Classifications

• • 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
  • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
  • F01D—NON-POSITIVE DISPLACEMENT MACHINES OR ENGINES, e.g. STEAM TURBINES
  • F01D15/00—Adaptations of machines or engines for special use; Combinations of engines with devices driven thereby
  • F01D15/005—Adaptations for refrigeration plants
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
  • F01D—NON-POSITIVE DISPLACEMENT MACHINES OR ENGINES, e.g. STEAM TURBINES
  • F01D15/00—Adaptations of machines or engines for special use; Combinations of engines with devices driven thereby
  • F01D15/08—Adaptations for driving, or combinations with, pumps
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
  • F04D—NON-POSITIVE-DISPLACEMENT PUMPS
  • F04D17/00—Radial-flow pumps, e.g. centrifugal pumps; Helico-centrifugal pumps
  • F04D17/08—Centrifugal pumps
  • F04D17/10—Centrifugal pumps for compressing or evacuating
  • F04D17/12—Multi-stage pumps
  • F04D17/122—Multi-stage pumps the individual rotor discs being, one for each stage, on a common shaft and axially spaced, e.g. conventional centrifugal multi- stage compressors
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
  • F04D—NON-POSITIVE-DISPLACEMENT PUMPS
  • F04D25/00—Pumping installations or systems
  • F04D25/02—Units comprising pumps and their driving means
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
  • F04D—NON-POSITIVE-DISPLACEMENT PUMPS
  • F04D29/00—Details, component parts, or accessories
  • F04D29/58—Cooling; Heating; Diminishing heat transfer
  • F04D29/582—Cooling; Heating; Diminishing heat transfer specially adapted for elastic fluid pumps
  • F04D29/5826—Cooling at least part of the working fluid in a heat exchanger
• • 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"
• • 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
  • F25J1/0047—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 an "external" refrigerant stream in a closed vapor compression cycle
  • F25J1/005—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 an "external" refrigerant stream in a closed vapor compression cycle by expansion of a gaseous refrigerant stream 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
  • F25J1/0047—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 an "external" refrigerant stream in a closed vapor compression cycle
  • F25J1/0052—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 an "external" refrigerant stream in a closed vapor compression cycle by vaporising a liquid refrigerant 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
  • F25J1/0047—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 an "external" refrigerant stream in a closed vapor compression cycle
  • F25J1/0052—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 an "external" refrigerant stream in a closed vapor compression cycle by vaporising a liquid refrigerant stream
  • F25J1/0055—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 an "external" refrigerant stream in a closed vapor compression cycle by vaporising a liquid refrigerant stream originating from an incorporated cascade
• • 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
  • F25J1/006—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures characterised by the refrigerant fluid used
  • F25J1/007—Primary atmospheric gases, mixtures thereof
  • F25J1/0072—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
  • F25J1/02—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
• • 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
  • F25J1/0211—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 a multi-component refrigerant [MCR] fluid in a closed vapor compression cycle
  • F25J1/0212—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 a multi-component refrigerant [MCR] fluid in a closed vapor compression cycle as a single flow MCR cycle
• • 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
  • F25J1/0211—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 a multi-component refrigerant [MCR] fluid in a closed vapor compression cycle
  • F25J1/0214—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 a multi-component refrigerant [MCR] fluid in a closed vapor compression cycle as a dual level refrigeration cascade with at least one MCR cycle
• • 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
  • F25J1/0211—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 a multi-component refrigerant [MCR] fluid in a closed vapor compression cycle
  • F25J1/0214—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 a multi-component refrigerant [MCR] fluid in a closed vapor compression cycle as a dual level refrigeration cascade with at least one MCR cycle
  • F25J1/0215—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 a multi-component refrigerant [MCR] fluid in a closed vapor compression cycle as a dual level refrigeration cascade with at least one MCR cycle with one SCR cycle
  • F25J1/0216—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 a multi-component refrigerant [MCR] fluid in a closed vapor compression cycle as a dual level refrigeration cascade with at least one MCR cycle with one SCR cycle using a C3 pre-cooling cycle
• • 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
  • F25J1/0211—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 a multi-component refrigerant [MCR] fluid in a closed vapor compression cycle
  • F25J1/0217—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 a multi-component refrigerant [MCR] fluid in a closed vapor compression cycle as at least a three level refrigeration cascade with at least one MCR cycle
• • 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
  • F25J1/0211—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 a multi-component refrigerant [MCR] fluid in a closed vapor compression cycle
  • F25J1/0217—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 a multi-component refrigerant [MCR] fluid in a closed vapor compression cycle as at least a three level refrigeration cascade with at least one MCR cycle
  • F25J1/0218—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 a multi-component refrigerant [MCR] fluid in a closed vapor compression cycle as at least a three level refrigeration cascade with at least one MCR cycle with one or more SCR cycles, e.g. with a C3 pre-cooling cycle
• • 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
  • F25J1/0228—Coupling of the liquefaction unit to other units or processes, so-called integrated processes
  • F25J1/0235—Heat exchange integration
  • F25J1/0242—Waste heat recovery, e.g. from heat of compression
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
  • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
  • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
  • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
  • F25J1/0243—Start-up or control of the process; Details of the apparatus used; Details of the refrigerant compression system used
  • F25J1/0257—Construction and layout of liquefaction equipments, e.g. valves, machines
  • F25J1/0262—Details of the cold heat exchange system
  • F25J1/0264—Arrangement of heat exchanger cores in parallel with different functions, e.g. different cooling streams
  • F25J1/0265—Arrangement of heat exchanger cores in parallel with different functions, e.g. different cooling streams comprising cores associated exclusively with the cooling of a refrigerant stream, e.g. for auto-refrigeration or economizer
• • 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
  • F25J1/0279—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum 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
  • 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
  • F25J1/0279—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc.
  • F25J1/0281—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc. characterised by the type of prime driver, e.g. hot gas expander
• • 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
  • F25J1/0279—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc.
  • F25J1/0281—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc. characterised by the type of prime driver, e.g. hot gas expander
  • F25J1/0282—Steam turbine as the prime mechanical driver
• • 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
  • F25J1/0279—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc.
  • F25J1/0281—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc. characterised by the type of prime driver, e.g. hot gas expander
  • F25J1/0283—Gas turbine as the prime mechanical driver
• • 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
  • F25J1/0279—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc.
