WO2008009930A2 - Appareil et procédés pour le transport et le traitement de gaz naturel - Google Patents

Appareil et procédés pour le transport et le traitement de gaz naturel Download PDF

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Publication number
WO2008009930A2
WO2008009930A2 PCT/GB2007/002712 GB2007002712W WO2008009930A2 WO 2008009930 A2 WO2008009930 A2 WO 2008009930A2 GB 2007002712 W GB2007002712 W GB 2007002712W WO 2008009930 A2 WO2008009930 A2 WO 2008009930A2
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WO
WIPO (PCT)
Prior art keywords
natural gas
carbon dioxide
nitrogen
liquid
heat exchange
Prior art date
Application number
PCT/GB2007/002712
Other languages
English (en)
Other versions
WO2008009930A3 (fr
Inventor
Aspelund Audun
Original Assignee
Ntnu Technology Transfer As
Robert, Jackson
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 Ntnu Technology Transfer As, Robert, Jackson filed Critical Ntnu Technology Transfer As
Priority to EP07766280A priority Critical patent/EP2041505A2/fr
Priority to US12/373,551 priority patent/US20100251763A1/en
Publication of WO2008009930A2 publication Critical patent/WO2008009930A2/fr
Publication of WO2008009930A3 publication Critical patent/WO2008009930A3/fr
Priority to NO20090754A priority patent/NO20090754L/no

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/164—Injecting CO2 or carbonated water
    • 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
    • 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
    • F25J1/0015—Nitrogen
    • 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
    • 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
    • F25J1/0027—Oxides of carbon, e.g. CO2
    • 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"
    • F25J1/0035—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"
    • F25J1/0035—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
    • F25J1/0037—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 of a 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
    • F25J1/003—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"
    • F25J1/004—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 flash gas recovery
    • 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
    • F25J1/0221—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 the cold stored in an external cryogenic component in an open refrigeration loop
    • 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
    • F25J1/0221—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 the cold stored in an external cryogenic component in an open refrigeration loop
    • F25J1/0222—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 the cold stored in an external cryogenic component in an open refrigeration loop in combination with an intermediate heat exchange fluid between the cryogenic component and the fluid to be liquefied
    • 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
    • F25J1/0221—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 the cold stored in an external cryogenic component in an open refrigeration loop
    • F25J1/0223—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 the cold stored in an external cryogenic component in an open refrigeration loop in combination with the subsequent re-vaporisation of the originally liquefied gas at a second location to produce the external cryogenic component
    • 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
    • F25J1/0221—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 the cold stored in an external cryogenic component in an open refrigeration loop
    • F25J1/0224—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 the cold stored in an external cryogenic component in an open refrigeration loop in combination with an internal quasi-closed refrigeration loop
    • 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
    • F25J1/0234—Integration with a cryogenic air separation unit
    • 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
    • F25J1/0235—Heat exchange integration
    • F25J1/0236—Heat exchange integration providing refrigeration for different processes treating not the same 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
    • 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
    • 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
    • F25J1/0274—Retrofitting or revamping of an existing liquefaction unit
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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
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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
    • F25J1/0278—Unit being stationary, e.g. on floating barge or fixed platform
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    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/04—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream for air
    • F25J3/04248—Generation of cold for compensating heat leaks or liquid production, e.g. by Joule-Thompson expansion
    • F25J3/04254—Generation of cold for compensating heat leaks or liquid production, e.g. by Joule-Thompson expansion using the cold stored in external cryogenic fluids
    • F25J3/0426—The cryogenic component does not participate in the fractionation
    • F25J3/04266—The cryogenic component does not participate in the fractionation and being liquefied hydrocarbons
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    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
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    • F25J3/04—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream for air
    • F25J3/04521—Coupling of the air fractionation unit to an air gas-consuming unit, so-called integrated processes
    • F25J3/04527—Integration with an oxygen consuming unit, e.g. glass facility, waste incineration or oxygen based processes in general
    • F25J3/04533—Integration with an oxygen consuming unit, e.g. glass facility, waste incineration or oxygen based processes in general for the direct combustion of fuels in a power plant, so-called "oxyfuel combustion"
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    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
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    • F25J3/04—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream for air
    • F25J3/04521—Coupling of the air fractionation unit to an air gas-consuming unit, so-called integrated processes
    • F25J3/04563—Integration with a nitrogen consuming unit, e.g. for purging, inerting, cooling or heating
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2221/00—Handled fluid, in particular type of fluid
    • F17C2221/01—Pure fluids
    • F17C2221/013—Carbone dioxide
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2221/00—Handled fluid, in particular type of fluid
    • F17C2221/01—Pure fluids
    • F17C2221/014—Nitrogen
    • 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
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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
    • 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
    • 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
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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
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/04—Mixing or blending of fluids with the feed stream
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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
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/42—Nitrogen
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/62—Liquefied natural gas [LNG]; Natural gas liquids [NGL]; Liquefied petroleum gas [LPG]
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/80—Carbon dioxide
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • F25J2220/00—Processes or apparatus involving steps for the removal of impurities
    • F25J2220/60—Separating impurities from natural gas, e.g. mercury, cyclic hydrocarbons
    • F25J2220/64—Separating heavy hydrocarbons, e.g. NGL, LPG, C4+ hydrocarbons or heavy condensates in general
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    • F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
    • F25J2230/08—Cold compressor, i.e. suction of the gas at cryogenic temperature and generally without afterstage-cooler
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    • F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
    • F25J2230/20—Integrated compressor and process expander; Gear box arrangement; Multiple compressors on a common shaft
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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
    • F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
    • F25J2230/30—Compression of the feed stream
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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
    • F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
    • F25J2230/42—Processes or apparatus involving steps for increasing the pressure of gaseous process streams the fluid being nitrogen
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
    • F25J2230/80—Processes or apparatus involving steps for increasing the pressure of gaseous process streams the fluid being carbon dioxide
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • F25J2235/00—Processes or apparatus involving steps for increasing the pressure or for conveying of liquid process streams
    • F25J2235/42—Processes or apparatus involving steps for increasing the pressure or for conveying of liquid process streams the fluid being nitrogen
    • 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
    • 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
    • F25J2235/80—Processes or apparatus involving steps for increasing the pressure or for conveying of liquid process streams the fluid being carbon dioxide
    • 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
    • F25J2240/00—Processes or apparatus involving steps for expanding of process streams
    • F25J2240/02—Expansion of a process fluid in a work-extracting turbine (i.e. isentropic expansion), e.g. of the feed stream
    • F25J2240/12—Expansion of a process fluid in a work-extracting turbine (i.e. isentropic expansion), e.g. of the feed stream the fluid being nitrogen
    • 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
    • F25J2260/00—Coupling of processes or apparatus to other units; Integrated schemes
    • F25J2260/42—Integration in an installation using nitrogen, e.g. as utility gas, for inerting or purging purposes in IGCC, POX, GTL, PSA, float glass forming, incineration processes, for heat recovery or for enhanced oil recovery
    • F25J2260/44—Integration in an installation using nitrogen, e.g. as utility gas, for inerting or purging purposes in IGCC, POX, GTL, PSA, float glass forming, incineration processes, for heat recovery or for enhanced oil recovery using nitrogen for cooling purposes
    • 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
    • F25J2260/00—Coupling of processes or apparatus to other units; Integrated schemes
    • F25J2260/80—Integration in an installation using carbon dioxide, e.g. for EOR, sequestration, refrigeration etc.
    • 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
    • F25J2270/00—Refrigeration techniques used
    • F25J2270/14—External refrigeration with work-producing gas expansion loop
    • 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
    • F25J2270/00—Refrigeration techniques used
    • F25J2270/14—External refrigeration with work-producing gas expansion loop
    • F25J2270/16—External refrigeration with work-producing gas expansion loop with mutliple gas expansion loops of the same refrigerant
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
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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
    • F25J2290/00—Other details not covered by groups F25J2200/00 - F25J2280/00
    • F25J2290/12—Particular process parameters like pressure, temperature, ratios
    • 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
    • Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
    • Y02C20/00—Capture or disposal of greenhouse gases
    • Y02C20/40—Capture or disposal of greenhouse gases of CO2
    • 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
    • Y02P90/00—Enabling technologies with a potential contribution to greenhouse gas [GHG] emissions mitigation
    • Y02P90/70—Combining sequestration of CO2 and exploitation of hydrocarbons by injecting CO2 or carbonated water in oil wells

Definitions

  • the present invention relates to the transportation and processing of natural gas, in particular stranded natural gas.
