanger 170 and the compression member 120 is configured to return the natural gas exiting the heat exchanger 170 to a pressure near atmospheric pressure. For example, the compression device 122 is configured to compress natural gas from 0.35bar to 1 bar. The so compressed natural gas can then reach the compression member 120 and/or the compression device 121, undergoing a second compression in one or each.
A first mode of operation of the system 100 according to the invention will now be described with reference to fig. 2. As previously mentioned, the first mode of operation is referred to as "balanced". In other words, this first mode of operation corresponds to an ideal situation in which the amount of vaporized natural gas present in the gaseous state at the top of the tank 201 is the same as the demand of the gas consuming device 130 and/or 131. As schematically shown, in this first mode of operation, the valves 150, 151 are closed and the first and second pumps 210, 220 are not running. In this first mode of operation, the natural gas is therefore extracted in gaseous state from the top of the tank 201 and then sent directly to the compression member 120 and/or the compression device 121, so that its pressure can be increased to supply the gas consumers 130 and/or 131.
Fig. 3 shows a second mode of operation of the system 100 according to the invention, which is referred to as "forced vaporisation". This second mode of operation is implemented when the amount of gaseous natural gas present at the top of the tank 201 is below the demand of the gas consuming device/devices. This second mode of operation advantageously allows the production of gaseous natural gas from liquefied natural gas, so as to be able to supply the item/items of equipment.
As shown in fig. 3, in the second operation mode, both the first pump 210 and the second pump 220 are activated, while the valves 150, 151 provided on the second conduit 102 and between the sixth conduit 106 and the heat exchanger 110, respectively, are closed, so that the compressed natural gas from the compression member 120 and/or the compression means 121 is entirely delivered to the item/items of gas consuming equipment. In other words, in this second mode of operation, the second passage 112 of the heat exchanger 110 is not supplied and the gaseous natural gas extracted from the tank is sent directly to the compression member 120 and/or the compression device 121.
The heat exchanger 170 itself is supplied with natural gas in liquid form that is withdrawn from the tank 200. Thus, the first pump 210 draws the liquefied natural gas from the tank 200, which passes through the expansion device 182, where the liquefied natural gas undergoes a reduction in its pressure in the expansion device 182. Provision may be made, for example, for this expansion to allow the liquefied natural gas to pass from atmospheric pressure, i.e. about 1bar, to a pressure below atmospheric pressure, e.g. a pressure of about 0.35 bar. Accordingly, the first passage 171 of the heat exchanger 170 is supplied with the liquefied natural gas of low pressure.
The second pump 220 also draws lng from the tank 200 to directly feed the second passage 172 of the heat exchanger 170. Thus, the second passage 172 of the heat exchanger 170 is supplied with the liquefied natural gas at atmospheric pressure. As previously described, heat is then exchanged in the heat exchanger 170 between the low pressure natural gas liquid circulating in the first passage 171 and the natural gas liquid at atmospheric pressure circulating in the second passage 172. This results in vaporization of the low pressure natural liquid gas flowing in the first passage 171 and subcooling of the natural liquid gas at atmospheric pressure flowing in the second passage 172. The subcooled liquefied natural gas may then be returned to the bottom of the tank 200 via the seventh conduit 107, while the vaporized natural gas leaves the first passage 171 in gaseous state to the compression device 122, where the vaporized natural gas undergoes an increase in its pressure. As described above, the compression device 122 is capable of compressing gaseous natural gas from a pressure of about 0.35bar to a pressure of about 1 bar. Thus, gaseous natural gas exits the compression device 122 at atmospheric pressure and reaches the compression member 120 and/or the compression device 121, the pressure of which in one or both of the compression member 120 and/or the compression device 121 is still high, so that it can be used as fuel for a gas consuming apparatus.
From the above it will be appreciated that in the second mode of operation of the system 100 according to the invention, the heat exchanger 170 advantageously allows the gas consumers 130, 131 to be supplied with gas on the one hand and cold to be stored in the bottom of the tank 200 on the other hand. As will be described in greater detail below, storage of subcooled liquid natural gas in tank 200 reduces the temperature of the liquid natural gas contained in tank 200, thereby reducing vaporization of the liquid natural gas contained in tank 200.