  • F25J1/0281—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc. characterised by the type of prime driver, e.g. hot gas expander
  • F25J1/0284—Electrical motor as the prime mechanical driver
• • 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
  • F25J1/0279—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc.
  • F25J1/0285—Combination of different types of drivers mechanically coupled to the same refrigerant compressor, possibly split on multiple compressor casings
• • 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
  • F25J1/0279—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc.
  • F25J1/0285—Combination of different types of drivers mechanically coupled to the same refrigerant compressor, possibly split on multiple compressor casings
  • F25J1/0287—Combination of different types of drivers mechanically coupled to the same refrigerant compressor, possibly split on multiple compressor casings including an electrical motor
• • 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
  • F25J1/0279—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc.
  • F25J1/0289—Use of different types of prime drivers of at least two refrigerant compressors in a cascade refrigeration system
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
  • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
  • F25J1/00—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures
  • F25J1/02—Processes or apparatus for liquefying or solidifying gases or gaseous mixtures requiring the use of refrigeration, e.g. of helium or hydrogen ; Details and kind of the refrigeration system used; Integration with other units or processes; Controlling aspects of the process
  • F25J1/0243—Start-up or control of the process; Details of the apparatus used; Details of the refrigerant compression system used
  • F25J1/0279—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc.
  • F25J1/029—Mechanically coupling of different refrigerant compressors in a cascade refrigeration system to a common driver
• • 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
  • F25J1/0279—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc.
  • F25J1/0291—Refrigerant compression by combined gas compression and liquid pumping
• • 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
  • F25J1/0279—Compression of refrigerant or internal recycle fluid, e.g. kind of compressor, accumulator, suction drum etc.
  • F25J1/0292—Refrigerant compression by cold or cryogenic suction of the refrigerant 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
  • F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
  • F25J2230/02—Compressor intake arrangement, e.g. filtering or cooling
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
  • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
  • F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
  • F25J2230/20—Integrated compressor and process expander; Gear box arrangement; Multiple compressors on a common shaft
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
  • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
  • F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
  • F25J2230/22—Compressor driver arrangement, e.g. power supply by motor, gas or steam turbine
• • 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
  • F25J2240/80—Hot exhaust gas turbine combustion engine
  • F25J2240/82—Hot exhaust gas turbine combustion engine with waste heat recovery, e.g. in a combined cycle, i.e. for generating steam used in a Rankine cycle
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
  • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
  • F25J2290/00—Other details not covered by groups F25J2200/00 - F25J2280/00
  • F25J2290/34—Details about subcooling of liquids

Definitions

• the present disclosure concerns systems and methods for producing liquefied natural gas, here below shortly named also LNG.
• thermodynamic cycles For transport purposes, where no gas pipelines are available, natural gas is conventionally chilled and converted into liquefied natural gas and transported via a carrier, for instance a liquefied gas tanker.
• a carrier for instance a liquefied gas tanker.
• thermodynamic cycles usually include one or more compressors which process one or more refrigerant fluids. The refrigerant fluids undergo cyclic thermodynamic transformations to remove heat from the natural gas until this latter is finally converted in liquid phase.
• the LNG compressor train and relevant driver is a cumbersome machinery.
• Improvements in the arrangement and configuration of the compressor train are needed, to enhance the operability and availability of the compressor train, as well as the overall efficiency thereof.
• LNG refrigerant compressor trains comprising: a driver section, drivingly coupled to a compressor section through a shaft line, wherein the compressor section is comprised of at least one refrigerant fluid compressor, driven into rotation by said driver section.
• the refrigerant compressor(s) will be referred to here on also as gas compressors.
• the driver section can comprise at least one of the following: an internal combustion engine; a gas turbine engine; an electric motor, a steam turbine; a reciprocating gas engine. If a gas turbine engine is provided, said gas turbine engine can be selected from the group consisting of: a 1 -spool gas turbine; a 1.5-spool gas turbine; a 2-spool gas turbine; a 3 -spool gas turbine.
• the compressor section can comprise more than one refrigerant compressor and preferably less than five refrigerant compressors, drivingly coupled to the driver section.
• the compressor(s) can include dynamic compressors, such as axial, radial or mixed axial-radial compressors, or positive-displacement compressors, such as reciprocating compressors .
• the compressor train can include additional rotating machinery.
• the compressor train can include one or more auxiliary machines driven by the driver section and mechanically coupled to at least one compressor of the compressor section.
• the auxiliary machine(s) may comprise one or more of the following: electric generators; electric or steam helpers; electric or steam starters; electric or steam starter- helpers; electric or steam starter-helper-generators.
• an auxiliary machine may also include a further compressor.
• Figs.l, 2, 3 and 4 illustrate schematics of compressor trains for natural gas liquefaction systems, according to the present disclosure
• Figs. 5, 6, 7, 8 and 9 illustrate schematics of gas turbine engines used as drivers in a gas compressor train according to the present disclosure
• Figs. 10, 11, 12, 13, 14, 15, 16 and 17 illustrate schematics of electric motors used as drivers in a gas compressor train according to the present disclosure
• Figs. 18, 19, 20 and 21 illustrate configurations of mechanical couplings between compressors of a compressor train according to the present disclosure
• Figs. 22, 23, 24, 25, 26, 27, 28, 29 and 30 illustrate alternative compressor layouts for gas compressor trains of the present disclosure
• Figs. 31, 32, 33 and 34 illustrate possible combinations of a plurality of compressor trains for a gas liquefaction system
• Figs. 35, 36, 37, 38, 39, 40 and 41 illustrate various LNG systems which can use one or more compressor trains according to the present disclosure
• Figs.42A, 42B, 42C, 42D, 42E illustrate a flow chart of a method for generating compressor train configurations according to the present disclosure
• Figs 43, 44 and 45 illustrate compressor trains with combined top and bottom thermodynamic cycles. - -
• FIG. 1 schematical ly illustrates a compressor train for processing one or more refrigerant fluids of a natural gas liquefaction plant .
• the compressor train is labeled 1 .
