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WO2010093400A1 - Procédés et systèmes d'échange de chaleur régénératif - Google Patents

Procédés et systèmes d'échange de chaleur régénératif Download PDF

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Publication number
WO2010093400A1
WO2010093400A1 PCT/US2009/068083 US2009068083W WO2010093400A1 WO 2010093400 A1 WO2010093400 A1 WO 2010093400A1 US 2009068083 W US2009068083 W US 2009068083W WO 2010093400 A1 WO2010093400 A1 WO 2010093400A1
Authority
WO
WIPO (PCT)
Prior art keywords
volume
gas
liquefaction
lng
location
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.)
Ceased
Application number
PCT/US2009/068083
Other languages
English (en)
Inventor
Moses Minta
Bruce T. Kelley
Mark E. Ehrhardt
William S. Mathews
Eric D. Nelson
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.)
ExxonMobil Upstream Research Co
Original Assignee
ExxonMobil Upstream Research Co
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 ExxonMobil Upstream Research Co filed Critical ExxonMobil Upstream Research Co
Priority to US13/145,972 priority Critical patent/US20110297346A1/en
Publication of WO2010093400A1 publication Critical patent/WO2010093400A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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    • 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
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K5/00—Heat-transfer, heat-exchange or heat-storage materials, e.g. refrigerants; Materials for the production of heat or cold by chemical reactions other than by combustion
    • C09K5/02—Materials undergoing a change of physical state when used
    • C09K5/06—Materials undergoing a change of physical state when used the change of state being from liquid to solid or vice versa
    • C09K5/063—Materials absorbing or liberating heat during crystallisation; Heat storage materials
    • 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
    • F25J1/0005—Light or noble gases
    • F25J1/001—Hydrogen
    • 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
    • F25J1/0012—Primary atmospheric gases, e.g. air
    • 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
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    • F25J1/0015—Nitrogen
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    • 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
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    • F25J1/0017—Oxygen
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    • 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
    • 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
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    • 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
    • F25J1/0027—Oxides of carbon, e.g. CO2
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    • 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"
    • F25J1/0035—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 gas expansion with extraction of work
    • 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"
    • F25J1/0042—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 liquid expansion with extraction of work
    • 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
    • F25J1/0251—Intermittent or alternating process, so-called batch process, e.g. "peak-shaving"
    • 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
    • F25J1/0262—Details of the cold heat exchange 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
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    • 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
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    • 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
    • F25J1/0278—Unit being stationary, e.g. on floating barge or fixed platform
    • 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
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    • 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
    • F28D17/00—Regenerative heat-exchange apparatus in which a stationary intermediate heat-transfer medium or body is contacted successively by each heat-exchange medium, e.g. using granular particles
    • F28D17/02—Regenerative heat-exchange apparatus in which a stationary intermediate heat-transfer medium or body is contacted successively by each heat-exchange medium, e.g. using granular particles using rigid bodies, e.g. of porous material
    • 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
    • F28D20/00—Heat storage plants or apparatus in general; Regenerative heat-exchange apparatus not covered by groups F28D17/00 or F28D19/00
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    • 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
    • F28D20/00—Heat storage plants or apparatus in general; Regenerative heat-exchange apparatus not covered by groups F28D17/00 or F28D19/00
    • F28D20/02—Heat storage plants or apparatus in general; Regenerative heat-exchange apparatus not covered by groups F28D17/00 or F28D19/00 using latent heat
    • F28D20/023—Heat storage plants or apparatus in general; Regenerative heat-exchange apparatus not covered by groups F28D17/00 or F28D19/00 using latent heat the latent heat storage material being enclosed in granular particles or dispersed in a porous, fibrous or cellular structure
    • 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
    • F28D7/00—Heat-exchange apparatus having stationary tubular conduit assemblies for both heat-exchange media, the media being in contact with different sides of a conduit wall
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    • 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
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    • F28D9/0062—Heat-exchange apparatus having stationary plate-like or laminated conduit assemblies for both heat-exchange media, the media being in contact with different sides of a conduit wall the conduits for one heat-exchange medium being formed by spaced plates with inserted elements
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    • 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
    • F17C2221/00—Handled fluid, in particular type of fluid
    • F17C2221/03—Mixtures
    • F17C2221/032—Hydrocarbons
    • F17C2221/035—Propane butane, e.g. LPG, GPL
    • 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
    • F17C2223/01—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
    • F17C2223/03—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
    • 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
    • F17C2225/03—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
    • 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
    • F17C2227/0135—Pumps
    • F17C2227/0142—Pumps with specified pump type, e.g. piston or impulsive type
    • 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
    • F17C2227/0135—Pumps
    • F17C2227/015—Pumps with cooling of the pump
    • 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
    • F17C2227/0304—Heat exchange with the fluid by heating using an electric heater
    • 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
    • F17C2227/033—Heat exchange with the fluid by heating using solar energy
    • 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
    • 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
    • F17C2227/0365—Heat exchange with the fluid by cooling 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
    • F17C2227/0397—Localisation of heat exchange characterised by fins
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2250/00—Accessories; Control means; Indicating, measuring or monitoring of parameters
    • F17C2250/03—Control means
    • F17C2250/032—Control means using computers
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2250/00—Accessories; Control means; Indicating, measuring or monitoring of parameters
    • F17C2250/04—Indicating or measuring of parameters as input values
    • F17C2250/0404—Parameters indicated or measured
    • F17C2250/043—Pressure
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2250/00—Accessories; Control means; Indicating, measuring or monitoring of parameters
    • F17C2250/04—Indicating or measuring of parameters as input values
    • F17C2250/0404—Parameters indicated or measured
    • F17C2250/0439—Temperature
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2260/00—Purposes of gas storage and gas handling
    • F17C2260/01—Improving mechanical properties or manufacturing
    • F17C2260/016—Preventing slosh
    • 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
    • F17C2260/00—Purposes of gas storage and gas handling
    • F17C2260/05—Improving chemical properties
    • F17C2260/053—Reducing corrosion
    • 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
    • F17C2265/01—Purifying the fluid
    • F17C2265/015—Purifying the fluid by separating
    • 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
    • F17C2265/034—Treating the boil-off by recovery with cooling with condensing the gas phase
    • 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
    • F17C2265/05—Regasification
    • 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
    • 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
    • F17C2270/0118—Offshore
    • F17C2270/0121—Platforms
    • 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
    • F25J2205/24—Processes or apparatus using other separation and/or other processing means using regenerators, cold accumulators or reversible heat exchangers
    • 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
    • F25J2235/00—Processes or apparatus involving steps for increasing the pressure or for conveying of liquid process streams
    • F25J2235/60—Processes or apparatus involving steps for increasing the pressure or for conveying of liquid process streams the fluid being (a mixture of) hydrocarbons
    • 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
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y02E60/14—Thermal energy storage
    • 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
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y02E60/30—Hydrogen technology
    • Y02E60/32—Hydrogen storage
    • 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
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P20/00—Technologies relating to chemical industry
    • Y02P20/10—Process efficiency

Definitions

  • the disclosure relates generally to methods and systems for efficiently and effectively liquefying, transporting, and delivering liquefied gas to commercial markets from production locations. More particularly, the disclosed systems, apparatuses, and associated methods relate to recovering and storing the cold thermal energy from the regasification of liquefied gases for later use in a liquefaction process or apparatus utilizing a regenerative heat exchange apparatus.