As shown in fig. 4, the third mode of operation, referred to as "reliquefaction," itself corresponds to a mode of operation of the system 100 in which the amount of natural gas present in the gaseous state at the top of the tank 201 exceeds the gas demand of the gas consuming device 130 and/or 131.
In this third mode of operation, natural gas is withdrawn in gaseous state from the top of the tank 201 to feed the heat exchanger 110, more specifically to the first passage 111 of the heat exchanger 110. As described above, in this heat exchanger 110, the gaseous natural gas collects heat energy from the gaseous compressed natural gas circulating in the second passage 112. Thus, the natural gas leaves the heat exchanger 110 in a gaseous state and at a temperature higher than its temperature in the top of the tank 201. Thus, the warmed gaseous natural gas reaches the compression member 120 and/or the compression device 121, where it undergoes a pressure increase, in one or both of the compression member 120 and/or the compression device 121, to a value sufficient to supply at least one of the gas consumers 130, 131. Thus, a portion of the warmed and compressed gaseous natural gas is supplied to the gas consuming device 130 and/or 131. At least one of the valves 150, 151 is itself open to allow another portion of the heated and compressed gaseous natural gas to reach the second passage 112 of the heat exchanger 110. It must be understood that the portion of the heated and compressed gaseous natural gas supplied to the gas consuming apparatus 130 and/or 131 is different from another portion of the heated and compressed gaseous natural gas reaching the second passage 112 of the heat exchanger 110. As described above, the gaseous natural gas circulating in the second passage 112 of the heat exchanger 110 releases thermal energy to the gaseous natural gas circulating in the first passage 111 of the heat exchanger 110, so that the gaseous natural gas leaves the heat exchanger 110 and reaches the third pipeline 103 at a temperature lower than the temperature at which it enters the second passage 112. However, it must be understood that the natural gas leaves the second passage 112 of the heat exchanger 110 in a gaseous state.
As previously described, the third conduit 103 is connected to the frothing member 140. The gaseous natural gas exiting the second passage 112 of the heat exchanger 110 is cooled to reach the foaming part 140 and passes through the holes 142 formed in the hanger bar 141 of the foaming part 140 to generate the bubbles 143 and discharge them to the bottom of the tank 200. Thus, these bubbles 143 find themselves in contact with the natural gas liquid contained in the tank 200, causing them to condense and thus become natural gas liquid, which is then mixed with the remaining natural gas liquid present in the tank 200.
Advantageously, the holes 142 of the frothing member 140 are evenly distributed over the entire length of the boom 141, that is to say over the longest dimension of this boom 141, so that the bubbles 143 are evenly distributed at the bottom of the tank 200, thereby increasing the contact area and the temperature difference between each bubble and the liquefied natural gas contained in the tank 200. It will be appreciated that the release of these bubbles 143 has a tendency to increase the temperature of the liquid natural gas contained in the tank 200.
According to the invention, the second and third operating modes are advantageously carried out continuously. In particular, as described with reference to fig. 3, the second mode of operation allows cold to be stored at the bottom of the tank-as natural gas that has been sub-cooled by heat exchange carried out in the heat exchanger 170 is returned to the bottom of the tank. The temperature of the liquefied natural gas contained in the tank 200 is thus lowered, and the temperature increase of the liquefied natural gas generated by releasing the bubbles 143 via the bubbling member 140 when the third operation mode is implemented is controlled. In other words, without the preliminary cold storage step, the bubbles 143 released by the frothing member 140 would cause an excessive increase in the temperature of the lng contained in the tank 200, which would cause it to boil off and therefore an increase in pressure, which could damage the tank 200. In other words, the second operating mode allows: since the frothing member 140 releases the bubbles 143 when the system 100 switches to the third operating mode, cold is stored in anticipation of the temperature increase of the lng contained in the tank.
From the above, it will be appreciated that for optimal operation of the system 100, that is to say operation in which the pressure at the top of the tank 201 is controlled, it is necessary to alternate between the second and third modes of operation of the system 100.