• One or more refrigerant ducts schematically shown at 3 are provided for flu idly coupling the compressor train to a cooling and liquefaction system 5, wherein one or more flows of compressed refrigerant fluids are cooled by exchanging heat with a heat sink and expanded, to produce chilled refrigerant. This latter is used to directly or indirectly remove heat from a natural gas flow 7 entering the cooling and liquefaction system 5. Through one or more cooling steps the natural gas is finally l iquefied and exits the cool ing and liquefaction system at 9.
• the LNG plant can include one or more compressor trains 1 .
• one compressor train 1 is illustrated by way of example.
• they can be identical to one another or different from one another, depending e.g. upon the liquefaction process used in the cooling and liquefaction system 5.
• the compressor train 1 is general ly comprised of a driver section 1 1 and a driven section.
• the driven section can comprise a gas compressor section 13, which is in turn comprised of at least one refrigerant fluid compressor, as will be described in greater detail here below.
• a transmission 15 provides a mechanical coupling between the driver section 1 1 and the gas compressor section 13.
• the transmission 15 can include a simple mechanical shaft or a more complex machinery arrangement, as will be described later on.
• the compressor train 1 can further include one or more auxiliary machine aggregates.
• a first auxilia y machine aggregate is labeled 1 7 and a second auxiliary machine aggregate is labeled 19.
• the first auxiliary machine aggregate 17 and the second auxiliary machine aggregate 19 are arranged at opposite ends of the compressor train. More specifically: the first auxiliary machine aggregate 1 7 is arranged at a first end of a shaft line 2, and the second auxiliary machine aggregate 19 is arranged at a second end of shaft line 2.
• one or more auxiliary machine aggregates 1 7, 1 9 can be arranged along shaft line 2 between the driver section 1 1 and the gas compressor section 13, as schematically shown in Fig. 2.
• a transmission 1 5. 1 can be arranged between the driver section 1 1 and the auxiliary machine aggregate 1 7, 19 and a transmission 15.2 can be arranged between the auxiliary machine aggregate 1 7, 1 9 and the compressor section.
• n in Figs. 3 and 4 can be comprised of two auxiliary machine aggregates 1 7 and 19 arranged as follows: in Fig. 3 the first auxiliary machine aggregate 1 7 is located at a first end of shaft line 2, and the second auxiliary machine aggregate 19 is located between the driver section 1 1 and the gas compressor section 13. Transmissions 15.3, 15.4, 1 5.5 are arranged between each pair of sequentially arranged machine sections and aggregates; in Fig. 4 the first auxiliary machine aggregate 1 7 is located along the shaft line 2 between the driver section 1 1 and the gas compressor section 13; the second - D - auxiliary machine aggregate 19 is located at the second end of the shaft l ine 2, on the opposite side of the first auxiliary machine aggregate with respect to the gas compressor section 13.
• Transmissions 15.6, 15.7, 15.8 are arranged between each pair of sequentially arranged machine sections and aggregates.
• the compressor train 1 can contain no auxiliary machine or auxiliary machine aggregate.
• the auxiliary machines may include further compressors, e.g. refrigerant compressors.
• Each auxiliary machine aggregate can in turn comprise one or more machines.
• the auxiliary machine can be a driven auxil iary machine, for example an electric generator, i.e. in general a machine w hich is driven by mechanical power prov ided by the driver section.
• the auxilia y machine can be a driver auxiliary machine, for example an electric motor, i .e. in general a machine which generates mechanical power. Exemplary embodiments of auxil iary machine arrangements will be discussed later on in this description.
• a combination of driven auxil iary machines and driv ing au il iary machines can also be env isaged.
• the auxil iary machine aggregate can include a reversible electric machine, capable of operating in an electric generator mode or in an electric motor mode.
• the electric generator mode excess power produced by the driver section 1 1 can be converted into useful electric power and exploited to drive another load or delivered to an electric power distribution grid.
• the auxiliary machine can operate as a helper, providing additional power to drive the load, w hen the power generated by the driver section 1 1 is insufficient, for instance if the efficiency of a gas turbine engine used as a driver drops as a consequence of variable env ironmental conditions.
• Combining one or more auxiliary machines or machine aggregates on the same shaft l ine 2 improves the operational flexibility and optional operating conditions of the compressor train.
• the driver section 1 1 can include one or more drivers.
• a driver converts power, other than mechanical power, avai lable from a power source, into mechanical power for driv ing the rotating load(s) mechanical ly coupled to the driver section 1 1 via shaft line 2, i.e. one or more compressors, and one or more auxiliary machines or auxiliary machine aggregates, if present.
• Fig. 1 several different drivers are schematically represented in the left-hand cloud.
• Each driver can be selected from the group consisting of: gas turbine engines (GT), steam or vapor turbines (ST), such as Rankine turbines, using either organic or non-organic (e.g. water) working fluid, expanders ( EX), electric motors (EM), reciprocating internal combustion engines such as gas engines (GE), or combinations thereof.
• Vapor turbines and expanders can be designed to process any fluid in vapor or gaseous state, for instance: carbon dioxide, organic fluids such as pentane, cyclo- pentane, or other fluids suitable for use in an organic thermodynamic cycle, such as an ORG (Organic Rankine Cycle) .
• ORG Organic Rankine Cycle
• the gas turbine engine can be a heavy duty gas turbine engine or an aeroderivative gas turbine engine.
• Exemplary embodiments of as turbine engines suitable to drive a compressor train are described here below, reference being made to Figs 5, 6, 7, 8 and 9.
• Each gas turbine engine is comprised of a compressor section.
• Each compressor section can comprise one or more air compressors.
• the air compressors of gas turbine engines disclosed herein will be referred to sim ly as "compressors".
• a gas turbine engine can del iv er up to about 130 MW mechanical power, which is made av ailable on the shaft line 2 to drive one or more rotary driven machines.
• FIG. 5 An exemplary heavy duty gas turbine engine 2 1 is schematically illustrated in Fig. 5 and in the left cloud of Fig. 1 .
• the gas turbine engine 2 1 is a one-shaft gas turbine engine comprised of a compressor portion 23, a com bus tor portion 25 and a power turbine portion 27.
• the power turbine portion is mechanically cou led to the compressor portion through a shaft 29. Air is compressed by compressor portion 23, fuel is mixed with the compressed air and the air-fuel mixture is ignited in combustor portion 25 to generate hot, compressed combustion gas. This latter is then expanded in turbine portion 21 , where mechanical power is generated.