  • LNG Liquefied Natural Gas
  • LNG production has increased by 7 % per year for the last two decades.
  • LNG is mainly used in gas power plants for energy production.
  • Gas that cannot be transported economically by pipeline or large scale LNG facilities is referred to as stranded natural gas.
  • Stranded natural gas can arise due to the inaccessible nature of the source of gas, and also through the remoteness of the source from its market.
  • stranded natural gas Several concepts exist for the utilization of stranded natural gas, among these are: re-injection into an oil reservoir or well for Enhanced Oil Recovery (EOR); Gas to Liquid (GTL); Gas to Hydrates (GTH) and Gas to Wire (GTW). Transport of natural gas to the market or processing site in semi -pressurized vessels, as pressurized LNG, can also be utilised to allow exploitation of minor stranded gas fields. At the end of 2004 a total of 412 billion cubic metres of natural gas, or the equivalent of the Ormen Lange Gas field, had been injected in the North Sea for EOR..
  • CO 2 One candidate that has been considered as an alternative gas for EOR use is CO 2 .
  • the use of CO 2 for EOR has the added advantage that it enables CO 2 that has been produced from the combustion of fossil fuels to be safely stored in the ground instead of being released into the atmosphere where it would act as a greenhouse gas.
  • CO 2 may be transported and injected into a final storage location.
  • Several formations in the North Sea are suitable for a final CO 2 storage.
  • the best known storage is probably the Utsira formation, where 8 million tonnes of CO 2 have been injected from the Sleipner field in the period from 1996 to 2004. Utilizing CO 2 for
  • EOR adds value to the CO 2 due to the resultant increase in oil production.
  • the natural gas that was previously injected for EOR can be exploited as it is replaced by CO 2 .
  • CO 2 the natural gas that was previously injected for EOR can be exploited as it is replaced by CO 2 .
  • EOR is the solution that can introduce an infrastructure for CO 2 handling on a financially sound basis.
  • Statoil and Shell are planning to capture CO 2 from an 860 MW Power Plant at Tjeldbergodden in Norway. 2.5 Million Tonnes of CO 2 are to be transported in a pipeline to the North Sea fields Draugen and Heidrun at Garnbanken and used for EOR.
  • WO 03/066423 which relates to liquid petroleum gas (LPG) rather than natural gas, addresses the problem of reducing CO 2 emissions to atmosphere, and discloses the use of CO 2 for EOR.
  • Liquid CO 2 (LCO 2 ) is transported to an offshore site on a suitable vessel, and is used, at least in part, to provide cooling in a heat exchanger of a separation unit.
  • the separation unit receives a flow of wet gas and condensate and separates this into LPG, dry gas, and condensate.
  • the LPG and condensate are stored on the vessel and transported to an onshore site, whereas the dry gas is passed back to the oil platform for subsequent further transport.
  • the CO 2 used to produce LCO 2 is a product of the combustion of hydrocarbons.
  • the captured CO 2 may then be conditioned to transport specifications, compressed and transported offshore where it is injected in an oil reservoir for EOR.
  • the CO 2 may be transported by pipeline or ship.
  • FPSO Floating Production, Storage and Offloading vessel
  • LNG carrier transports the LNG onshore to the receiving terminal.
  • the LNG is pumped to storage tanks, vaporized and sent to a power plant.
  • the CO 2 may then be liquefied, stored and sent to a CO 2 ship, which transports the LCO 2 to a injection well.
  • an offshore unloading system including pumping, heating and transport of CO 2 to the injection well is required; however, no storage is needed offshore as batch injection actually is favourable for the oil recovery.
  • Figure 1 shows a complete chain for electricity generation with CO 2 capture based on natural gas.
  • the main areas in this chain are; (1) production and transport of natural gas, (2) gas to electricity with CO 2 capture and (3) transport and injection of CO 2 .
  • the problem with conventional standard processes is that there is a lack of integration between the separate parts of the chain. It would therefore be advantageous to create an integrated energy and cost effective transport chain, in particular for stranded natural gas, for power production with CO 2 capture where the CO 2 is used for EOR.
  • WO 96/17766 discloses one prior art method of obtaining LNG offshore in which a conversion plant is provided on a tanker to produce LNG from natural gas.
  • Natural gas which is largely methane, cannot be liquefied by just increasing the pressure as with heavier hydrocarbons used for energy purposes. To liquefy natural gas it is necessary to greatly reduce the temperature. As will be appreciated, this involves significant energy input at the source of natural gas, and can also result in large and complex equipment being required at the source, which, as in WO 96/17766, is often offshore and in particular with stranded natural gas the source is, by its nature, not easily accessible.
  • cryogenic exergy in LNG is roughly 1.5 % of the chemical potential and it would be advantageous to utilize this exergy.
  • a cold carrier between the production and receiving terminals can be used to reduce the overall losses by effectively recycling the energy investment made when liquefying the natural gas.
  • Two main cold carriers have been proposed, nitrogen and CO 2 .
  • US 3,400,547 discloses a process for liquefaction and transportation of natural gas in which Liquid Inert Nitrogen (LIN) or liquefied air is used as a cold carrier.
  • LIN or liquid air is transported to the field site (the source of natural gas) by cryogenic tanker ship, and used to cool and liquefy the natural gas to produce LNG. This reduces the equipment required at the field site.
  • the gaseous nitrogen or air produced can simply be vented to atmosphere.
  • the LNG is then pumped into the same cryogenic tanker ship and transported to an onshore site, where regasification of the LNG is used to liquefy air or nitrogen, which is then shipped to the field site.
  • the 'cold energy' stored in the LNG and liquefied air or LIN is constantly recycled to reduce energy usage.
  • Some form of energy input is required at the onshore site, to ensure that sufficient heat energy can be removed from the natural gas at the field site, and thereby avoid the need for any energy input offshore.
  • US 3,400,547 also teaches that when LIN is used as the cold carrier, oxygen is advantageously produced as a by-product of the separation of air to form LIN.
  • JP 08269469 discloses the use of CO 2 in the form of dry ice as a cold carrier.
  • CO 2 is separated from a combustion exhaust gas and recovered as dry ice by utilising cold stored as LNG liquefaction energy.
  • the dry ice is then transported to a LNG production centre, where natural gas is liquefied using the cold generated by the sublimation of dry ice.
  • the CO 2 gas formed in this step is used in a methane synthesis unit to produce methane, which is then preferably mixed with natural gas.
  • a combination of CO 2 and LIN for peakshaving LNG plants is suggested in DE 2014776, which discloses a natural gas liquefaction process in which LCO 2 and also optionally LIN are used as cold carriers. Natural gas is piped to a shipping site, where LIN and LCO 2 are used to liquefy the gas for transportation to a consumer site in the form of LNG. At the consumer site the LNG is regasified and used to liquefy CO 2 and Nitrogen, which is then transported to the shipping site.
  • US 2003/089125 discloses a natural gas liquefaction process for use offshore where a carbon dioxide pre-cooling circuit is provided in a cascade arrangement with a main cooling circuit.
  • the refrigerant in the main cooling circuit can be nitrogen based.
  • the inventors have developed an energy- and cost- effective transport chain for natural gas, in particular for stranded natural gas, utilized for power production with CO 2 capture and storage. It includes a remote or offshore section for LNG production, a combined gas carrier, and a market or onshore section.
  • the present invention provides a method of liquefaction of natural gas supplied by a field site, the method comprising the steps of: providing supplies of liquid nitrogen and liquid carbon dioxide, performing a heat exchange process between the liquid nitrogen and the liquid carbon dioxide and the natural gas to thereby liquefy the natural gas, wherein the heat exchange process is arranged so that the resultant carbon dioxide is in gaseous or supercritical form at a pressure suited for enhanced oil recovery.