  • LNG Liquefying the natural gas
  • the present invention discloses a heat transfer system.
  • the system includes a regasification system at a first location configured to convert a first volume of liquefied gas (LG) contained at or below a liquefaction temperature into a first volume of gas at above the liquefaction temperature, the regasification system comprising a heat exchange apparatus.
  • the heat exchange apparatus includes a regenerator matrix having a volume of high heat capacity materials configured to recover and store cold energy from the LG from the regasification system for subsequent use at a second location to provide at least a portion of a cold energy requirement for liquefaction of a second volume of gas into a second volume of LG.
  • Another embodiment of the present invention discloses a heat transfer system.
  • the heat transfer system includes a liquefaction system at a first location configured to convert a first volume of gas at above a liquefaction temperature into a first volume of liquefied gas (LG) contained at or below the liquefaction temperature, the liquefaction system comprising a heat exchange apparatus.
  • the heat exchange apparatus includes a regenerator matrix including a volume of high heat capacity materials configured to provide cold energy to the first volume of gas in the liquefaction system, wherein the cold energy is obtained from a regasification system at a second location configured to regasify a second volume of LG contained at liquefaction temperatures.
  • a third embodiment of the present invention discloses a heat transfer system.
  • the heat transfer system includes a heat exchange apparatus.
  • the heat exchange apparatus having a regenerator matrix including a volume of high heat capacity materials, wherein the regenerator matrix is configured to: a) recover and store cold energy from a volume of liquefied gas at or below a liquefaction temperature from a regasification system at a first location; and b) provide cold energy to a volume of gas at above the liquefaction temperature in a liquefaction system at a second location.
  • a method of delivering liquefied natural gas includes flowing LNG to a heat exchange apparatus from an LNG storage tank on an LNG carrier at an LNG gasification location; recovering cold energy from the LNG using the heat exchange apparatus having a regenerator matrix including a volume of high heat capacity materials to form at least partially vaporized natural gas; storing the cold energy in the high heat capacity materials for use at an LNG liquefaction location; and delivering the at least partially vaporized natural gas to a consuming market.
  • a method of producing natural gas is provided.
  • the method includes feeding a natural gas stream to a heat exchange apparatus on a liquefied natural gas (LNG) carrier from a producing location; and passing the natural gas stream through the heat exchange apparatus having a regenerator matrix including a volume of high heat capacity materials. Passing the natural gas through the heat exchange apparatus includes a) imparting cold energy from the high heat capacity materials to the natural gas to form at least partially liquefied natural gas; and b) storing heat energy in the high heat capacity materials for use at an LNG gasification location. The method further includes storing the at least partially liquefied natural gas on the LNG carrier.
  • LNG liquefied natural gas
  • an alternative heat transfer system in a sixth embodiment of the present disclosure, includes a regasification system at a first location configured to convert a first volume of liquefied gas (LG) contained at or below a liquefaction temperature into a first volume of gas at above the liquefaction temperature, the regasification system comprising a heat exchange apparatus.
  • the heat exchange apparatus includes a shell and tube heat exchanger.
  • the shell and tube heat exchanger includes a) a sealed tube bundle containing a volume of high heat capacity material; and b) the shell side is configured to receive the first volume of liquefied gas (LG) to provide the cold energy stored in the tube bundle, wherein the volume of high heat capacity material is configured to recover and store cold energy from the LG from the regasification system for subsequent use at a second location to provide at least a portion of a cold energy requirement for liquefaction of a second volume of gas into a second volume of LG.
  • LG liquefied gas
  • an alternative heat transfer system includes a liquefaction system at a first location configured to convert a first volume of gas at above a liquefaction temperature into a first volume of liquefied gas (LG) contained at or below the liquefaction temperature, the liquefaction system comprising a heat exchange apparatus.
  • a liquefaction system at a first location configured to convert a first volume of gas at above a liquefaction temperature into a first volume of liquefied gas (LG) contained at or below the liquefaction temperature
  • LG liquefied gas
  • the heat exchange apparatus includes a shell and tube heat exchanger, comprising a) a sealed tube bundle containing a volume of high heat capacity material; and b) the shell side is configured to receive the first volume of liquefied gas (LG) to receive the cold energy to the volume of high heat capacity material in the sealed tube bundle, wherein the volume of high heat capacity material is configured to provide cold energy to the first volume of gas in the liquefaction system, wherein the cold energy is obtained from a regasification system at a second location configured to regasify a second volume of LG contained at liquefaction temperatures.
  • the systems may include a phase-change material (PCM) configured to utilize at least the latent heat of vaporization and a non-condensible gas in the sealed tubes.
  • PCM phase-change material
  • a method of delivering liquefied natural gas includes flowing LNG to a heat exchange apparatus from an LNG storage tank on an LNG carrier at an LNG gasification location; passing the LNG through the heat exchange apparatus having a shell and tube heat exchanger including sealed tubes containing a volume of high heat capacity material; recovering cold energy from the LNG utilizing the shell and tube heat exchanger to form at least partially vaporized natural gas; storing the cold energy in the high heat capacity materials for use at an LNG liquefaction location; and delivering the at least partially vaporized natural gas to a consuming market.
  • the shell and tube heat exchanger may include a phase-change material (PCM) configured to utilize at least the latent heat of vaporization and a non-condensible gas in the sealed tubes.
  • PCM phase-change material
  • a heat transfer system in a ninth embodiment, includes a regasification system at a first location configured to convert a first volume of liquefied gas (LG) contained at or below a liquefaction temperature into a first volume of gas at above the liquefaction temperature, the regasification system comprising a heat exchange apparatus.
  • LG liquefied gas
  • the heat exchange apparatus including a cross-flow heat exchanger, comprising: a) at least one plugged flow channel containing a volume of high heat capacity material; and b) at least one open flow channel configured to receive the first volume of liquefied gas (LG) to provide cold energy to the volume of high heat capacity material in the at least one plugged flow channel, wherein the volume of high heat capacity material is configured to recover and store cold energy from the LG from the regasification system for subsequent use at a second location to provide at least a portion of a cold energy requirement for liquefaction of a second volume of gas into a second volume of LG.