• Part of the mechanical power produced by expanding combustion gas in the power turbine portion 27 is partly used to power the compressor portion 23 and maintain continuous del ivery of compressed ai , and partly made available on shaft line 2 through shaft 29 to drive into rotation one or more loads connected to the shaft line 2.
• the power turbine portion 27 and the compressor portion 23 are flu idly and mechanically coupled, through the combustor portion 25 and the shaft 29, respectively.
• the term " one-shaft gas turbine engine " as used herein can be understood as a machine wherein the rotat ing part of the compressor port ion 23 and the rotat ing part of the power turbine portion 27 are mounted on the same shaft 29 and thus rotate at the same rotational speed.
• a one-shaft gas turbine engine is also called “ one-spool gas turbi ne engine " , labeled in Fig. 1 with "G i l " .
• one-shaft or single-shaft gas turbine engines as shown in
• Fig.5 can provide particularly high efficiencies, if compared with multi-shaft gas turbine engines. Moreover, this type of gas turbine can be more compact and less expensive with respect to the other ones.
• the one-shaft gas turbine engine can be one of the gas turbines hcre-below listed:
• the driver section 1 1 can comprise a multi-shaft gas turbine engine, i.e. a gas turbine engine comprised of two or more shafts.
• Multi-shaft gas turbine engines can be either heavy duty gas turbine engines or aeroderivativ e gas - - turbine engines.
• the gas turbine engine is labeled 31 and can be either a heavy duty gas turbine engine or an aeroderivativc gas turbine engine.
• the gas turbine engine 3 1 comprises a compressor portion 33, a com bust or portion 35, a turbine portion 36. This latter can in turn be comprised of a high pressure turbine 37 and a low pressure turbine 39.
• the low pressure turbine 39 is also referred to as power turbine.
• the aggregate comprised of the compressor portion 33, the combustor portion 35 and the high pressure turbine 37 are sometimes cumulatively referred to as gas generator, since they provide compressed, high-temperature combustion gas, which is expanded in the low pressure turbine 39 to generate mechanical power.
• Air is ingested and compressed by compressor portion 33, fuel is mixed with the compressed air and the air- fuel mixture is ignited in combustor portion 35 to generate hot, compressed combustion gas. This latter is then sequentially expanded in the high pressure turbine 37 and in the low pressure turbine 39 of turbine portion 36.
• Mechanical power generated by the high pressure turbine 37 is used to drive the compressor portion 33 into rotation through first shaft 38.
• Mechanical power generated by the low pressure tu bine 39 is used to drive the loads coupled to shaft line 2, which is mechanically coupled to a second shaft 40 of the gas turbine engine 31.
• the high pressure turbine 39 and the compressor portion 33 are flu idly and mechanical ly coupled, through the combustor portion 35 and the shaft 38, respectively.
• the low pressure turbine 39 is fluidly coupled but not mechanically coupled to the high pressure turbine 37, i.e. the low pressure turbine 39 and the high pressure turbine 37 comprise respective rotors which are supported by separate shafts, namely shaft 38 and shaft 40, respectively.
• the high pressure turbine 37 and the low pressure turbine 39 can thus rotate at different rotational speeds.
• the gas turbine engine 31 of Fig. 6 is also referred to as a 1.5-spool gas turbine engine and it is indicated with "GT1.5" in Fig. 1 .
• a 1 .5 -spool gas turbine engine is a machine comprised of a first spool, formed by a first shaft, a turbine and a compressor, and a half spool, formed by a shaft and a turbine, but not having a compressor counterpart.
• the 1 .5 -spool gas turbine engine 31 is a compact driver, which al lows the low- pressure turbine 39 to rotate at a rotational speed different from the rotational speed of the high pressure turbine 37 and of the compressor 33, forming part of the gas generator. Flexibility of operation of the compressor train can thus be obtained, for increased efficiency of the compressor train .
• the 1 .5-spool gas turbine engine can be one of the gas turbines here-below listed:
• FIG. 7 illustrates a further embodiment of a gas turbine engine, labeled 41 as a whole.
• Gas turbine engine 41 can be a heavy duty gas turbine engine or an aerodcHvative gas turbine engine.
• gas turbine engine 41 is a two-shaft gas turbine engine, comprised of a compressor portion 43, a combustor portion 45 and a turbine portion 47.
• the compressor portion 43 comprises a first compressor 49 and a second compressor 51 arranged in sequence.
• the turbine portion 47 comprises a high pressure turbine 53 and a low pressure turbine 55.
• the high pressure turbine 53 and the low pressure turbine 55 are 11 u idly coupled to one another, such that combustion gas expands sequential ly in the high pressure turbine and in the low pressure turbine.
• the high pressure turbine 53 and the low pressure turbine 55 are mechanically separate from one another, i.e. the rotors thereof are supported on shafts which rotate independently from one another and which are arranged coaxial ly. The two rotors can thus rotate at different rotational speeds.
• Air is ingested by the first compressor 49 and is sequentially compressed by first compressor 49 and second compressor 51.
• the compressed air is delivered to the combustor portion 45, wherein fuel is mixed with the compressed air.
• the air- fuel mixture is ignited in combustor portion 45 to generate hot. compressed combustion gas. This latter is then sequential ly expanded in the high pressure turbine 53 and in the low pressure turbine 55 of turbine portion 47.
• Mechanical pow er generated by the high pressure turbine 53 is used to drive the second compressor 5 1 into rotation through a first shaft 57. which mechanically connects the high pressure turbine 53 to the second compressor 5 1 .
• Mechanical power generated by the low pressure turbine 55 is used to drive the first compressor 49 into rotation through a second shaft 59, which mechanically connects the low pressure turbine 55 to the first compressor 49 and to the shaft line 2.
• the first and second shafts 57, 59 are co-axial. Mechanical power generated by low pressure turbine 55 exceeding the power needed to drive the first compressor 49 into rotation is applied to shaft line 2, which can be mechanically coupled to the second shaft 59, and can be used to drive the load.
• the high pressure turbine 53 and the second compressor 5 1 are flu idly coupled through the combustor portion 45 and mechanically coupled through the first shaft 57.
• the low pressure turbine 55 and the first compressor 49 are mechanically coupled through second shaft 59.
• the low pressure turbine 55 is flu idly coupled, but not mechanically coupled, to the high pressure turbine 53.