  • the "field site” is the location of the remote LNG production section which may be offshore or seaside onshore.
  • the gas is indeed injected into ground formations as part of an enhanced oil recovery process.
  • the gas may be injected into any suitable formation, or indeed into deep sea, for sequestration.
  • the quantities, or at least the relative proportions, of natural gas and carbon-dioxide are preferably pre-determined.
  • the natural gas can be transported in an onshore (or offshore) pipeline from the reservoir to the production site or market site where it is liquefied.
  • the CO 2 can be transported in an onshore (or offshore) pipeline to the reservoir.
  • the market site is generally onshore, however, it may be placed offshore to take account of safety or space requirements near the market.
  • the phrase market site includes both possibilities.
  • references to CO 2 , nitrogen and oxygen, in both gaseous and corresponding liquid forms, should generally be taken to mean a substance containing those gases to such extent that the disturbing influence of other components is avoided. It will of course be appreciated that depending upon the specific circumstances varying degrees of purity and/or contamination can be allowed without detrimental effect.
  • the invention is not limited only to the use of nitrogen. Instead, it is only necessary that the cold carrier used in conjunction with LCO 2 to liquefy the natural gas is a substance having a boiling point lower than that of LNG that can be utilised in a heat exchange process in the same way as LIN.
  • the present invention provides an apparatus for liquefaction of natural gas, the apparatus being arranged to receive liquid nitrogen, liquid carbon dioxide and natural gas, wherein the apparatus comprises: a heat exchange device for transferring heat between the natural gas and the liquid nitrogen and the liquid carbon dioxide to thereby liquefy the natural gas, and wherein the heat exchange device is arranged such that the resultant carbon dioxide is in gaseous or supercritical form at a pressure suited for injection for enhanced oil recovery.
  • the invention enables CO 2 ready for EOR to be produced from a natural gas liquefaction process.
  • the natural gas of the second aspect is preferably supplied by a field site and more preferably the apparatus is arranged to receive natural gas at the field site.
  • the CO 2 can then be used for EOR at the field site, thus leading to environmental benefits as discussed above.
  • Cold energy stored in the LCO 2 and LIN is transferred to natural gas, but contrary to conventional heat exchange processes the CO 2 does not finish at atmospheric conditions, and instead is provided at a pressure suitable for EOR. IfEOR is not required, then the CO 2 produced may be readily sequestered for final storage, for example in a suitable geological formation.
  • LCO 2 as a 'cold carrier' in conjunction with LENf has advantages in efficiency as discussed for example in DE 2014776.
  • the method and apparatus of the first and second aspects is particularly advantageous when the field site is an offshore installation, and therefore in a preferred embodiment the liquefaction occurs offshore with the natural gas being sourced from an offshore installation.
  • the heat exchange process or device is arranged to be self-sufficient with power, such that no power input is required to run the process.
  • heat exchangers, compressors, expanders and pumps may be used, and preferably the power output of the expanders is balanced against the power input for the compressors and pumps.
  • the apparatus at the field site and in particular the heat exchanger can be made to be simple and self-sufficient.
  • the resultant nitrogen is substantially returned to atmospheric conditions, and vented to atmosphere, with the cold energy stored by the liquid nitrogen transferred to the natural gas during the liquefaction.
  • a combined carrier which initially contains the liquid nitrogen and the liquid carbon dioxide.
  • the liquefied natural gas is loaded onto the combined carrier.
  • the combined carrier may be a gas transport vessel, preferably a multigas ship, particularly in the case where the field site is an offshore installation.
  • the liquefied natural gas is stored ⁇ n the same storage vessels on the combined carrier as the liquid nitrogen and the liquid carbon dioxide. This allows more efficient utilisation of the carrier, particularly in comparison to the prior art situation where the LNG and LCO 2 are transported in completely separate vessels.
  • the heat exchange device is provided on the combined carrier. This avoids the problematic cryogenic transfer of LNG, LCO 2 and LIN between the combined carrier and the field site, as all transfers will be in the gaseous or supercritical phase. Further, expensive modification to the field site is not required, and instead the combined carrier may be advantageously arranged to interact with existing apparatus on current field sites.
  • the heat exchange process/device may include one or more heat exchangers, compressors, expanders and pumps, the arrangement of which is preferably optimised for efficiency using conventional techniques.
  • the arrangement is such that the two phase region is avoided in at least one of and preferably all of the nitrogen, carbon dioxide and natural gas paths.
  • the heat exchange process does not include any additional refrigeration, and in particular does not require the use of hazardous materials such as flammable refrigerants.
  • hazardous materials such as flammable refrigerants.
  • the present invention provides a method of producing natural gas, liquefied carbon dioxide and liquefied nitrogen comprising: providing amounts of liquefied natural gas, gaseous carbon dioxide and gaseous nitrogen, and transferring heat from the carbon dioxide and nitrogen to the liquefied natural gas in order to gasify the natural gas and liquefy the carbon dioxide and nitrogen.
  • the present invention provides an apparatus comprising a heat exchanger, the apparatus arranged to receive liquefied natural gas, gaseous carbon dioxide and gaseous nitrogen and to produce liquid carbon dioxide and liquid nitrogen by gasification of the liquefied natural gas and transfer of heat from the carbon dioxide and nitrogen to the liquefied natural gas.
  • LNG is used to liquefy nitrogen and carbon dioxide.
  • the resultant LCO 2 and LIN can then be utilised as cold carriers, and can be transported to a source of natural gas and used to liquefy the natural gas.
  • a continuous process can thus be established in which the cold energy of the liquefied gases is recycled during each stage of transport.
  • both LCO 2 and LIN are produced and these can then be used to meet the requirements of an offshore natural gas liquefaction process as described in relation to the first and second aspects above.
  • the process is arranged such that all of the input LNG is gasified, and all of the input gaseous CO 2 and nitrogen is liquefied.
  • the apparatus may also include one or more further components selected from heat exchangers, compressors, expanders and valves.
  • the function of such components is to increase the efficiency of the processing of the various liquid and gaseous materials, and to allow repeated heat exchange stages either over multiple heat exchangers or by cycling the materials several times through the same heat exchanger.
  • the LNG is preferably initially at atmospheric pressure and is compressed, preferably by pumping, prior to regasification to avoid compression in the gas phase after heat exchange.
  • the CO 2 and nitrogen may also be initially at atmospheric pressure and thus are compressed prior to being liquefied.
  • the CO 2 is preferably compressed to a pressure higher than its triple point (5.2 bar) before it is liquefied to avoid dry-ice formation.
  • the nitrogen is compressed to a pressure higher than the transport pressure in order to be liquefied by heat exchange with the LNG. Receiving nitrogen and/or CO 2 at higher pressures will increase the efficiency and reduce the investment costs and is therefore preferable.
  • the output natural gas is at above atmospheric pressure. This makes later handling and transport of the gas easier.
  • the LCO 2 is transported at a pressure higher than the triple point (TP) and preferably at as low a pressure as possible above the triple point, for example 5.5 bar, to increase ship utilization.
  • the LIN can be transported at ambient pressure, or preferably elevated pressure, for example at 6 bar, to increase the total chain efficiency. , Compression and/or expansion of the various materials during the heat transfer, liquefaction and regasification process helps to improve the efficiency of this process.
  • the natural gas process may comprise compression and/or pumping along with heating by heat exchange with the carbon dioxide and nitrogen.
  • the nitrogen process preferably includes compression followed by cooling by heat exchange with the natural gas to produce liquid nitrogen (LIN).
  • a valve may be used to reduce the pressure of the LIN to a pressure suitable for transport. Flash gas produced at the valve is preferably recycled to the compressor and may be used in heat exchange to cool the incoming nitrogen gas and/or carbon dioxide.
  • Liquefaction of the carbon dioxide may be achieved by compression followed by heat exchange with the natural gas. After compression the carbon dioxide may be cooled by ambient air or water coolers to ambient temperatures. Preferably the compression is a multi-stage compression process, and in a preferred embodiment the carbon dioxide is split into two streams after a compression stage is complete, with one stream being cooled by heat exchange with the natural gas, and the other stream being compressed further before cooling to achieve a better utilization of the LNG cold and thereby a higher efficiency.