  • LG liquefied gas
  • FIG. 1 shows an exemplary diagram of one embodiment of a heat transfer system including a heat exchange apparatus in accordance with certain aspects of the present disclosure
  • FIG. 2 shows an exemplary diagram of an alternative embodiment of the heat transfer system of FIG. 1;
  • FIG. 3 shows an exemplary diagram of an alternative embodiment of the heat transfer system of FIGs. 1 and 2;
  • FIGs. 4A-4C are illustrations of flow charts of methods of operating one of a regasif ⁇ cation unit, a liquefaction unit, and an integrated unit in accordance with certain embodiments of FIGs. 1-3;
  • FIGs. 5A-5B show an exemplary embodiment of the heat exchange apparatus of FIGs. 1-3 in two modes of operation
  • FIGs. 6A-6E show various particular embodiments of heat exchange apparatuses utilizing phase-change materials in the heat exchange arrangements of FIGs. 1-3;
  • FIGs. 7A-7C are graphs showing the effect on the thermal energy consumption using a single composite material; and [0027] FIG. 8 is an illustration of the arrangement of an exemplary group of materials with respect to the fluid flow paths and temperatures of flow streams of FIGs. 1-3.
  • liquefaction temperature means a temperature at which a gas is converted to a liquid.
  • the liquefaction temperature of a gas will change with pressure, so a single gas may have more than one liquefaction temperature, depending on the pressure of the gas.
  • compositions of natural gas may vary by location or by the inclusion or exclusion of certain pre -treating process steps and the liquefaction temperature will vary somewhat with variations in the composition of such gases.
  • the term is intended to include any and all such variations in pressure and temperature.
  • a heat transfer system may include a regasif ⁇ cation system for converting liquefied gas at a liquefaction temperature, such as, for example, liquefied natural gas (LNG), from a liquid to a vapor phase (e.g. natural gas) at above a liquefaction temperature for the gas.
  • LNG liquefied natural gas
  • the system may further include a heat exchange apparatus having a regenerator matrix containing a volume of high heat capacity materials (a.k.a. thermal energy storage materials), which may be phase-change materials in some exemplary embodiments.
  • the heat exchange apparatus may further be configured to recover and store the cold energy (e.g.
  • the regenerator matrix is configured to store the cold energy in the high heat capacity materials long enough to transport it to a second location to perform a liquefaction operation utilizing the cold energy for at least a portion of the cooling needed to liquefy gas from a vapor phase.
  • a heat transfer system including a liquefaction system for converting a first volume of feed gas at above liquefaction temperature from a substantially gaseous phase to a substantially liquid phase (e.g. a first volume of liquefied gas) is provided.
  • the liquefaction system further includes a heat exchange apparatus having a regenerator matrix including a volume of high heat capacity materials configured to provide cold energy to the first volume of gas in the liquefaction system, wherein the cold energy is obtained from a regasif ⁇ cation system at a second location configured to re-gasify a second volume of liquefied gas contained at liquefaction temperatures.
  • the re-gasification system and the liquefaction system may be integrated and utilize the same heat exchange apparatus.
  • the high heat capacity materials may include phase change materials (PCMs) and may be configured in the regenerator matrix as micro-encapsulated spheroids, macro-encapsulated spheroids, microencapsulated sheets, macro-encapsulated sheets, macro-encapsulated honey-comb network, or a micro-encapsulated honey-comb network.
  • the PCMs may be a series of phase-change materials (PCMs) stacked sequentially based on a phase transition temperature of the PCMs or may be a thermo-adjustable mixture, which allows the phase transition temperature to be tuned based on the composition of the mixture.
  • the mixture may comprise at least two unique PCMs, wherein each PCM has a different phase transition temperature range.
  • an integrated production, transport, and re-gasification system (PTRS) is provided.
  • PTRS production, transport, and re-gasification system
  • One specific embodiment provides for the integration of the LNG production system, the LNG transport system, and the LNG regasif ⁇ cation system into a single unit (LNG-PTRS) through the use of a heat exchange system.
  • Such an integrated system may further utilize the liquefaction system to reliquefy boil-off gas during transit.
  • Additional embodiments include methods of re-gasifying and delivering natural gas to an import terminal as well as liquefying and producing natural gas at a production location utilizing embodiments of the systems disclosed herein.
  • Still further alternative embodiments may incorporate a shell and tube heat exchanger instead of the regenerator matrix, wherein the tubes may be filled with a high heat capacity material and a non-condensible gas.
  • the high heat capacity material may be a phase change material (PCM) that takes advantage of the latent heat of vaporization for a liquefaction temperature of interest.
  • PCM phase change material
  • a cross-flow heat exchanger with alternating flow channels having high heat capacity materials may also be used.
  • the disclosed embodiments also provide substantial advantages over building an LNG production facility on an offshore platform.
  • the disclosed systems and methods eliminate the need for several large LNG storage tanks on a platform; eliminate the technical challenges associated with cryogenic liquid transfer between an offshore platform and an LNG ship (only a gas connection is needed between the resource and the LNG ship); and eliminate the enormous space and weight requirements for an LNG production facility on an offshore platform.
  • FIG. 1 shows an exemplary diagram of one embodiment of a heat transfer system including a heat exchange apparatus in accordance with certain aspects of the present disclosure.
  • the heat transfer system disclosed in FIG. 1 shows an exemplary diagram of one embodiment of a heat transfer system including a heat exchange apparatus in accordance with certain aspects of the present disclosure.
  • the heat transfer system disclosed in FIG. 1 shows an exemplary diagram of one embodiment of a heat transfer system including a heat exchange apparatus in accordance with certain aspects of the present disclosure.
  • a regasification system 100 having a container or tank 102 for holding liquefied gas at or below its liquefaction temperature, a line 104 for delivering the liquefied gas to a pump 106 configured to pressurize the liquefied gas, a line 108 for delivering the pressurized, liquefied gas to a heat exchange apparatus 110 configured to vaporize the pressurized liquefied gas, and a line 112 for delivering the vaporized gas.
  • the liquefied gas is liquefied natural gas (LNG), but may alternatively be liquefied propane gas (LPG), liquefied carbon dioxide gas, liquefied nitrogen gas, liquefied air, liquefied oxygen, liquefied neon, liquefied hydrogen, or some combination thereof.
  • the container 102 may be any type of container suitable for transporting liquefied gases, such as a spherical tank container, a membrane tank container, a corrugated tank container, a prismatic tank container, or other type of container.
  • the line 104 may be any type of conduit or flow line suitable for delivering liquefied gases.
  • the line 104 should be large enough to flow the liquefied gas at a rate sufficient to support efficient regasification operations. It is contemplated that the line 104 may include insulation, have a corrosion resistant coating, a low-friction loss coating, another performance-enhancing coating, and any combination thereof.