• the rotational speed of the shaft line 2 and of the lo pressure turbine 55 can be adjusted independently from the rotational speed of the high-pressure turbine 53, for improved efficiency of the compressor train, taking into account variable operating conditions of the compressor(s) and/or variable environmental conditions.
• Gas turbine engines configured as shown in Fig. 7 are termed also "two-spool gas turbine engines”. This kind of gas turbine is indicated i Fig. 1 with "GT2".
• a two-spool gas turbine engine is comprised of two concentrically arranged shafts, wherein the inner shaft supports the rotor of a first compressor and the rotor of a first turbine, forming a first spool, and wherein the outer shaft supports the rotor of the second compressor and the rotor of a second turbine, forming a second spool.
• a two-spool gas turbine engine as shown in Fig. 7 may provide some advantage over a 1 .5 -spool gas turbine engine as shown in Fig. 6.
• Advantages can be provided in particular by splitting the air compression process in more than just one air compressor. For instance, splitting the air compression process in two air compressors 49,
• the two-spool gas turbine engine can be - the gas tu bine model LM6000, available from General Electric, USA.
• Further embodiments of the driver section 1 1 can include a three-shaft gas turbine engine, as exemplarily illustrated in Fig. 8 and labeled 61.
• the gas turbine engine 61 comprises a compressor portion 63, a combustor portion 65 and a turbine portion 67.
• the compressor portion 63 comprises sequentially arranged first compressor, or booster compressor 69 and second compressor 71.
• the turbine portion 67 comprises a high pressure turbine 73, an intermediate pressure turbine 75 and a low pressure turbine 77, which are arranged in series, such that combustion gas expands through said three turbines sequentially.
• the high pressure turbine 73 can be mechanically coupled, through a first shaft 79, to the second compressor 71.
• the intermediate pressure turbine 75 can be mechanically coupled to the first compressor 69, through a second shaft 81, which is arranged coaxial to and inside the first shaft 79.
• the low pressure turbine 77 is mechanically coupled through a third shaft 83 to the shaft line 2, but is mechanically separate from the compressor portion 63 and from the high pressure turbine 73 and intermediate pressure turbine 75.
• the high pressure turbine 73 and the second compressor 71 are flu idly coupled through the combustor portion 65, and are further mechanically coupled through the first shaft 79.
• the intermediate pressure turbine 75 and the first compressor 69 are mechanically coupled through second shaft 81.
• the first compressor 69 and the second compressor 71 are flu idly coupled but mechanically independent from one another, such that they can rotate at different rotational speeds.
• the low pressure turbine 77 is flu idly coupled but not mechanically coupled to the intermediate pressure turbine 75 , i.e. the rotor of the intermediate pressure turbine 75 and the rotor of the low pressure turbine 77 rotate independently from one another.
• the three turbines 73, 75, 77 can thus rotate at respective different rotational speeds.
• Air is ingested by the first compressor 69 and sequentially compressed by first compressor 69 and second compressor 71 .
• Compressed air is mixed with fuel and the air/fuel mixture is ignited in combustor portion 65 to generate hot. compressed combustio gas.
• This latter is sequential ly expanded in turbines 73, 75, 77.
• Mechanical power generated by the high pressure turbine 73 and intermediate pressure turbine 75 is used to drive the second compressor 71 and the first compressor 68, respectively.
• Mechanical power generated by the low pressure turbine 77 is used to drive the load - - coupled to shaft line 2.
• the three-shaft gas turbine engine of Fig.8 is referred to as a "2.5 spool gas turbine engine " and is labeled in Fig. 1 with "GT2.5".
• a 2.5 spool gas turbine engine is a three-shaft gas turbine engine wherein a first shaft supports the rotor of a first turbine and the rotor of a first compressor, forming a first spool, and a second shaft supports the rotor of a second turbine and the rotor of a second compressor, forming a second spool.
• a third shaft supports the rotor of a third turbine, forming a half spool.
• a 2.5 -spool gas turbine engine may have some advantages over a two-spool gas turbine engine as shown in Fig. 6.
• the 2.5 -spool gas turbine engine provides for independent control of the rotational speed of the free power turbine or low pressure turbine 77, w hich can rotate at a rotational speed and which can be adjusted independently of the rotational speed of the first and second shafts 79, 81.
• the 2.5 -spool gas turbine engine can thus combine the advantages of the free power turbine of a 1 .5 -spool gas turbine engine ( Fig.6) to the advantages of a two-spool gas turbine engine ( Fig.7), i.e. shaft line rotational speed independent from the rotational speed of the air compressors and air compressor process split in two separate air compressors.
• the 2.5-spool gas turbine engine can be one of the gas turbines here-below listed: -Model RB2 1 1 . available from Rol ls-Royce (Siemens );
• a further embodiment of a gas turbine engine for driver section 1 1 is shown in
• the three-shaft gas turbine is also shown in Fig. 1 and it is labeled as "G IT " .
• the gas turbine engine 85 is a three-shaft gas turbine engine, comprised of a compressor portion 87, a combustor portion 89 and a turbine portion 91 .
• the compressor portion 87 is comprised of a first compressor or booster compressor 93, a second compressor 95 and a third compressor 97.
• the three compressors 93, 95, 97 are arranged in sequence, in order to sequentially compress air at progressively increasing pressure values. Compressed air from the last compressor 97 is delivered to the combustor portion 89.
• the turbine portion 91 comprises a high pressure turbine 99, an intermediate pressure turbine 101 and a low pressure turbine, also referred to as power turbine 103.
• the three turbines 99, 101 and 103 are arranged in series to sequentially expand combustion gas from combustor portion 89 and produce mechanical power through said expansion.
• the high pressure turbine 99 is mechanically coupled to the third compressor 97 through a first shaft 105, such that mechanical power generated by the high pressure turbine 99 is used to mechanically drive the third compressor 97.
• a second shaft 107 is arranged coaxial to the first shaft 105 and mechanically connects the intermediate pressure turbine 101 to the second compressor 95, such that mechanical power generated by the expansion of combust ion gas in the intermediate pressure turbine 1 01 is used to drive the second compressor 95 into rotation.
• a third shaft 1 09 is arranged coaxial to the first shaft 105 and the second shaft 107 and mechanically connects the low pressure turbine 103 to the first compressor 93 and to the shaft line. Power produced by combustion gas expansion in the low pressure turbine 103 thus rotates the first compressor 93 and drives into rotation the load applied to shaft l ine 2.