  • an air separation unit produces the nitrogen to be liquefied.
  • the ASU may be powered from an external source.
  • the ASU will also produce oxygen, which may be used for an Oxyfuel Power Plant, where oxygen along with natural gas, which is preferably sourced from the regasified natural gas, is converted to electricity, CO 2 and water.
  • oxygen along with natural gas, which is preferably sourced from the regasified natural gas, is converted to electricity, CO 2 and water.
  • the water is removed from the CO 2 during the compression process before the CO 2 is liquefied by the LNG.
  • the CO 2 Prior to liquefaction the CO 2 is preferably compressed to a pressure above the triple point to avoid dry ice formation.
  • CO 2 for liquefaction may be provided by an external industrial source such as steel and cement industry, or a coal, bio-mass or natural gas fired power plant with CO 2 capture.
  • the LCO 2 together with LIN is preferably transported to a field site, such as an offshore site, in a combined gas carrier.
  • the LCO 2 may be regasified and utilised for EOR, preferably in accordance with the first and second aspects of the invention and the preferred features thereof with the LIN similarly being regasified, and then vented to atmosphere.
  • the present invention provides a method of producing natural gas, liquefied carbon dioxide and liquefied nitrogen comprising the steps of: providing a (preferably predetermined) amount of liquefied natural gas, using a part of the liquefied natural gas in the separation of air to produce oxygen and liquid nitrogen by regasifying the natural gas, and combusting the oxygen and at least part of the regasified natural gas in a power production plant.
  • the present invention provides an apparatus for carrying out the method of the fifth aspect, the apparatus comprising: an air separation unit which receives liquefied natural gas and air, and produces oxygen, liquid nitrogen and regasified natural gas, and a power production plant which combusts the oxygen and regasified natural gas.
  • oxygen which is produced as a by-product of the transfer of cold energy from the LNG to LIN is.utilised for combustion with the natural gas to thus produce power.
  • LIN is made available for use as a cold carrier, which may be transported to a source of natural gas and used in the liquefaction of the natural gas.
  • the cold energy stored in the LNG is therefore not wasted.
  • the efficiency of the process as a whole is enhanced.
  • carbon dioxide produced by the combustion process is captured.
  • the carbon dioxide is liquefied by gasification of another part of the liquefied natural gas.
  • the regasified natural gas produced may be used in the combustion process.
  • the power production plant is an Oxyfuel power plant, which combusts oxygen and natural gas to produce water, carbon dioxide and electricity.
  • Carbon dioxide may be added to the oxygen prior to combustion to reduce the combustion temperature. This carbon dioxide may be sourced from the carbon dioxide emitted by combustion.
  • Liquefaction utilising cold energy stored in the LNG provides LCO 2 as a cold carrier, and allows the CO 2 produced by the power production plant to be transported for storage elsewhere.
  • the LCO 2 is used for EOR.
  • the capture and liquefaction of carbon dioxide allows the above process, which in preferred embodiments occurs at an onshore market site, to be integrated with the natural gas liquefaction process of the first and second aspects.
  • Oxyfuel power plant is preferred, as this type of power plant provides clean and efficient power production from natural gas and oxygen.
  • the end result of a process including the Oxyfuel plant is electricity, water, LCO 2 and LIN.
  • the latter two products may be used as a cold carrier, with the LCO 2 preferably being regasified and utilised for EOR, preferably in accordance with the first and second aspects of the invention and the preferred features thereof and the LIN similarly being regasified, and then vented to atmosphere.
  • regasification of LNG in an efficient integrated process results in more natural gas than can be combusted using the oxygen which is produced. Therefore, in a further preferred embodiment, an additional power production plant is provided for the combustion of the excess regasified natural gas.
  • This may be any power plant, preferably one with CO 2 capture.
  • the present invention provides a method for transportation and processing of natural gas, the method comprising the steps of: using liquid nitrogen and liquid carbon dioxide in a heat exchange process to liquefy natural gas supplied by a field site, transporting the liquefied natural gas to a regasification plant, utilising at least a part of the liquefied natural gas in a heat exchange process to produce liquid nitrogen and liquid carbon dioxide, and transporting the liquid nitrogen and liquid carbon dioxide to be used for further liquefaction of natural gas supplied by the field site.
  • the present invention provides an apparatus for transportation and processing of natural gas, the apparatus comprising: a heat exchange device which utilises liquid nitrogen and liquid carbon dioxide to liquefy natural gas supplied by a field site, a carrier which transports the liquefied natural gas to a regasification plant, the regasification plant comprising a regasification apparatus that utilises at least a part of the liquefied natural gas in a heat exchange process to produce liquid nitrogen and liquid carbon dioxide, and a carrier which transports the liquid nitrogen and liquid carbon dioxide to be used by the heat exchange device for further liquefaction of natural gas supplied by the field site.
  • the seventh and eighth aspects provide a method and apparatus in which an efficient energy chain is provided, where LIN and LCO 2 are used as cold carriers to recycle cold energy stored in LNG.
  • Preferred features of the seventh and eighth aspects are discussed below and should be taken to include apparatus and method features equivalent to the method and apparatus features described as appropriate.
  • the field site may be an offshore installation, and the regasification and optionally power production may occur at a market site, preferably an onshore or seaside offshore market site.
  • the liquid carbon dioxide used as a cold carrier may be output from the heat exchange device at a pressure suitable for EOR, and/or heat exchange between the liquid carbon dioxide and liquid nitrogen and the natural gas may occur as discussed above.
  • the transportation of liquefied natural gas and the liquid carbon dioxide and liquid nitrogen may occur in a combined carrier as discussed above.
  • the regasification site may be an onshore site and may include an Oxyfuel power plant as the power production plant.
  • the seventh or eighth aspect may include the use of some of the LNG in an ASU to produce the liquid nitrogen and also oxygen.
  • the LCO 2 is preferably produced using the remainder of the LNG.
  • the oxygen which is also produced can advantageously be used in the combustion of the regasified natural gas. Undesirable carbon dioxide emissions may be avoided by capture and liquefaction of the carbon dioxide produced by combustion.
  • the regasified natural gas which is combusted is preferably the gas produced by the air separation unit and/or the gas produced after liquefaction of carbon dioxide.
  • the regasified natural gas in another process, or to store it for later use in another process.
  • the natural gas for combustion may be obtained from this storage, or may be from another source.
  • the CO 2 may be obtained from the other process, or from an alternative source
  • the liquid nitrogen and liquid carbon dioxide produced by regasification of the liquefied natural gas will not be sufficient to then liquefy a corresponding amount of natural gas supplied from the field site in a subsequent cycle. Therefore, in a preferred embodiment, additional liquefied natural gas is supplied to the regasification site (market site) from a different source.
  • the market site may be situated at or adjacent a liquefied natural gas processing plant for this purpose. This will reduce the required power input to complete the liquefaction of sufficient nitrogen and carbon dioxide . Electricity produced by the power production plant may be utilised as the additional power.
  • the cycle will not produce sufficient oxygen from the separation of air to combust all of the regasified natural gas in the preferred Oxyfuel power plant. Therefore, in a preferred embodiment a further power plant, preferably with CO 2 capture, for example a post combustion or pre combustion power plant, is provided.
  • the regasified natural gas may be split between the Oxyfuel plant and the other power plant in a ratio of, for example, 25% to 75%.
  • Carbon dioxide produced by the other power plant is preferably captured and liquefied as discussed above.
  • substantially all carbon dioxide produced by combustion of the natural gas is captured for use for EOR.
  • Intermediate storage may be provided between the processes and carrier at both the field site and market site and is the preferred solution at the market site.
  • the use of intermediate storage allows continual operation of the offshore, onshore and transport parts of the cycle without the need for one part of the cycle to be delayed by down-time or differences in production or usage rates in another part of the cycle.