  • the container 102 and the line 104 should be capable of operation at temperatures from at least about -253 degrees Celsius ( 0 C) to about 4O 0 C and have joints and other design features to permit the container 102 and the line 104 to cyclically contract and expand between these temperatures without failure for the life of the system 100. It is contemplated that a person of ordinary skill in the art has been provided with sufficient information to engineer the container 102 and line 104 in accordance with the present disclosure.
  • the pump 106 may be a series of multiple pumps or one large pump.
  • the pump 106 should be configured to handle liquefied gases at temperatures ranging from about -253 0 C to about -6O 0 C or from about - 196 0 C to about -100 0 C and should be capable of handling stress due to expansion and contraction cycles over a temperature range of about -253 0 C to about 4O 0 C.
  • the pump 106 should further be capable of providing a sufficient flow rate of the liquefied gas through the system 100 for normal unloading and regasification operations.
  • a reciprocating pump, a centrifugal pump, a cryogenic pump, or any combination of these types of pumps may be utilized in accordance with the present disclosure.
  • the line 108 may have many of the same features as line 104, however the liquefied gas flowing through line 108 is expected to have a somewhat higher temperature and pressure than the liquefied gas in line 104 because it passes through the pump 106.
  • the heat exchange apparatus (heat exchanger) 110 may include a regenerator matrix, a shell and tube arrangement, a plate-fin arrangement, or other configuration having high heat capacity materials configured to recover and store cold energy from the liquefied gas (LG) for subsequent use at a second location (e.g. a liquefaction location) to provide at least a portion of a cold energy requirement for liquefaction of a second volume of gas (e.g. a feed gas) into a second volume of LG.
  • a regenerator matrix e.g. a shell and tube arrangement, a plate-fin arrangement, or other configuration having high heat capacity materials configured to recover and store cold energy from the liquefied gas (LG) for subsequent use at a second location (e.g. a liquefaction location) to provide at least a portion of a cold energy requirement for liquefaction of a second volume of gas (e.g. a feed gas) into a second volume of LG.
  • a second location e.g. a lique
  • the high heat capacity materials may be a series of phase-change materials (PCMs) stacked sequentially based on a phase transition temperature of the PCMs, may include a thermo-adjustable mixture of materials which allow the phase transition temperature to be tuned based on the composition of the mixture.
  • the mixture may comprise at least two PCMs each having a different phase transition temperature, or may be a combination of these configurations.
  • the heat exchanger 110 may be a fixed bed regenerator, a compact regenerator, a micro-scale regenerator, or some combination of these.
  • the heat exchanger 110 may include a regenerator matrix including one of micro-encapsulated spheres, macro-encapsulated spheroids, micro-encapsulated sheets, a micro-encapsulated honey-comb network, macro-encapsulated sheets, macro-encapsulated honeycomb network, or some combination of these.
  • the heat exchanger 110 may comprise a shell and tube arrangement having high heat capacity materials in the tubes configured to recover and store cold energy from the liquefied gas (LG) for subsequent use at a second location (e.g. a liquefaction location) to provide at least a portion of a cold energy requirement for liquefaction of a second volume of gas (e.g. a feed gas) into a second volume of LG.
  • the high heat capacity materials may be PCMs and include a thermo- adjustable mixture of materials which allow the phase transition temperature to be tuned based on the composition of the mixture.
  • the high heat capacity materials in this arrangement may include materials utilizing at least the latent heat associated with vapor- liquid phase transition - (latent heat of vaporization or condensation). Note, these materials may also utilize the liquid-solid phase transition similar to the PCM's discussed above.
  • the regasification system 100 further includes a line 112 from the heat exchanger 110 to one of a vaporized gas delivery or offloading system, or may optionally include a supplemental heat exchange system 114 with optional supporting equipment 114a such as pumps, condensers, and boilers to further vaporize the gas after it passes through the heat exchanger 110.
  • the line 112 may be configured to carry vaporized gas after it passes through the heat exchanger 110.
  • line 112 may have a larger diameter than lines 108 and 104, may not include insulation and may have a composition with less nickel as lines 104 and 108 because line 112 may not operate at or below cryogenic liquefaction temperatures.
  • the optional heat exchange system 114 may be an electrical heater, may burn some of the vaporized gas for heat, may use ambient air or water, may utilize concentrated solar energy, or impart heat to the at least partially vaporized gaseous stream in line 112 by some other means.
  • power for the optional heat exchange system 114 may be generated by a co-located power plant, such as on a ship, on-shore, or off-shore structure having the regasification system 100.
  • FIG. 2 shows an exemplary diagram of an alternative embodiment of the heat transfer system of FIG. 1.
  • the heat transfer system includes a liquefaction system 200 having a line 202 for delivering a feed gas, a heat exchange apparatus 110, a line 204 for carrying the condensed, cooled feed gas from the regenerator to a container 102 for storing liquefied gas.
  • the system 200 may also include a supplemental heat exchanger 206 for sub-cooling the gas, a line 208 to carry the further cooled gas to an optional expander 210, and a line 212 to carry the liquefied gas to the liquefied gas container 102.
  • the line 202 for carrying the gaseous feed may be similar to the line 112, as it may be configured to carry a substantially gaseous feed, such as natural gas from a production location at substantially atmospheric or slightly higher temperatures and above ambient pressure.
  • the line 202 may not require insulation and may have a larger diameter than some of the other lines, but may be sized to handle sufficient amounts of gas to supply the system 200.
  • the gas may be a natural gas (NG), but may alternatively be propane gas (PG), carbon dioxide gas, nitrogen gas, air, oxygen, neon, hydrogen, or some combination thereof.
  • the heat exchange apparatus 110 may be the same or similar to the heat exchange apparatus (heat exchanger) 110 of the regasification system 100.
  • the heat exchanger 110 includes high heat capacity materials configured to provide cold energy to the feed gas in the liquefaction system 200.
  • the cold energy is obtained from a regasification system (e.g., regasification system 100) at a second location (e.g. a delivery or offloading location) configured to regasify another volume of liquefied gas contained at liquefaction temperatures.
  • the high heat capacity materials may be a series of phase-change materials (PCMs) stacked sequentially based on a phase transition temperature of the PCMs, may include a thermo-adjustable mixture of materials which allow the phase transition temperature to be tuned based on the composition of the mixture.
  • the mixture may comprise at least two PCMs each having a different phase transition temperature, or may be a combination of these configurations.
  • the heat exchanger 110 may be a fixed bed regenerator, a compact regenerator, a micro-scale regenerator, a shell and tube heat exchanger, or some combination of these.