Finally, fig. 5 is a cross-sectional view of the ship 70, showing a tank 200 containing liquid and gaseous natural gas, the tank 200 having a prismatic overall shape and being installed in the double hull 72 of the ship. The walls of the tank 200 comprise a main sealing membrane intended to come into contact with the liquefied gas contained in the tank, a secondary sealing membrane arranged between the primary sealing membrane and the double hull 72 of the ship, and two insulating layers arranged between the primary sealing membrane and the secondary sealing membrane and between the secondary sealing membrane and the double hull 72, respectively.
Loading and/or unloading lines 73 arranged on the upper deck of the ship may be coupled to a marine or port terminal by means of suitable connectors for transporting liquid natural gas cargo out of or to the tank 1.
Fig. 5 also depicts an example of a marine terminal comprising a loading and/or unloading station 75, a submarine pipeline 76 and an onshore facility 77. The loading and/or unloading station 75 is a fixed offshore installation comprising a movable arm 74 and a tower 78 supporting the movable arm 74. The mobile arm 74 supports a bundle of insulated lines 79 that can be connected to the loading and/or unloading line 73. The orientable movable arm 74 can be adapted for all sizes of vessel. The loading and unloading station 75 allows the ship 70 to be loaded and/or unloaded from an onshore facility 77 to the onshore facility 77. The latter comprises a liquefied gas storage tank 80 and a connecting pipeline 81 connected to the loading or unloading station 75 by means of the underwater pipeline 76. The underwater pipeline 76 is used to transport liquefied gas over long distances (e.g. 5km) between the loading or unloading station 75 and the onshore facility 77, which allows the vessel 70 to be located far from shore during loading and/or unloading operations.
In order to generate the pressure required for the transportation of the liquefied gas, use is made of one or more unloading pumps as described above and supported by loading and/or unloading towers belonging to the tank 200 and/or pumps provided with the onshore installation 77 and/or with the loading and unloading station 75.
Of course, the invention is not limited to the examples just described, and various modifications may be made to these examples without departing from the scope of the invention.
The invention thus proposes a gas treatment system which allows to supply gas consumers onboard a ship with naturally vaporized gas and with forcibly vaporized liquefied gas and also allows to condense the natural calligraphy and painting gas if the naturally vaporized gas is too much compared to the energy requirements of the gas consumers onboard the ship, which is advantageous for limited costs.
The invention is naturally not limited to the devices and constructions described and shown herein, but extends also to any equivalent device and any equivalent construction and any technically feasible combination of such devices.

Claims (17)

1. A gas treatment system (100) for treating gas contained in a tank (200) for storing and/or transporting liquid and gaseous gas, the tank being mounted on a ship, the system (100) comprising at least:
a heat exchanger (110) configured to exchange heat between gas withdrawn in a gaseous state from the tank (200) and compressed gas from the tank (200),
a compression member (120) configured to compress the gaseous gas from the heat exchanger (110),
a gas consuming device (130, 131) consuming gaseous gas and configured to be supplied with said compressed gas,
a first conduit (101) connecting the compression member (120) to the gas consuming device (130, 131) consuming gaseous gas,
a second conduit (102) connecting the first conduit (101) to an inlet aperture (115) of the heat exchanger (110),
a third pipe (103) connecting an outlet hole (116) of the heat exchanger (110) to the bottom of the tank (200),
a frothing member (140) connected to the third conduit (103) and configured to distribute gaseous gas from the heat exchanger (110) into the bottom of the tank (200).
2. Gas treatment system (100) according to claim 1, comprising an expansion means (182) and a heat exchanger (170), the heat exchanger (170) being equipped with at least one first channel (171) supplied with gas drawn from the tank (200) in liquid state and at least one second channel (172) supplied with gas drawn from the tank (200) in liquid state, the expansion means (182) being arranged between the tank (200) and the first channel (171) of the heat exchanger (170).
3. The gas treatment system (100) according to any one of the preceding claims, wherein the frothing member (140) comprises at least one boom (141) provided with holes (142) generating gas bubbles (143).
4. The gas processing system (100) of claim 3, wherein the holes (142) of the hanger bar (141) each have a cross-section of 0.0078mm2To 315mm2Within the range.
5. The gas processing system (100) according to any of the preceding claims, wherein at least one expansion member (181) is arranged on the first conduit (101).