• the high pressure turbine 99 and the third compressor 97 are fin idly coupled through the combustor portion 89 and mechanical ly connected through the first shaft 105.
• the intermediate pressure turbine 101 and the second compressor 95 are mechanically coupled through second shaft 1 07.
• the low pressure turbine 1 03 and the first compressor 93 are mechanically coupled through third shaft 109.
• the low pressure turbine 1 03 is flu idly cou led but not mechanically coupled to the intermediate pressure turbine 1 01 .
• the three shafts 105, 107, 109 and relevant machinery connected thereto can thus rotate at different rotational speeds.
• the rotational speed of the shaft line 2 can be adjusted independently from the rotations speed of the high pressure turbine 99 and of the intermediate pressure turbine 101.
• the rotational speed of the intermediate pressure turbine 1 0 1 can be adjusted independently from the rotation speed of the high pressure tu bine 99. thus providing enhanced adjustment options for increased efficiency of the driver, e.g. under v ariable operating conditions of the load and/or to take variable env ironmental conditions into - - account.
• the turbine configuration of Fig. 9 is referred to as a three-spool gas turbine engine, wherein each spool is comprised of a shaft, a compressor rotor and a turbine rotor coupled by said shaft.
• a three-spool gas turbine engine may have particular advantages over a 2.5- spool or 2 -spool gas turbine engine, as shown in Figs. 8 and 7, respectively.
• a three-spool gas turbine engine allows air bleeding at lower pressures, which reduces the negative impact of air bleeding on the overall turbine efficiency.
• the three-spool gas turbine engine can be the gas turbine named TRENT 60, available from Rolls-Royce (Siemens).
• the shaft line 2 can be mechanically coupled to the hot side or else to the cold side of the gas turbine engine.
• the term "hot side” as used herein can be understood as the side of the gas turbine engine where the turbine portion is arranged, while the term “cold side " as used herein can be understood as the opposite side of the gas turbine engine, where the compressor portion is arranged.
• hot side as used herein can be understood as the side of the gas turbine engine where the turbine portion is arranged
• cold side as used herein can be understood as the opposite side of the gas turbine engine, where the compressor portion is arranged.
• the shaft l ine 2 can extend on both sides of the gas turbine engine, in which case part of the machinery can be arranged on a shaft line section 2 extending from the hot side of the gas turbine engine, and part of the machinery is arranged on a shaft l ine section 2 extending from the cold side of the gas turbine engine.
• the compressor section 13 is arranged on the hot side of the gas tu bine engine. Possible refrigerant gas leakages from the compressor section will in this case not contaminate the combustion air ingested by the air compressor's) of the gas turbine engine, preventing possible explosion or fire hazards.
• the gas turbine engine can comprise two or more ai compressors, as shown by way of example in Figs. 7, 8 and 9.
• an intercooler can be arranged between sequentially arranged upstream compressor and downstream compressor of the compressor portion.
• the intercooler can be arranged between any pai of upstrcam-downstream sequential ly arranged compressors. More than just one intercooler can be provided, if needed, between serially arranged compressors of two or ore compressors pairs.
• An intercooler 1 i 0 is illustrated by way of example in the embodiment of Fig. 8, between the first compressor 69 and the second compressor 71. It shall however be understood that intercooler arrangements can be provided also in other gas turbine engine arrangements.
• Intercooler(s) can be used to remove heat from air compressed by an upstream compressor prior to undergoing a second compression step in a downstream compressor. Using intercooler(s) a lower final air temperature can be obtained, which increases the overal l efficiency of the gas turbine engine cycle. Moreover, by l imiting the final temperature of the compressed air, less performing materials can be employed, in particular for manufacturing the last compressor stages, which reduces the overall cost of the compressor section.
• the intercooler can include an air/air heat exchanger, an air/water heat exchanger or any other heat exchanger wherein hot, partially compressed air is cooled by heat exchange against a heat sink.
• the partly compressed air can be cooled by heat exchange against a refrigerant of the LNG circuit. This can allow lower temperatures to be achieved and/or smaller heat exchange surfaces to be used, thus resulting in more compact heat exchangers.
• Each heat exchanger may include a single section or more sections. Different cooling media can be used in each section. For instance, air can be cooled in the heat exchanger by exchanging heat with air. water or other cooling media in combination.
• the multiple-shaft gas turbine engines can be heavy duty gas turbine engines, aeroderivative gas turbine engines or hybrid gas turbine engines, e.g. including an aeroderivative core section and an additional power turbine, or low pressure turbine which is designed according to heav y duty design criteria.
• the gas turbine engine can include control means to adjust the operating conditions of the gas turbine engine.
• a fuel metering device 1 1 2 can be prov ided to adjust the amount of fuel delivered to the combustor portion, as schematically shown e.g. in Figs. 5 and 9. It shall be understood that a similar fuel metering dev ice can be prov ided also in other gas tu bine engine arrangements disclosed herein.
• Fuel can be a gaseous fuel, such as methane or methane-based gas mixtures.
• the gas fuel can be taken from the natural gas flowing in 7.
• the fuel can be a liquid fuel, such as kerosene or Distillate n.2.
• combustor portions designed to operate with gaseous fuel and liquid fuel alternatively, can be envisaged.
• variable inlet guide vanes can be provided in the compressor portion to adjust the air inlet section as a function of the required operating conditions of the gas turbine engine.
• Variable IGVs are schematically shown at 1 14 in Figs. 5 and 6 by way of example, it being understood that variable IGVs can be provided also in the other gas turbine engine arrangements described herein.
• variable nozzle guide vanes can be provided at the inlet of one or more turbines in the turbine portion of the gas turbine engine.
• variable NGVs 1 16 are shown in Figs. 6 and 8. Similar NGVs can be used also in combination with other embodiments disclosed herein.
• NGVs can be arranged at the inlet of one, some or al l said turbines, for improved control flexibility.
• Variable IGVs and variable NGVs can be used indiv idually or in combination in the same gas turbine engine.
• Variable IGVs and variable NGVs can be used in combination, to prov ide better flow control flexibility and to better operate low emission combustion systems, the combustion portion can be prov ided with.