  • the heat exchanger may include a regenerator matrix, which may be comprised of micro-encapsulated spheres, macro-encapsulated spheroids, micro-encapsulated sheets, a micro-encapsulated honey-comb network, macro-encapsulated sheets, macro-encapsulated honey-comb network, or some combination of these.
  • the high heat capacity materials may be enclosed in sealed tubes in a shell and tube heat exchanger arrangement, or a cross-flow heat exchanger arrangement having alternating flow channels with high heat capacity materials therein.
  • the line 204 is configured to carry gas that may be at least partially liquefied and at or below liquefaction temperatures and at high pressures.
  • Line 204 may be the same or similar to line 108.
  • Lines 208 and 212 are optional and may be the same or similar to line 204, line 108, and line 104, which are configured to safely and efficiently transport a substantially liquefied gas at liquefaction temperatures and above ambient pressures.
  • the system 200 may further include optional supplemental cooling systems
  • Supplemental cooler 206 may include additional equipment 206a such as pumps, chillers, and/or expanders and may be utilized for sub-cooling the gaseous stream if the heat exchanger 110 fails to sufficiently liquefy the gas for transport and supplemental cooler 214 may include additional equipment 214a such as pumps, chillers, and/or expanders and may be utilized for pre-cooling the gaseous stream before entering the heat exchanger 110 to ensure sufficient liquefaction of the gas for transport.
  • the cooling may be accomplished by utilizing any reasonably applicable heat exchanger such as a co-current or counter-current heat exchanger, a finned heat exchanger, direct contact heat exchanger, another type of heat exchanger, or some combination of these.
  • the refrigerant may be obtained from cold sea water, a mixed refrigerant system, an HPXP system, or some combination of these.
  • Power for the system may be generated by a co-located power plant, such as on a ship, on-shore, or off-shore structure, by a solar array, by burning a fuel gas, or some combination of these.
  • the optional expander 210 may be configured to provide supplemental cooling and liquefaction of the cooled stream prior to storage in the container 102.
  • the container 102 is the same or similar to the container 102 in the regasification system 100.
  • the expander 210 may be capable of cryogenic operation.
  • the expander may be a dual expander, a hydraulic turbine, a turbo expander, a throttling valve, or some combination of these. Depending on the ambient conditions, composition of the feed gas, and other factors, the expander 210 may not be needed and may be bypassed.
  • FIG. 3 shows an exemplary diagram of an alternative embodiment of the heat transfer system of FIGs. 1 and 2. As such, FIG. 3 may be best understood with reference to FIGs. 1 and 2.
  • the heat transfer system 300 includes a regasif ⁇ cation system 100 and a liquefaction system 200 integrated into a single system.
  • the integrated system 300 is installed on a platform 302 and includes connections for receiving a feed gas via line 308, which may be delivered by line 304 to a gas pre-treatment unit 306.
  • the system 300 further includes a pipeline 312 for delivery of vaporized gas to a consuming market.
  • the system 300 may include a pre-cooler 310 with a compressor 310a and a chiller 310b.
  • the platform 302 may be a carrier, such as an LNG carrier, or a barge or other facility.
  • the platform 302 will be capable of moving from a regasif ⁇ cation location to a liquefaction location which may be separated by a distance of from 100 miles to about 15,000 miles or from about 1,000 miles to about 10,000 miles, or from about 3,000 miles to about 6,000 miles.
  • the optional equipment 310, 214, and 114 may be on the platform 302 or located at a loading or unloading location.
  • the pretreatment unit 306 may be located at a gas production location or connected by pipeline to such a location.
  • the pretreatment unit 306 may be configured depending on the quantity and quality of the gas for treating, but may include a liquids separation portion or water-knockout portion to remove any hydrocarbon or aqueous liquids from the feed gas stream.
  • the unit 306 may further include an acid gas removal or separation unit to remove carbon dioxide, hydrogen sulfide, and other unwanted gases, depending on the composition of the feed gas.
  • Such a separation unit may include an amine unit, a membrane separation unit, an adsorption unit, or similar unit, or some combination thereof.
  • the pipeline 312 may be operably connected to gas handling system, a gas storage facility, a gas distribution network, or any combination thereof (not shown).
  • the vaporized gas product is delivered to a gas consuming market via the available gas receiving and handling system at that particular location.
  • the facilities may vary significantly from one location to another. Exemplary gas consuming markets include the United States, Japan, China, Italy, Great Britain, and others. Delivery locations may be located offshore or onshore.
  • the system 300 may be configured to be interoperable with any or all of these gas delivery locations.
  • the heat exchange apparatus 110 is configured to recover and store cold energy from a volume of liquefied gas at liquefaction temperatures from a regasification system 100 at a first location; and provide cold energy to a volume of gas at above liquefaction temperatures in a liquefaction system 200 at a second location.
  • the integrated system 300 may be utilized with an integrated production, transport, and re-gasification system (PTRS).
  • the production system may be liquefaction system 200
  • the transport may be carrier or barge 302
  • the re-gasification system may be re-gasification system 100.
  • such an integrated unit may be utilized to deliver liquefied natural gas (LNG) to commercial markets from remote production location.
  • LNG liquefied natural gas
  • Such an integrated LNG unit may be referred to as an LNG-PTRS.
  • the PTRS may further utilize the liquefaction system to reliquefy boil-off gas during transit.
  • the carrier 302 transports the liquefied gas from the producing location to the delivery location some of the liquefied gas in the container 102 may boil off or vaporize.
  • the stored cold energy in the heat exchange apparatus 110 may be utilized to reliquefy this boil-off gas and return it to the container 102 in liquid form.
  • any of the systems 100, 200, or 300 may utilize an instrumentation and control system (not shown) for safely and efficiently operating the systems 100, 200, or 300.
  • various sensors at a plurality of locations may be utilized to measure temperature and pressure of the gas in liquid or vapor form. Input from such sensors may be utilized to determine the amount of supplemental heat that may be added via the supplemental heat exchanger 114, the amount of supplemental cooling that may be added via the supplemental cooler 214 or 206, and the expander 210.
  • Such a control system may also control the flow rate of the liquefied gas via the pump 106 or the re liquefaction of boil-off gas.
  • the control system may be programmed to operate automatically via a programmable computer system having software instructions, may include manual inputs, a graphical user interface (GUI), and may include manual overrides, such as valves or switches in a central location or throughout the system 100, 200, or 300 at particular locations. It is contemplated that a person of ordinary skill in the art has been provided with sufficient information to engineer the control system in accordance with the present disclosure.
  • FIGs. 4A-4C are illustrations of flow charts of methods of operating one of a regasification unit, a liquefaction unit, and an integrated unit in accordance with certain embodiments of FIGs. 1-3. As such, FIGs. 4A-4C may be best understood with reference to FIGs. 1-3.