  • Figure 1 shows an example of a complete chain from natural gas well to CO 2 storage
  • Figure 2 shows schematically a simplified natural gas transport chain and the full processing chain in accordance with an embodiment of the present invention
  • FIG. 3 shows schematically a more detailed natural gas transport and processing chain in accordance with an embodiment of the present invention
  • Figure 4 shows the required amount of LIN and LCO 2 , the thermo-mechanical exergy content in the streams and the exergy conversion efficiency for the field site LNG process;
  • Figure 5 is a process flow diagram for an offshore LNG process
  • Figure 6 is a pressure-enthalpy diagram for the natural gas path in the offshore process of Figure 5 ;
  • Figure 7 is a pressure-enthalpy diagram for the CO 2 path in the offshore process of Figure 5;
  • Figure 8 is a pressure-enthalpy diagram for the nitrogen path (logarithmic pressure) in the offshore process of Figure 5;
  • Figure 9 shows composite curves for the heat exchangers HX-IOl and HX- 102 of
  • Figure 10 shows composite curves for the heat exchangers HX-IOl and HX- 102 of Figure 5 for pressurized LNG;
  • Figure 11 shows the amount of LNG, LIN and LCO2, the thermo-mechanical exergy content in the streams and the exergy conversion efficiency for the market site LNG regasification process;
  • Figure 12 is a schematic process flow diagram for the onshore market site LNG regasification process
  • Figure 13 is a pressure-enthalpy diagram for the natural gas process path in the onshore process of Figure 12;
  • Figure 14 is a pressure-enthalpy diagram for the nitrogen process path in the onshore process of Figure 12;
  • Figure 15 is a pressure-enthalpy diagram for the carbon dioxide process path in the onshore process of Figure 12;
  • Figure 16 shows composite curves for the main exchangers in the onshore process of Figure 12; for atmospheric transport pressure of LNG and
  • Figure 17 shows composite curves for the main cold end heat exchanger of Figure 12 when LNG at an increased pressure is used
  • Figure 18 shows, for the embodiment of Figure 2, 4 and 12, the ship utilisation and required LCO 2 and LIN versus ship- and LNG pressure;
  • Figure 19 shows for the embodiment of Figure 2, 4 and 12, the exergy efficiency versus ship- and LNG pressure
  • Figure 20 shows the exergy efficiency for the simple transport chain showed in the inner part of Figure 2;
  • Figure 21 shows the exergy efficiency for the total transport chain shown in the part Figure 2 and Figure 3;
  • a transport chain following interactions as shown in Figure 1 is implemented in an improved integrated form as shown in Figure 2.
  • This simple transport chain is shown in the inner part of Figure 2 and includes a field site section, a combined gas carrier and an integrated receiving terminal or market site.
  • natural gas is liquefied to LNG by Liquid Carbon Dioxide (LCO 2 ) and Liquid Inert Nitrogen (LIN), which are used as cold carriers.
  • LCO 2 Liquid Carbon Dioxide
  • LIN Liquid Inert Nitrogen
  • the nitrogen is emitted to the atmosphere at ambient conditions.
  • the CO 2 at high pressure is transferred to an offshore oilfield for Enhanced Oil Recovery (EOR).
  • EOR Enhanced Oil Recovery
  • the LNG is transported to the receiving terminal or market site (generally onshore) in the a combined carrier, which is described in further detail below.
  • the cryogenic exergy in LNG is recovered by liquefaction of CO 2 and nitrogen, which can be provided by external sources.
  • An embodiment of the onshore process is also provided in detail below.
  • An expanded embodiment where the process also provides both the nitrogen and CO 2 itself will be discussed.
  • the cold carriers are the foundation in an integrated transport chain for stranded natural gas utilized for power production with CO 2 capture where the CO 2 is used for EOR.
  • the simple transport chain is integrated with an air separation unit (ASU) and a conventional oxyfuel arrangement that provides CO 2 and nitrogen to the transport chain.
  • a schematic of such an energy chain is shown in Figure 2 where the field site is an offshore installation and the market site is an onshore site.
  • Liquefied Energy Chain Liquefied Energy Chain (LEC)
  • the onshore process is connected to an air separation unit (ASU) that produces nitrogen for the offshore process and oxygen for an Oxyfuel Power Plant, where natural gas is converted to electricity, CO 2 and water.
  • ASU air separation unit
  • the water is removed from the CO 2 which is compressed to a pressure above the triple point and liquefied by vaporization of the remaining LNG.
  • the LCO 2 together with LIN are transported offshore in the combined gas carrier.
  • the LEC is integrated with an external LNG receiving terminal providing additional cold exergy that is normally not utilized to the transport chain.
  • the processes are designed using a new methodology for Process Synthesis (PS) extending traditional Pinch Analysis (PA) with exergy calculations.
  • PS Process Synthesis
  • PA Pinch Analysis
  • ExPAnD Extended Pinch Analysis and Design
  • the procedure shows great potential for minimizing total shaft work in sub ambient processes. This is achieved by optimizing compression and expansion work for the process streams together with the work needed to create necessary cooling utilities.
  • the methodology and a detailed description of the development of the offshore process can be found in the work by A. Aspelund, D.O. Berstad, T. Gundersen entitled "An Extended Pinch Analysis and Design Procedure utilizing Pressure based Exergy for Subambient Cooling", Applied Thermal Engineering (2007), doi 10.1016/j. applthermaleng, 2007.04.017.
  • the design philosophy is to create a field site process that is self-supported with power and hot and cold utilities. . Hence, the required power and utilities for the energy chain is provided at the market site terminal.
  • the processes are based on state-of-the-art equipment with standard industrial efficiencies and it is designed to have high exergy efficiency; however, efforts are made to keep the number of equipment units low.
  • Equipment data are found in Table 1, ambient data and feed gas properties in Table 2.
  • Liquid expanders Isentropic efficiency 85 %
  • FIG 3 shows a more detailed flow diagram of a LEC developed for utilization of stranded natural gas from depleting oilfields with associated gas.
  • Associated gas 4 from an offshore oil field 6 is transferred to a combined carrier 8 via a short sub-sea pipeline, a riser and a Submerged Turret Loading (STL) anchoring system.
  • the STL concept is described in WO 96/17766. Other conventional gas transfer systems could of course be used.
  • the combined carrier 8 can be a multigas ship 8 as shown in figure 4.
  • the combined carrier 8 transports LCO 2 and LIN on the outbound stage, and LNG on the inbound stage.
  • the LNG process is placed on the combined carrier which is connected to the offshore oil field throughout the process.
  • the combined carrier 8 high pressure natural gas is cooled against LCO 2 before it is expanded and cooled by LIN to LNG.
  • the combined carrier 8 is simply equipped to load/unload and transport the liquids, and the liquefaction of natural gas occurs at a facility provided on the offshore installation 2 (for example, an oil platform), or at another location.
  • the nitrogen 10 is vented to atmosphere at ambient conditions.
  • the CO 2 at high pressure 12 is transferred to an offshore oilfield for EOR 14 through a flexible riser and a short subsea pipeline. It is advantageous that the LNG production process is arranged to have, as an end product, CO 2 at a pressure suited for EOR. This CO 2 can easily be directly injected as EOR, or stored for injection at an appropriate time, without the need for any further processing.
  • the combined carrier transports approximately one volume of LIN to two volumes OfLCO 2 , with three volumes of LNG then being transported back to the receiving site.
  • Intermediate storage 16 can be used between the carrier and the onshore site for LCO 2 , LIN and LNG, and also at the offshore installation for natural gas from the well.
  • the ship unloads the cargo to an intermediate storage and simultaneously loads a new cargo LCO 2 and LIN.
  • ASU Air Separation Unit
  • the ASU 20 produces LIN for the offshore process and advantageously also oxygen.
  • the oxygen is used in an Oxyfuel power plant 22 of a conventional type, where the natural gas is converted to electricity, CO 2 and water.
  • CO 2 is mixed with the oxygen prior to combustion in order to avoid excessively high temperature, which would damage the Oxyfuel plant 22 components.
  • This input CO 2 can be sourced from the CO 2 produced by combustion.
  • the water is removed from the CO 2 which is compressed to a pressure above the triple point (TP) and liquefied by vaporization of the remaining LNG.
  • TP triple point
  • the additional energy input required can be sourced, in one embodiment, from the electricity produced by the Oxyfuel plant or from the grid.
  • additional LNG from another source can be utilised as a source of cold energy to further reduce the energy requirement.