• the combustion portion can be prov ided with.
• only NGVs can be env isaged, even though combination of NGVs and IGVs provides for a higher fle ibil ity.
• NGVs can for instance be used to provide better tuning of the air flow and thus improved control of low emission combustion systems, such as so-called dry-low NOx emission combustions systems, without adversely affecting the overall efficiency of the machine.
• IGVs Even without NGVs, can be env isaged for better anti-surge control of the air compressor of the gas turbine engine.
• IGVs at the inlet of the compressor portion can be used for tuning the air flow rate even if no NGVs are prov ided, while multi-shaft gas turbine engines would require both IGVs and NGVs in combination.
• multi-shaft gas turbine engines are preferably used. e.g. for improved efficiency over an extended rotational speed range, e.g. when the turbine speed ranges between 50% to 105% of the nominal rotational speed.
• One, some or all compressors of the compressor section can include one or more v ariable stator vanes (VSVs), i.e. movable statoric blades, to adjust the operating conditions of the compressor.
• VSVs v ariable stator vanes
• Fig. 8 movable statoric blades
• VSVs v ariable stator vanes
• IGVs IGVs
• VSVs and IGVs can be used in combination in one, some or all compressors of the compressor portion.
• VSVs can be particularly used when an extensive aerodynamic operativ e range is desirable. In such case, VSVs can increase the overall efficiency of the compressor portion, since the geometry of several compressor stages can be adapted to the operating conditions of the compressor.
• IGVs and VSVs can be mechanically coupled to one another, such that they are adjusted simultaneously with the same adjusting actuator.
• IGVs and VSVs can be at least partly independent from one another, i.e. the VSVs of at least one compressor stage can be adjusted by an actuator that is independent of the actuator adjusting the IGVs.
• each air compressor can include one or more compressor stages.
• the air compressors may be axial compressors, centrifugal compressors, or mi ed centrifugal and axial compressors, or combinations thereof.
• one or more axial compressor can be combined with one or more centrifugal compressor.
• at least one axial compressor is arranged upstream of at least one centrifugal compressor.
• each compressor includes no centrifugal stage or one centrifugal stage and from 1 to N a ial stages, wherein in some embodiments N can be comprised between 4 and 30, preferably between 4 and 20.
• the compression ratio of a compressor can be comprised between approximately 1 .5 and approximately 35, preferably between 1 .5 and 30.
• the total compression ratio of the air compressor port ion can be up to 60.
• each stage can comprise a set of circularly arranged rotating blades, co-acting with a diffuser (centrifugal compressor) or with a set of stationary blades (axial compressor).
• Each tu bine can be an action turbine (also know n as impulse turbine) or else a reaction turbine. Action or impulse turbines are preferably used for instance for higher rotational speeds, for instance between about 6000 and about 1 2000 rpm, while reaction turbines are preferably used for instance for lower rotational speeds, e.g. below 4000 rpm.
• High-speed, action turbines usual ly include a lower number of stages, for instance between 1 and 4 stages preferably between 2 and 3 stages.
• Low-speed react ion turbines may have a larger number of stages, for instance four or more stages. While in some embodiments action turbines w ith a low number of stages and high rotational speeds are used as low-pressure turbines, directly coupled to the shaft line, in some embodiments, low-speed turbines with a larger number of stages, e.g. 3 or more stages, preferably four or more stages, for instance six or more stages, are used as low-pressure power turbines, directly coupled to the shaft line 2. In some embodiments, low-speed power turbines may be advantageously used in direct coupling with the shaft line 2, such that a gearbox for reducing the rotational speed can be dispensed with.
• Each turbine stage can include a set of stationary blades and a set of rotating blades.
• the first turbine stage may be devoid of stationary blades and only include rotating blades.
• Each turbine can be a high-speed turbine or a low speed turbine.
• the term "high speed turbine” as used herein may be understood as a turbine having a rated rotational speed of about 4000 rpm or more, preferably of about 5000 rpm or more.
• the term "low speed turbine as used herein may be understood as a turbine having a rated rotational speed of about 4000 rpm or less. Low speed turbines preferably have rated rotational speeds between about 3000 and about 3600 rpm.
• the two turbines can be co-rotating, i.e. they can rotate both clockwise, or both counter- clockwise.
• the two sequentially arranged turbines can be counter-rotating, i.e. one can rotate clockwise and the other can rotate counterclockwise. In such case, one or more rows of circularly arranged stat iffy blades can be dispensed with, this resulting in a more compact arrangement and higher turbine efficiency.
• the combustor portion (25, 35, 45, 65, 89) can comprise a multi-can combustor. In other embodiments the combustor portion can comprise an annular combustor. In some embodiments the combustor portion can comprise a silo- combustor. Combinations of different combustors can be envisaged as well.
• the combustor portion can have a fixed geometry or a variable geometry, to adjust the air flow inside and outside a combustion liner.
• Each combustor portion may include one or more fuel control valves, for instance from one to ten fuel control valves, preferably from one to five fuel control valves, to adjust the fuel distribution, e.g. among a plurality of cans of a multi-can combustor.
• the gas turbine engine may include a radial or an axial exhaust gas discharge at the hot side and an axial or radial air inlet at the cold side. Radial air inlet and radial exhaust gas discharge are advantageously selected when the shaft line extends on the side of the air inlet or exhaust gas discharge, respectively, and no room is available to arrange an axial ai inlet or an axial exhaust gas discharge.
• axial air inlet and or axial exhaust gas discharge are preferably used whenever room is available on the cold side or hot side, respectively, of the gas turbine engine.
• all multi-shafts gas turbines like those of Figs. 6. 7. 8 and 9. allow a facilitated start-up of the gas turbine engine, since the gas generator is mechanically disconnected from the gas compressor section 13.
• Each gas turbine engine may be further comprised of a starter or starting motor.
• the starter may include a smaller driver, such as a hydraulic motor, a combustion engine, an electric motor, an expander, a steam turbine, for instance, to start rotation of the gas turbine engine.
• a starter 120 is shown in Fig.6.
• multi-shaft gas turbine engines provide for easier startup, with starting motors which may have a total power rate of around 1 -3%, typically 2% of the total power rate of the gas turbine engine.
• starting motors which may have a total power rate of around 1 -3%, typically 2% of the total power rate of the gas turbine engine.