  • the method 400 includes delivering 402 liquefied natural gas (LNG) to a heat exchange apparatus from an LNG storage tank on an LNG carrier at an LNG gasification location, recovering 404 cold energy from the LNG utilizing the heat exchange apparatus having a regenerator matrix including a volume of high heat capacity materials to form at least partially vaporized natural gas and storing 406 the cold energy in the high heat capacity materials for use at an LNG liquefaction location, then delivering 408 the at least partially vaporized natural gas.
  • LNG liquefied natural gas
  • the LNG storage tank may be container 102 and the LNG carrier may be an LNG-PTRS, which may be represented by platform 302.
  • the heat exchange apparatus is the heat exchange apparatus 110.
  • the heat exchanger 110 may be included in the regasification system 100 or the integrated system 300.
  • the liquefaction location may include a liquefaction system 200.
  • the delivering step 410 may include the utilization of pipeline 312.
  • the method 450 includes feeding 452 a natural gas stream to a heat exchange apparatus on a liquefied natural gas (LNG) carrier from a producing location and passing 454 the natural gas stream through the heat exchange apparatus having a regenerator matrix including a volume of high heat capacity materials.
  • LNG liquefied natural gas
  • the heat exchange apparatus is configured to impart 456 cold energy from the high heat capacity materials to the natural gas to form at least partially liquefied natural gas and store 458 heat energy in the high heat capacity materials for use at an LNG gasification location.
  • the method 450 further includes storing 460 the at least partially liquefied natural gas on the
  • natural gas may be fed via line 202 in the liquefaction system 200 or via line 304 in the integrated system 300.
  • the heat exchange apparatus is the heat exchange apparatus 110.
  • the heat exchanger 110 may be included in the liquefaction system 200 or the integrated system 300.
  • the gasification location may include a regasification system 100.
  • the storing step 460 may include the utilization of container 102.
  • the method 470 includes delivering 472 liquefied natural gas (LNG) to a heat exchange apparatus from an LNG storage tank on an LNG carrier at an LNG gasification location, recovering 474 cold energy from the LNG using the heat exchange apparatus having a shell and tube heat exchanger including sealed tube bundles containing a volume of high heat capacity material to form at least partially vaporized natural gas, storing 476 the cold energy in the high heat capacity materials for use at an LNG liquefaction location, then delivering 478 the at least partially vaporized natural gas.
  • LNG liquefied natural gas
  • the tube sheets may include a non-condensible gas to account for the volume change if the high heat capacity materials are phase change materials over the heat of vaporization and may include a connected buffer volume to hold such a gas during high volume phase shifts.
  • FIGs. 5A and 5B show an exemplary embodiment of the heat exchange apparatus of FIGs. 1-3 in two modes of operation. As such, FIGs. 5 A and 5B may be best understood with reference to FIGs. 1-3.
  • FIG. 5 A is an exemplary embodiment of a portion of a liquefaction flow system 500 including the heat exchange apparatus 110 as it may operate in the liquefaction system 200.
  • the liquefaction flow system 500 includes a vessel 502 configured to enclose the heat exchange apparatus 110, flow valves 504a, 504b, 504c, and 504d configured to control fluid flow via lines 202, 112, 108, and 204, respectively.
  • Valves 504a and 504d are shown in the open position to permit fluid flow through lines 202 and 204, while valves 504b and 504c are shown in the closed position to prevent fluid flow in the opposing direction via lines 108 and 112.
  • valve 504a may be open while valve 504d is closed.
  • valve 504d may remain in the closed position until the feed gas (which is now much colder and may be at least partially liquefied) reaches valve 504d and some pressure is built up.
  • valves 504a and 504d may be operated based on the pressure requirements of the liquefaction system 200, which may depend on the feed gas composition, initial temperature, flow rate, flow volume, and other factors. Alternatively, as the process comes to an end, valve 504a may be closed while 504d remains open.
  • FIG. 5B shows an exemplary embodiment of a portion of a re-gasification flow system 520 including the heat exchange apparatus 110 as it may operate in the re- gasification system 100.
  • the re-gasification flow system 520 is similar to the liquefaction flow system 500, but with valves 504b and 504c open to permit flow of fluid streams through the heat exchange apparatus 110 and valves 504a and 504d closed to prevent fluid flow in the opposing direction.
  • the valves may be operated to open and close at different times, depending upon the operational needs.
  • valves 504a-504d may all be of the same or similar design, but alternatively, the valves 504a- 504d may be independently selected based on expected operating conditions. For example, it is expected that valve 504a may be configured to handle primarily gaseous feed streams at relatively high temperatures (e.g. from about O 0 C to about 120 0 C) and relatively high pressures (e.g. from about 1 atmosphere (atm) to about 20 atm), depending on the feed gas source. However, valve 504d may be expected to handle gas and liquid (multiphase) streams at significantly lower temperatures (e.g. from about -200 0 C to about -2O 0 C).
  • relatively high temperatures e.g. from about O 0 C to about 120 0 C
  • relatively high pressures e.g. from about 1 atmosphere (atm) to about 20 atm
  • valve 504d may be expected to handle gas and liquid (multiphase) streams at significantly lower temperatures (e.g. from about -200 0 C to about -2O 0 C
  • valve 504d may have different sizing, material selection, and operating parameters than valve 504a.
  • valve 504b is expected to handle fluid streams similar to the streams handled by valve 504a, but may require operation at a slightly lower temperature and pressure and valve 504c may be required to handle fluid streams similar to that of valve 504d.
  • valves 504a and 504b may be the same valve, capable of operation in both directions (liquefaction 500 and re-gasification 520) and valves 504c and 504d may be the same valve.
  • the high heat capacity materials may be any one or a combination of phase-change materials (PCMs), molecular alloys, a single composite material configured to span a temperature range of interest.
  • the material of choice includes a high enthalpy change in the appropriate temperature range (e.g. about 2OK (-253 0 C) to about 273K (O 0 C) or about 77K (-196 0 C) to about 213K (-6O 0 C)); phase change temperature in the appropriate regime of interest; and high mass density.
  • the material selected should have low density variation accompanying the thermal energy changes, high chemical stability associated with the thermal cycling, and compatibility between the active phase change material (PCM) and any containment material.
  • FIGs. 6A-6E show various particular embodiments of heat exchange apparatuses utilizing high heat capacity materials in the heat exchange arrangements of FIGs. 1-3.
  • FIGs. 6A-6D may be best understood with reference to FIGs. 1-3.
  • the arrangement 600 includes a regenerator matrix 601 including a first phase change material (PCM) 602, a first dividing wall 604a, a second PCM 606, a second dividing wall 604b, a third PCM 608, a third dividing wall 604c, and a fourth PCM 610.