  • the output of the onshore process is water, electricity, LCO 2 and LIN, with the LCO 2 and LIN being transported offshore by the combined carrier, where the cold energy is recovered, with the resultant nitrogen and CO 2 being vented 10 and used for EOR 14 respectively.
  • the transport chain is especially suited for tail production of oilfields with associated gas, where the gas is used for injection.
  • CO 2 for EOR will increase the lifetime of the oilfield, thus also increase the total oil production.
  • the ship utilization is defined as the total volume of LNG, LIN and LCO 2 transported divided over two times the ship volume and thereby reflects the total capacity of the ship.
  • the utilization rate of the combined carrier 8 can vary between 70 and 100 % depending on the LNG and LIN transport pressure.
  • CO 2 is most preferably transported at a pressure as close to the triple point (TP) as possible.
  • the density is higher at lower pressures and also the exergy density is higher as the temperature is lower.
  • the LNG (and LIN) can be transported at any pressure between 1 bar and maximum ship vessel pressure. The following process description assumes a LIN pressure of 6 bar and a NG pressure of 1 bar for maximum exergy efficiency. The reason for these transport pressures is that the cold exergy in the LNG is reused at the receiving terminal; hence, although more cold duty is required offshore at low pressure, the irreversibilities are smaller, resulting in a higher efficiency for the total chain.
  • FIG. 5 shows one configuration of the LNG/LCO 2 -LIN offshore natural gas liquefaction process.
  • the offshore process is self-powered and so does not need an external power source. In addition, it can operate with little rotating equipment and without . flammable refrigerants.
  • the power produced by the expanders is used to power the compressors and pumps.
  • Another characteristic of the process is cooling of dense-phase natural gas against sub-cooled liquid CO 2 at high pressure.
  • the CO 2 is still in liquid form at ambient temperature and is pumped to injection pressure and injected for EOR. This is beneficial as no power input is required offshore to prepare the transported CO 2 for use in EOR, but instead the gas at injection pressure is produced from the liquefaction process, which is self-powered.
  • the cold dense-phase NG is expanded to a pressure and temperature close to the bubble point, e.g. 55 bar and -63 0 C and sub cooled by high pressure LIN before it is expanded to transport pressure.
  • the LIN is pumped to high pressure (100 bar), heated to about -40°C and then expanded in one, preferably two, possibly several stages to utilize the pressure exergy.
  • the hot end of the nitrogen gas can be used in addition to the liquid CO 2 in the first cooling stage.
  • the fluids exchange heat in the dense, liquid or gaseous phase in order to avoid going through the two phase region. Therefore the heat capacity flow rate is close to constant, enabling energy exchange with small exergy losses. Since the process streams entering the heat exchangers are in single phase, mal-distribution due to two-phase flow in the manifold system is avoided.
  • Figure 4 shows the inlet and outlet streams and utilities for the offshore process.
  • the required LIN and LCO 2 flow rates are given in kg/kg LNG.
  • the figure also shows the thermo-mechanical exergy content in the streams and the transient exergy efficiency.
  • a process flow diagram for the offshore LNG process is shown in Figure 5.
  • Natural gas NG at 15 0 C and 70 bar NG-I is compressed to 100 bar, a pressure higher than the cricondenbar pressure, and cooled by liquid CO 2 and gaseous nitrogen in HX-IOl.
  • the cooled natural gas in dense phase NG-3 is expanded in a dense phase expander to 50 bar, which is close to the bubble point line. It is further sub-cooled to -164 °C before it is expanded to transport pressure and stored in an LNG tank.
  • Stream NG-6 is preferably at the bubble point to avoid purge or recycling.
  • the NG process path is shown in a pressure- enthalpy diagram in Figure 6.
  • Liquid CO 2 CO2-1 is pumped from transport pressure at e.g. 5.5 bar and Bubble Point (BP) temperature to 60 bar before it is heated in HX-IOl.
  • the CO 2 pressure must be high enough to avoid vaporization.
  • the CO 2 is then pumped to injection pressure.
  • the CO 2 process path is shown in a pressure-enthalpy diagram in Figure 7. After heating and pumping, the CO 2 is transferred to an oil reservoir for EOR.
  • N2-1 is pumped from transport pressure of, for example, 6 bar and -170 0 C to 100 bar before it enters the cold-end main heat exchanger HX- 102, where the dense-phase nitrogen is heated to approximately -80 0 C. The nitrogen is further heated to - 40 0 C in HX- 101 before it is expanded to 10 bar in EXP- 101. Then the nitrogen gas N2-5 at -160 0 C is sent to HX- 102 and HX-IOl where it is heated to -80 and -40 0 C respectively. The nitrogen gas N2-7 is compressed to 20 bar and cooled by CO 2 to -40 0 C in HX-IOl.
  • the gas N2-9 is then expanded to 1.4 bar in EXP- 102 and sent to HX- 102 and HX-IOl where it is heated to -80 and 20 0 C respectively. Finally, nitrogen N2-12 at atmospheric pressure and close to ambient temperature is emitted to the atmosphere. A cold vent system should be utilized to avoid accumulation of nitrogen alongside the gas carrier. The nitrogen process path is shown in a pressure-enthalpy diagram in Figure 8.
  • the Composite Curves for HX- 102 and HX-IOl are shown in Figure 9.
  • the process design starts in the cold end of HX-102.
  • the NG is to be cooled to -164 0 C to avoid flashing of gas after expansion.
  • Pumping the LIN from 6 bar to 100 bar leads to a temperature increase from -177°C to -171 0 C. Since the heat capacity flow rate of the LIN is less than for the NG a temperature of -160 0 C or less is required after expansion in order to obtain a pinch point at the cold end of the heat exchanger.
  • the nitrogen gas is expanded from -40 0 C to -160 0 C in two stages.
  • the cold pinch point should be - 49 °C / -52 °C which corresponds to the CO 2 inlet temperature. The reason for this is that it, from a both energy efficiency and ship utilization point of view, is desirable to use as little LIN as possible.
  • the NG leaves the heat exchanger at -68 0 C.
  • the cooling duty in the cold end of the heat exchanger is provided by cold gaseous nitrogen coming HX- 102.
  • the nitrogen streams from HX-101 are emitted at -40 0 C to obtain a cold enough temperature after expansion in EXP-101 and EXP- 102.
  • the hot stream outlet of HX- 102 can also be increased.
  • the required NG temperature before expansion is increased from -164°C to -136°C.
  • the required cooling duty for the NG stream is then reduced, which results in a reduction in required nitrogen.
  • nitrogen is already close to maximum pressure and it is therefore not possible to increase the temperature at the cold end of the cold Composite Curves.
  • the Composite Curves for the heat exchangers HX-IOl and HX- 102 for production of semi pressurized LNG (6 bar) is shown in Figure 10.
  • the NG to be liquefied is at ambient temperature and a pressure of 70 bar. It is treated for water, CO 2 and heavy hydrocarbons (HHC) that would freeze out. It has a "normal" LNG composition with a dew point of -48 0 C at 55 bar and contains one mole % of nitrogen. If too much HHC are present, they will have to be removed. This can be done by pre-cooling the NG to -20 °C in HX-IOl, expand the NG into the two phase area e.g. 50 - 60 bar in a compander (expander and compressor on the same shaft), which also recompresses NG. The HHC are separated from the NG in a fractionation column.
  • HHC heavy hydrocarbons
  • the column condenser should be cooled with LCO 2 .
  • the NG is then compressed to 100 bar.
  • the required compressor duty will not increase as the temperature of the gas to compressor K-100 will be lower than the ambient temperature, thereby reducing the shaft-work needed for compression.
  • the exact HHC removal process depends on the feed gas composition and the LNG transport pressure. The more HHC present in the stream the more cooling in HX- 101 is required. Additional cooling can be provided by increasing the amount OfLCO 2 .
  • Freeze-out of water, CO 2 or HHC will plug the narrow channels (2-3 mm) in the plate-fin heat exchangers. Hence, all water and most of the HHC and CO 2 must be removed.
  • the freeze-out temperature of HHC and CO 2 is strongly dependent on the amount present; hence the mole fraction gives the lowest temperature for the LNG in the heat exchangers.