6. The gas processing system (100) according to any one of the preceding claims, comprising a compression device (121) arranged in parallel with the compression member (120), the compression member (120) being configured to compress a first portion of the gaseous gas from the heat exchanger (110), the compression device (121) being configured to compress a second portion of the gaseous gas from the heat exchanger (110), the first portion of the gas from the heat exchanger (110) being different from the second portion of the gas from the heat exchanger (110).
7. The system (100) according to any one of the preceding claims, wherein the gas stored and/or transported in the tank (200) is natural gas.
8. The gas processing system (100) according to any of the preceding claims, comprising at least one first gas consuming device (130) and at least one second gas consuming device (131), wherein the first gas consuming device (130) is configured to be supplied with compressed gas at a first pressure, wherein the second gas consuming device (131) is configured to be supplied with compressed gas at a second pressure, and wherein the first pressure is lower than the second pressure.
9. Vessel for transporting liquefied gas, comprising at least one tank (200) for liquefied gas cargo, at least one gas consumption device (130, 131) consuming vaporized gas and a gas treatment system (100) according to any of the preceding claims.
10. A system (100) for loading or unloading liquid gas, incorporating at least one onshore facility and at least one ship for transporting liquefied gas according to claim 9.
11. A method for treating gas contained in a tank (200) fitted to a ship, said method implementing a gas treatment system (100) according to any one of claims 1 to 8, said method comprising at least the following steps:
withdrawing gaseous gases from the tank (200),
heating the gas withdrawn in the gaseous state from the tank (200) by heat exchange in a heat exchanger (110) with the gas compressed by the compression means (120),
compressing the heated gas using the compression member (120),
supplying a first portion of the heated and compressed gas to at least one gas consuming device (130, 131) consuming boil-off gas,
cooling a second portion of the heated and compressed gas by heat exchange in the heat exchanger (110) with gas withdrawn in the gaseous state from the tank (200),
distributing a second portion of the gas cooled by passing it through the heat exchanger (110) to the bottom of the tank (200).
12. A method for treating a gas as recited in claim 11, wherein the step of dispensing the second portion of the cooling gas includes bubbling the second portion of the cooling gas.
13. Method for treating a gas according to any one of claims 11 and 12, wherein the pressure at the inlet of the third conduit (103) is higher than the pressure measured at the bottom of the tank (200).
14. A method for treating a gas according to any one of claims 11 to 13, comprising at least one step of subcooling the natural gas withdrawn from the tank (200) in the liquid state and at least one step of storing the subcooled natural gas in the bottom of the tank (200).
15. A method for treating a gas according to claim 14, wherein the sub-cooling step is carried out by heat exchange between natural gas in liquid state and maintained at atmospheric pressure, extracted from the tank (200), and natural gas in liquid state and expanded to sub-atmospheric pressure, extracted from the tank (200).
16. The method for treating gases according to any of claims 14 and 15, wherein the step of subcooling the natural gas withdrawn from the tank (200) in the liquid state, the step of storing the subcooled natural gas in the bottom of the tank (200) and the step of distributing at the bottom of the tank (200) a second portion of the gas cooled by passing it through the heat exchanger (110) are carried out at least twice in succession in this order.
17. A method of loading or unloading liquid gas to or from a gas carrier according to claim 9.
CN202080066480.5A 2019-08-19 2020-08-17 System installed on board a ship for treating gas contained in tanks for storing and/or transporting liquid and gaseous gases Pending CN114423691A (en)

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FR1909275A FR3100055B1 (en) 2019-08-19 2019-08-19 Gas treatment system contained in a tank for storing and / or transporting gas in the liquid state and in the gaseous state fitted to a ship
FR1909275 2019-08-19
PCT/FR2020/051471 WO2021032925A1 (en) 2019-08-19 2020-08-17 System for treating gas contained within a tank for storing and/or transporting gas in the liquid state and the gaseous state, the system being fitted on a ship

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FR3121504B1 (en) * 2021-04-01 2023-04-14 Gaztransport Et Technigaz Method for cooling a heat exchanger of a gas supply system of a gas-consuming device of a ship

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FR3100055B1 (en) 2021-07-23
EP4018119A1 (en) 2022-06-29
WO2021032925A1 (en) 2021-02-25
KR20220049030A (en) 2022-04-20
FR3100055A1 (en) 2021-02-26

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