  • the series of materials 602, 606, 608, and 610 are used to transfer thermal energy at discrete temperatures within the total temperature range of interest.
  • Each dividing wall 604a-604c may be of the same or similar type, but may comprise a rigid, porous material that permits the passage of fluids, but prevents the passage of PCMs from one portion of the regenerator matrix 601 to another portion thereof.
  • a plastic annular disc or punched plastic or other insulating material may be used as a spacer between the PCMs.
  • the specific heat capacity of each material 602, 606, 608, and 610 in the series of materials may also be used to augment the thermal energy storage capability of the PCM near its phase transition temperature.
  • the thermal energy storage capacity of the target material may be optimized for both the heat of fusion and the integrated value of the specific heat capacity over the appropriate temperature interval.
  • the TES system may further be packaged into a heat exchanger, such as the regenerator matrix 601 in the heat exchange apparatus 110. As such, the form of encapsulation may guide the development of the heat exchanger configuration.
  • the encapsulation technology may recognize the need for long term stable behavior of the TES system (e.g., compatibility between the different materials, minimizing the potential for adverse impacts of thermal cycling, abrasion, corrosion etc.).
  • the material may have a significantly high density (> 1000 kg/m 3 ).
  • FIGs. 6B-6D show an alternative arrangement of the heat exchange apparatus
  • FIG. 6B shows an exemplary shell and tube heat exchanger arrangement 620 having a shell 622, a tube bundle with straight tubes 624, baffles 626 (optional), tube sheets 628a and 628b, a gas inlet 630, and a gas outlet 632.
  • Such an arrangement 620 may be particularly suited to PCM 's utilizing the heat of vaporization, involves use of modified tube sheets traditionally used in shell and tube heat exchangers.
  • FIG. 6C shows a detail view of one embodiment of the tubes in the tube bundle 624, which are filled with the PCM material 644 and sealed to provide sufficient thermal storage capacity.
  • the tube wall material is made of relatively high thermal conductivity metallic material allowing for good heat transfer for the thick- wall required.
  • a non-condensible gas 642 such as nitrogen or argon, is added to the PCM 644 in the tube 624.
  • a non-condensible gas 642 such as nitrogen or argon
  • FIG. 6D An alternative embodiment of the shell and tube design to accommodate the volume changes associated with the phase transition is shown in FIG. 6D, where the non-condensible gas (e.g. nitrogen) is provided as a buffer 665 in the header for the tube sheet 628b.
  • FIG. 6E shows an exemplary cross-flow heat exchanger apparatus.
  • the cross- flow heat exchanger 680 with open flow channels 682 for flowing gas or cryogenic liquids 686 therethrough alternating with plugged flow channels 684 containing high heat capacity materials and, optionally non-condensible gas therein.
  • Other traditional heat exchangers such as spiral-wound, brazed aluminum, printed-circuit or micro-channel heat exchangers may be used with or without the buffer tank embodiment disclosed above.
  • the high heat capacity material may comprise a material analogous to phase change materials (PCMs) made up of molecular alloys (sometimes called MAPCM) which have the advantage of being thermo-adjustable, allowing the flexibility to tune the phase transition temperature through their composition.
  • PCMs phase change materials
  • MAPCM molecular alloys
  • one configuration may include a pair of materials, each with high heat of fusion that may be mixed in different proportions to provide mixtures with phase transition temperatures in the range of about 77 K to about 273 K, or from about 100 K to about 250 K or from about 150 K to about 200 K. Such a mixture may be encapsulated to preserve the mixture composition and thereby ensure a fixed phase transition temperature.
  • Another variation of the disclosed embodiments includes the use of a single composite material (SCM) to span the temperature range of interest.
  • the thermal energy storage capacity for the composite material is the sum of the solid phase specific heat capacity, the latent heat (of fusion) and the liquid phase specific heat capacity.
  • Graphs 700, 750, and 760 showing the effect on the thermal energy consumption using such a material are provided at FIGs. 7A-7C.
  • the composite material is thus chosen to optimize the integrated heat capacity associated with both the liquid and solid phases, and the heat of fusion for maximum thermal energy storage.
  • the total mass required to absorb the energy associated with a unit mass of LNG is between 0.55 to 0.65.
  • Yet another variation of the disclosed embodiments includes the use of a single composite material (SCM) to span the temperature range of interest but in an arrangement with an even higher thermal energy storage capacity.
  • SCM single composite material
  • the higher thermal energy storage capacity comes from utilizing the large latent heat associated with vapor- liquid phase transition - latent heat of vaporization (condensation).
  • a graph 760 showing the effect on the thermal energy consumption using such a material is provided as FIG. 7C.
  • the composite material is thus chosen to optimize the integrated heat capacity associated with the liquid and solid phases, as well as the heat of fusion and the heat of vaporization for maximum thermal energy storage.
  • the total mass required to absorb the energy associated with a unit mass of LNG is between 0.20 to 0.27.
  • the PCM material may be hermetically sealed to isolate it from the process stream 202 or 108. This may be accomplished by encapsulating the PCM in a form and geometry such that, when integrated into a heat exchanger, improves heat transfer effectiveness as well as cost effectiveness.
  • the regenerator matrix has a high surface area for a given volume, which provides a small exchanger volume for a given energy density, effectiveness and pressure drop.
  • the PCM may be macro-encapsulated.
  • This may include creating spheroids or sheets of encapsulated material that may be formed into a heat exchanger.
  • Heat transfer enhancement techniques such as fins, may be incorporated into the chosen configuration to increase the heat transfer area and hence the heat exchange effectiveness.
  • Other heat transfer enhancement techniques may be exploited in the manufacture of the PCM. For example, composites may be developed based on the PCM to advantageously improve the latent heat of fusion of the packaged PCM. This is analogous to composites that have been developed based on paraffins such as styrene-butadiene-styrene triblock copolymer. Further, a small fraction of other materials such as carbon fibers may be dispersed in the PCM to enhance the thermal conductivity of the TES.
  • a high thermal conductivity is not a primary requirement, unlike the typical Thermal Energy Storage system (where there may be sufficient energy stored but insufficient capacity to dispose of the energy quickly enough): there is enough flexibility in this application, to design a system optimized around the thermal conductivity value of the PCM.
  • PCMs phase-change materials
  • Table 1 shows the list of materials with each material's heat of fusion (hfs), temperature of fusion (T fs), specific heat capacity (Cp), mass and change in enthalpy (dH).
  • FIG. 8 is an illustration of the arrangement of the materials shown in Table 1 with respect to the fluid flow paths and temperatures of flow streams 202 and 108, respectively.
  • the temperature increase in each PCM is limited to the phase transition temperature of the adjacent PCM for illustrative purposes only.