  • HHC can easily be removed in the process, the remaining discussion will focus on CO 2 . Normally CO 2 will be removed by adsorption for fractions lower than 1 -2 mole % and by absorption for larger fractions. Both technologies are space- and energy- demanding and should be avoided offshore if possible.
  • the wall temperature at the hot side may be lower than the hot fluid temperature, thus CO 2 may freeze out on the wall, plugging the channels. This can be avoided by placing an indirect cooling circuit between the cold LIN and the LNG.
  • One solution is to use a dense- phase nitrogen circuit at 50 bar.
  • the power generated in the expanders is equal to the power needed in the compressors and pumps. If additional power is supplied to the process, the pressure after the nitrogen compressor K-IOl can be increased giving a larger cooling duty in the streams from the expanders. Hence, the outlet temperature of the nitrogen from HX-IOl can be increased, thereby reducing the needed amount of CO 2 slightly or, alternatively lower the temperature after expansion giving a larger cooling duty in HX- 102. Alternatively a third expander loop can be implemented in the process.
  • the ship's engines can be used to provide power for the nitrogen compressor. In this way the amount of nitrogen needed can be reduced, however, this will reduce the process efficiency and increase the CO 2 emissions from the ship.
  • the combined carrier will transport LIN and LCO 2 to the offshore installation and return with LNG to the onshore terminal, where the cargo is contained in several semi- pressurized vessels.
  • the selected carrier size in this description is 20 000 m 3 .
  • the carrier size is not particularly limited, however, typical vessel sizes might be between 10000 and 50 000 m 3 .
  • the material of the semi-pressurised vessels must be able to withstand pressures up to 7 bar and temperatures down to -175 0 C, hence SST 304 or 9 % nickel steel or similar should be used in the vessels.
  • the offshore process should preferably take place on the gas carrier to avoid offshore storage and loading of LNG.
  • the combined carrier will be connected to the production facility through a flexible riser and a submerged turret loading (STL) connection.
  • STL submerged turret loading
  • the LNG will replace the LIN and LCO 2 in the storage tanks.
  • the combined carrier will consist of at least 6-20 semi-pressurized tanks.
  • the main challenge is that LNG cannot contain much CO 2 ; hence the CO 2 tanks should be purged with nitrogen prior to loading of LNG.
  • the LNG should be unloaded to an intermediate storage.
  • the change of grade is easier as the CO 2 may contain some natural gas without causing operational problems.
  • the gas carrier should use electric propulsion and natural gas engines to reduce the CO 2 emissions to a minimum.
  • the total chain efficiency and the CO 2 emissions depend on the distance between the field and market site. It is worth noting that due to frictional pressure drop in pipelines, ship transport is more efficient than pipelines over longer distances for both natural gas and CO 2 . As semi-pressurized tanks are used there is no need for a re-liquefaction unit on the gas carriers as a small pressure (and temperature) increase can be allowed for. This will, however, decrease the efficiency slightly. Any possible losses during transport (change of grade, fuel for propulsion and heat leak) are not accounted for in the results.
  • Figure 12 shows one configuration of the market site process.
  • LNG at 1 bar needs to be compressed to 25 bar and vaporized.
  • the CO 2 and nitrogen must be compressed from 1 to 5.5 and 6 bar and liquefied.
  • the nitrogen is provided from an ASU at atmospheric pressure.
  • the CO 2 is provided by either an external industrial source such as steel and cement industry, a coal, bio-mass or natural gas fired power plant with CO 2 capture or an integrated Oxyf ⁇ iel power plant.
  • Figure 11 shows the inlet and outlet streams and utilities to the onshore process. The required LIN and LCO 2 flow rates are given in kg/kg LNG.
  • Figure 11 also shows the exergy content in the streams and the exergy conversion efficiency.
  • the LNG is pumped to 25 bar prior to heat exchange. It is then pumped to a pressure of 75 bar, heated and expanded to 25 bar again to produce extra cooling duty and work in a direct expansion cycle.
  • the nitrogen needs to be compressed to a pressure of 65 bar. It is then cooled, liquefied and subcooled before it is expanded to transport pressure using a valve. Additional cooling is provided by a nitrogen recycle, where some of the nitrogen is expanded from 6 to 3 bar, or alternatively 1 bar, and re-compressed to 65 bar.
  • CO 2 is liquefied in at least three stages, at 7, 24 and 65 bar. Approximately one third of the CO 2 is liquefied at each pressure level.
  • the LNG is pumped to a pressure of 25 bar NG-I before it is heated to -109 0 C NG- 2 by cooling of nitrogen in HX-102.
  • the LNG is then pumped to 74 bar NG-4 and heated to 12°C, before it is expanded to 25 bar NG-5 and re-heated to 12°C.
  • the natural gas process path is shown in a pressure- enthalpy diagram in Figure 13.
  • the nitrogen is compressed to 65 bar in four stages with intermediate cooling N2-8 before it is pre-cooled to -95 0 C MN2-9 in HX-IOl. It is then liquefied and subcooled to - 161°C in HX-102 and expanded to the transport pressure of 6 bar N2-11 through a valve.
  • the flash gas N2-12 is heated to -HO 0 C and expanded in EXP- 102 to 3.2 bar, or alternatively 1 bar, N2-14 to provide additional cooling for the hot nitrogen stream. After reheating to atmospheric conditions the nitrogen is recompressed.
  • the nitrogen process path is shown in a pressure-enthalpy diagram in Figure 14.
  • the CO 2 is compressed in two stages to 7.25 bar and cooled to ambient conditions before it is split into two parts. Approximately half of the CO 2 , CO2-1, is liquefied in HX- 101. The other part CO2-4 is compressed to 24 bar and cooled to ambient conditions. It is then split in two new streams, where one stream CO2-10 is liquefied and subcooled to - 55°C in HX-IOl. The last part CO2-6 is compressed to 65 bar and liquefied by seawater. It is then sub cooled to -55°C in HX-IOl. Due to the sub cooling there should not be any flash gas after expansion, however, a recycle stream is provided for start-up and better flexibility.
  • the CO 2 process path is shown in a pressure-enthalpy diagram in Figure 15. If water and volatiles are present in the feed gas, it will be removed during the compression and liquefaction process. Most of the water will be removed in vapour-liquid separator drums after cooling and prior to expansion. To obtain the current specification of 50 ppm water, adsorption dryers should be included after the third compression stage. If more than 1% of volatiles are present a column with re-boiler and condenser should be placed after liquefaction and before the subcooling. A detailed description of gas conditioning of CO 2 for large-scale transport can be found in Aspelund, A., Jordal, K., 2007, Gas conditioning ;- the interface between CO2 capture and transport, International Journal of Greenhouse Gas Control.
  • the Composite Curves for HX-101 and HX- 102 are shown in Figure 16.
  • the process design starts in the cold end of HX- 102.
  • the LNG is pumped to 20 bar to avoid phase change through HX- 102.
  • the nitrogen is compressed to 65 bar so that the condensing temperature is high enough for it to be liquefied by the heating of LNG.
  • the flash gas from MV- 102 is heated to -1 10 0 C and expanded to 3 bar and -142°C to provide the necessary additional cooling at low temperature.
  • a lower temperature in the sub-cooled nitrogen N2-10 gives less flash gas and thereby a smaller recycle to the nitrogen compressor train. If there are losses in the chain, the temperature in N2-10 will increase and a larger fraction of nitrogen will flash, giving a larger recycle and an increase in the energy requirements.
  • the current design outlet temperature is -161°C. Notice the parallel Composite Curves in HX-102 resulting in small irreversibility losses of only 0.9%. If an additional 10% of LIN is needed to account for the losses in the chain, the energy requirements will increase with 11%, decreasing the exergy efficiency in the entire chain with 5%.
  • Table 4 gives the irreversibility losses for the process equipment as well as the total irreversibilities.
  • the largest irreversibilities can be found in the nitrogen and CO 2 compressor trains with aftercoolers. These compressors are also the main consumers of power. However, about 50% of these irreversibilities (13%) occur in the compression from atmospheric pressure to transport pressure of 6 and 5.5 bar and can not be avoided. Therefore, the current exergy efficiency of 71.1% is relatively high. The total losses are 28.9% in the onshore process, which means that only 1.1% of the chemical potential in the natural gas is lost in the onshore process.