  • the total mass of the TES material required may be reduced to 1.21 from 1.81 by allowing each PCM to warm up to the highest process temperature. Further, the required mass may be reduced to about 0.65 by using only the exemplary high heat capacity material Mix2 to span the whole temperature range.
  • an ammonia-water binary system may be utilized with the shell and tube arrangement 620, 640, or 660.
  • Such an exemplary TES material would be expected to have an hfs of 146 BTU/lbm a Tfs of -103 0 F, a hfg of 589 BTU/lbm, a Tfg of -28 0 F and a Cp of 1.123 BTU/lbm-F and a mass ratio of about 0.27 lbm/lbm.

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  • Oil, Petroleum & Natural Gas (AREA)
  • General Chemical & Material Sciences (AREA)
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Abstract

L'invention concerne des dispositifs, des systèmes et des procédés permettant d'améliorer le rendement énergétique à l'aide de matières à capacité calorifique élevée. Certaines formes de réalisation comprennent une matière à changement de phase (PCM). En particulier, les systèmes comprennent un système de re-gazéification, un système de liquéfaction ou un système intégré utilisant un échangeur de chaleur équipé d'une matrice de régénération, un dispositif d'enveloppe et de tuyaux ou des canaux d'écoulements croisés (p. ex. dispositif de plaques-ailettes) pour stocker l'énergie froide provenant d'un gaz liquéfié dans un système de regazéification se situant dans un premier emplacement, en vue d'une utilisation dans un processus de liquéfaction se situant dans un deuxième emplacement. La matrice de régénération comprend une pluralité de PCM empilées séquentiellement ou une matière à phase continue constituée de multiples PCM. Divers procédés d'encapsulation peuvent être utilisés. Une reliquéfaction peut être mise en oeuvre à l'aide d'un tel système. Les systèmes et procédés de l'invention permettent de rendre commercialement viable du gaz naturel se situant dans des lieux distants par la conversion de celui-ci en gaz naturel liquéfié (LNG), et de transporter et de fournir un tel gaz.
PCT/US2009/068083 2009-02-11 2009-12-15 Procédés et systèmes d'échange de chaleur régénératif Ceased WO2010093400A1 (fr)

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WO2019195581A1 (fr) 2018-04-04 2019-10-10 Active Energy Systems Système d'échange de chaleur destiné à congeler un matériau à changement de phase, et procédés associés
CN111023237A (zh) * 2019-12-16 2020-04-17 北京金茂绿建科技有限公司 基于固体蓄热电锅炉的流体介质加热系统
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US9823014B2 (en) 2011-04-19 2017-11-21 Babcock Ip Management (Number One) Limited Method of cooling boil off gas and an apparatus therefor
WO2012174700A1 (fr) * 2011-06-21 2012-12-27 Linde Aktiengesellschaft Procédés et appareil pour la récupération d'énergie froide
GB2498850A (en) * 2011-12-30 2013-07-31 Weiss Klimatechnik Gmbh Heat exchanger
FR3024223A1 (fr) * 2014-07-28 2016-01-29 Valeo Systemes Thermiques Batterie thermique de stockage comprenant un composant adapte pour stocker et liberer une quantite determinee de chaleur
EP2985562A1 (fr) * 2014-07-28 2016-02-17 Valeo Systemes Thermiques Batterie thermique de stockage comprenant un composant adapte pour stocker et liberer une quantite determinee de chaleur
WO2016027098A1 (fr) * 2014-08-21 2016-02-25 Liquid Gas Equipment Limited Procédé de refroidissement de gaz d'évaporation, et appareil pour ce dernier
KR102379711B1 (ko) 2014-08-21 2022-03-25 엘지이 아이피 매니지먼트 컴퍼니 리미티드 보일 오프 가스의 냉각 방법 및 이를 위한 장치
KR20170043637A (ko) * 2014-08-21 2017-04-21 리퀴드 가스 이큅먼트 리미티드 보일 오프 가스의 냉각 방법 및 이를 위한 장치
CN107810361A (zh) * 2015-06-29 2018-03-16 国际壳牌研究有限公司 再气化端和操作此类再气化端的方法
JP2018520318A (ja) * 2015-06-29 2018-07-26 シエル・インターナシヨネイル・リサーチ・マーチヤツピイ・ベー・ウイＳｈｅｌｌ Ｉｎｔｅｒｎａｔｉｏｎａｌｅ Ｒｅｓｅａｒｃｈ Ｍａａｔｓｃｈａｐｐｉｊ Ｂｅｓｌｏｔｅｎ Ｖｅｎｎｏｏｔｓｈａｐ 再ガス化ターミナル及びそのような再ガス化ターミナルを動作させる方法
CN107810361B (zh) * 2015-06-29 2021-01-29 国际壳牌研究有限公司 再气化端和操作此类再气化端的方法
WO2017001313A1 (fr) * 2015-06-29 2017-01-05 Shell Internationale Research Maatschappij B.V. Terminal de regazéification et procédé pour faire fonctionner un tel terminal de regazéification
JP2019525103A (ja) * 2016-08-23 2019-09-05 シエル・インターナシヨネイル・リサーチ・マーチヤツピイ・ベー・ウイＳｈｅｌｌ Ｉｎｔｅｒｎａｔｉｏｎａｌｅ Ｒｅｓｅａｒｃｈ Ｍａａｔｓｃｈａｐｐｉｊ Ｂｅｓｌｏｔｅｎ Ｖｅｎｎｏｏｔｓｈａｐ 再ガス化端末およびそのような再ガス化端末の操作方法
EP3775748A4 (fr) * 2018-04-04 2022-03-16 Active Energy Systems Système d'échange de chaleur destiné à congeler un matériau à changement de phase, et procédés associés
WO2019195581A1 (fr) 2018-04-04 2019-10-10 Active Energy Systems Système d'échange de chaleur destiné à congeler un matériau à changement de phase, et procédés associés
US12000659B2 (en) 2018-04-04 2024-06-04 Active Energy Systems Heat exchange system for freezing a phase change material and methods thereof
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US12013179B2 (en) 2019-03-27 2024-06-18 LGE IP Management Company Limited Method of cooling boil off gas and an apparatus therefor
CN111023237B (zh) * 2019-12-16 2021-07-09 北京金茂绿建科技有限公司 基于固体蓄热电锅炉的流体介质加热系统
CN111023237A (zh) * 2019-12-16 2020-04-17 北京金茂绿建科技有限公司 基于固体蓄热电锅炉的流体介质加热系统
WO2022157379A1 (fr) 2021-01-25 2022-07-28 L'air Liquide, Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Procede et appareil de separation d'air par distillation cryogenique
FR3119226A1 (fr) 2021-01-25 2022-07-29 L'air Liquide, Societe Anonyme Pour L'etude Et L'exploitation De Procede et appareil de separation d’air par distillation cryogenique

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