  • EXP-102 The purpose of EXP-102 is to provide additional cooling at low temperature. If the temperature difference between the transported LNG and LIN is low, and the losses throughout the chain are reduced to a minimum, the expander can be replaced with a valve. For the base-case with LNG at 1 bar and LIN at 6 bar, the duty of the expander is marginal due to the low flash rate in V-102. When losses are included or the temperature difference between LNG and LIN is increased, this expander is vital for the efficiency of the onshore process. Therefore the expander is included in all simulations.
  • the nitrogen is provided by an external ASU, it should preferably be provided at intermediate pressure between 5 and 8 bars. This will decrease the total CAPEX and OPEX and increase the overall efficiency as two of the nitrogen compressors can be replaced by a marginal increase in the ASU compressors.
  • the CO 2 can be provided at a higher pressure, the first part of the CO 2 compression can be avoided and hence, the exergy efficiency will be improved.
  • the liquid CO 2 can only contain about 0.25 mole% of volatiles. For small amounts of volatiles ( ⁇ 1%) it can be sufficient to use a flash drum prior to the product tank to remove to volatiles. This will, however, lead to some CO 2 emissions.
  • a column with re-boiler and condenser should be implemented in the process. The columns should be placed after liquefaction, but before subcooling of the CO 2 rich stream. Since the CO 2 is liquefied at three different pressure levels, either three columns must be used, or alternatively the column can be placed at the intermediate pressure (25 bar) or high pressure (65 bar). This will result in increased power requirements as more of the CO 2 must be compressed to a higher pressure.
  • HX-IOl the irreversibilities in HX-IOl will increase as there will be a larger temperature gap between the hot and cold composite curve.
  • the CO 2 should be subcooled in HX-IOl to avoid flashing of gas in VD-IOl.
  • the exact configuration of the volatile removal process can be determined on a case by case basis.
  • the processes are based on state-of-the-art process equipment.
  • Plate-fin heat exchangers are selected for the main heat exchangers as they should be as compact as possible. For simplicity, only two heat exchangers are shown in the process flow diagram, however, it may be favourable to divide the heat exchangers into three or four sections to decrease the complexity. All the process streams entering the heat exchangers are in single phase; hence, mal-distribution due to two-phase flow in the manifold system, which is a well-known problem in plate-fin heat exchangers in the LNG industry, is avoided.
  • the heat transfer coefficients will be lower than for state-of-the-art LNG processes where the cooling duty required to condense the LNG is provided by vaporization of a mixed refrigerant.
  • Plate-fin heat exchangers are well suited for the purpose, and are currently used for pressures up to 95 bar. Heatric exchangers can also be used. Standard centrifugal compressors are selected for the compressors. The cryogenic pumps are similar to the pumps used in LNG receiving terminals.
  • the exergy efficiency for the process is 52 % and the required energy is 319 kWh/tonne LNG.
  • Production of nitrogen in an ASU will require 47 kWh/tonne nitrogen, which corresponds to 45 kWh/tonne LNG and will decrease the efficiency to 48 %.
  • Figure 18 shows the ship utilization (first axis) and the required amount Of LCO 2 and LIN in the offshore process (second axis), as a function of LNG pressure and maximum ship pressure.
  • Figure 19 shows the exergy efficiencies for the offshore, onshore and simple chain, versus LNG and maximum ship pressure.
  • CCS Capture and Storage
  • B a conventional LNG chain with CCS
  • CCS pipeline transport of natural gas with CCS where the CO 2 also is returned in a pipeline
  • the LEC requires the same power as for pipeline transport (chain C) of NG and CO 2 .
  • chain C pipeline transport
  • the LEC will be more effective than pipeline transport as recompression is needed due to the frictional drop in the pipeline.
  • chain B transport chains for stranded natural gas
  • the LEC energy requirement is, in fact, less than ship transport of natural gas without CO 2 capture (chain A).
  • the required power will be generated by conversion of natural gas to power.
  • the efficiency for power generation in an open cycle offshore is 30 %, whereas an onshore power plant with CO 2 recovery has an efficiency of 50 % and a combined cycle power plant without CO 2 capture has an efficiency of 56.7%.
  • the total exergy (thermo-mechanical and chemical) for the natural gas is 14413 kWh/tonne. Assuming the efficiencies given above, the loss of natural gas is 4.8 for the LEC, roughly the same as for pipeline transport, 5.1%.
  • the LNG chains without (A) and with (B) CO 2 capture has two and three times as large NG losses with 9.1% and 12.8% respectively.
  • all the power required in the LEC is taken from a power plant with CO 2 capture, which means that most of the CO 2 will be captured. All other concepts will emit CO 2 to the atmosphere
  • the full LEC includes a power process with CO 2 capture.
  • Oxyfuel concepts are especially suited as they will produce nitrogen as a by-product. Hence, the requirements for ' the production of nitrogen (45 kWh/tonne LNG) is avoided, as the required amount of nitrogen is far less than what corresponds to the amount of oxygen needed in an oxyfuel power plant.
  • natural gas at 70 bar is processed and transported from the field site to the market site where it is used for electricity production in an oxyfuel power plant.
  • An LHV efficiency of 50% (which corresponds to an exergy efficiency of 48%) is used in the calculations.
  • the CO 2 is conditioned and transported to the field site where it is unloaded at 150 bar. The exergy efficiency for the full LEC is found in Figure 21.
  • the LEC chain is compared with a full conventional chain with and without CO 2 capture.
  • the full LEC efficiency is the same as for pipeline transport, 46.6%, where as a similar conventional chain including production transport of LNG and CO 2 and a power plant with CO 2 capture will have an efficiency of 42.9%.
  • the conventional utilization of natural gas with LNG production and transport and a CC power plant without a capture process will have an efficiency of 50.4%.

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Abstract

Pour le transport et le traitement de gaz naturel, on utilise de l'azote liquide et du dioxyde de carbone liquide dans une opération d'échange de chaleur pour liquéfier le gaz naturel fourni à partir d'un champ de gaz. Le gaz naturel liquéfié est transporté vers une installation de regazéification où l'énergie froide d'une partie du gaz naturel liquéfié dans un dispositif de séparation d'air est utilisée pour produire de l'azote liquide et de l'oxygène par regazéification du gaz naturel. L'oxygène subit une combustion dans une installation de production d'énergie, laquelle capture le dioxyde de carbone produit par la combustion. Le dioxyde de carbone est liquéfié par gazéification d'une autre partie du gaz naturel liquéfié. L'azote liquide et le dioxyde de carbone liquide sont alors transportés en vue d'une liquéfaction supplémentaire du gaz naturel fourni à partir du champ de gaz.
PCT/GB2007/002712 2006-07-18 2007-07-18 Appareil et procédés pour le transport et le traitement de gaz naturel WO2008009930A2 (fr)

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US12/373,551 US20100251763A1 (en) 2006-07-18 2007-07-18 Apparatus and Methods for Natural Gas Transportation and Processing
NO20090754A NO20090754L (no) 2006-07-18 2009-02-17 Anordning og fremgangsmater for transport og prosessering av naturgass

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GBGB0614250.9A GB0614250D0 (en) 2006-07-18 2006-07-18 Apparatus and Methods for Natural Gas Transportation and Processing
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CN105783419A (zh) * 2016-03-30 2016-07-20 重庆耐德能源装备集成有限公司 一种天然气预冷装置及预冷控制方法
JP2021095066A (ja) * 2019-12-19 2021-06-24 三菱造船株式会社 船舶
JP2021095051A (ja) * 2019-12-19 2021-06-24 三菱造船株式会社 船舶、船舶における液化二酸化炭素の積込方法
WO2021124622A1 (fr) * 2019-12-19 2021-06-24 三菱造船株式会社 Navire
JP7350647B2 (ja) 2019-12-19 2023-09-26 三菱造船株式会社 船舶、船舶における液化二酸化炭素の積込方法
JP7377094B2 (ja) 2019-12-19 2023-11-09 三菱造船株式会社 船舶

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NO20090754L (no) 2009-04-08

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