• One-shaft gas t urbine engines m ay- require larger starting motors, for instance having a power rate of around 15-20% of the total power rate of the gas turbine engine.
• a starter helper can be provided along shaft line 2.
• a starter helper is a driv ing machine which is capable of starting the gas turbine engine and further to provide supplemental mechanical power to drive the load whenever the power generated by the gas turbine engine is insufficient.
• a starter helper may have a power rate up to 25 MW. In some embodiments, larger starter helpers can be used, having a power rate e.g. up to 60 MW.
• the starter/helper can be an electric motor. In other embodiments the starter/helper can be a reversible electric machine, which can be switched alternatively in an electric motor mode or in an electric generator mode, such that the same electric machine can operate as a starter, as a helper and as a generator as well.
• a turning gear can be provided, to keep the shaft of the gas turbine engine into slow rotation upon shut down of the gas turbine engine.
• a turning gear 122 is shown schematically in Fig.6. Similar turning gears can be prov ided also in other gas turbine engine embodiments. Slow turning of the shaft upon shut down of the gas turbine engine prevents adverse effects on the rotating and stationary components of the gas turbine engine caused by thermally induced deformations of the camber of the shaft, for instance.
• the gas turbine can include a chiller for cooling the air at the inlet of the compressor portion, in particular when the gas turbine engine is installed in a hot place. In Figs.
• a chiller is schematically shown at 88.
• Inlet air can be chilled by heat exchange with a cooling fluid.
• the cooling fluid can be one the refrigerant fluids processed by the compressor train whereto the gas turbine engine belongs, or processed by another compressor train of the same LNG system or can be a chilled fluid from another process, separate from the LNG system.
• the chiller may be dispensed with if the ambient temperature is sufficiently cold.
• the driver section 11 can include different kinds of prime movers for driving the compressor train.
• Gas turbine engines arc particularly advantageous e.g. when a portion of the natural gas processed by the LNG system is available for use as fuel for the driver section 1 1 .
• gas turbine engines may be combined to electric motors acting as starters or helpers, i.e. providing additional mechanical power, e.g. when the efficiency of the gas turbine engine drops and the mechanical power generated thereby becomes insufficient to drive the compressor train.
• electric drivers i.e. electric motors
• gas turbine engines can be more convenient than gas turbine engines.
• the electric motor is labeled "EM".
• electric motors may allow improv ed flexibility in terms of speed adjustment, e.g. through a variable speed drive.
• gas turbine engines or electric motors can offer better solutions in terms of efficiency, especially in off-design operating conditions.
• Variable speed electric motors as prime movers may be particularly advantageous when low rotational speed and high torque are required under some operating conditions.
• gas turbine engines and electric motors can be used, wherein one or more gas turbine engines drive one or more electric generators to convert chemical energy of a fossil fuel, such as gas, into electric power. This latter is used to drive one or more variable speed electric motors, which in turn drive one or more compressor trains.
• Figs. 10, 11, 12, 13, 14, 15, 16 and 17 illustrate exemplary layouts of driver sections 11 including respective electric motors 124, and its electrical connections.
• the electric motor(s) can be powered by an electric power distribution grid, or by electric generators, in turn driven by gas turbines.
• each electric motor can have a power rate of about 100 MW or lower, preferably of 75 MW or lower.
• smaller electric motors i.e. electric motors hav ing a lower power rate
• helpers i.e. to provide additional power to supplement the main driver. This can be beneficial, e.g. when the power supplied by the main driv er can fluctuate due to for instance to environmental conditions, or when the requested driv ing power exceeds for whatever reason the rated power of the driver.
• Electric helper motors may hav e a power rate of up to around 40 MW, preferably of about 30 MW or less.
• the electric motor 124 can be a synchronous motor. In other embodiments the electric motor 124 can be an asynchronous or induction motor.
• the electric motor 124 is electrically connected to the electric power distribution grid G through a variable speed drive system.
• the variable speed drive system comprises a variable frequency drive 129.
• the variable frequency drive 129 can be a voltage source inverter (VSI) or a current source inverter (CSI), for instance a load commutated inverter (LCI).
• the variable frequency drive in turn comprises a rectifier, a direct current section, or a direct voltage section, and an inverter.
• the variable frequency drive can be used to modify the frequency of the electric voltage supplied to the electric motor 124 and make it independent of the grid frequency, i.e. the frequency of the electric power distribution grid G.
• the variable frequency drive can be used e.g. to start the compressor train providing high torque at low rotational speed and reducing the voltage drop at the grid connection point.
• variable frequency drive 129 is electrically coupled to the electric power distribution grid through a transformer 127.
• the transformer may have a 3 -phase primary winding and a 6-phase secondary winding.
• the electric motor can be a 3 -phase electric motor, while in the second case the electric motor can be a 6-phase electric motor.
• the 6-phase electric motor can be an LCI synchronous electric motor.
• variable frequency drive 129 is directly coupled to the electric power distribution grid G.
• a step-down transformer 127 is arranged between the electric power distribution grid G and the variable frequency drive 129, and a step-up transformer 128 is arranged between the variable frequency drive 129 and the electric motor 124.
• the step-down transformer 127 can have a 3 -phase primary winding and a 6-phase secondary winding.
• the step-up transformer can have a 6-phase primary and a 6-phase secondary winding and the electric motor 124 can be a 6-phase electric motor.
• the step-up transformer can have a 6-phase primary winding and a 3 -phase secondary winding, and the electric motor 125 would then be a 3 -phase motor.
• a multi-level voltage source inverter can be provided, between the grid and the electric motor, to reduce the harmonic content of the electric voltage.
• variable frequency drive 129 can be used to adjust the rotational speed of the electric motor 124 in steady state conditions, when the rotational speed of the compressor train requires adjustment, as well as to set a speed-up ramp of the electric motor during start up, to control the time required to achieve a steady state rotational speed and/or to control the voltage drop at the grid connection during start-up of the electric motor 124.
• the electric motor 124 is electrically coupled to the electric power distribution grid G through a soft starter 131.
• the soft starter 131 comprises a first connection branch 133 A and a second connection branch 133B, which can be selectively used to electrically connect the electric motor 124 to the electric power distribution grid G.
• a switch 135 selectively connects one of said two branches 133 A, 133B to the electric power distribution grid G.
• the first branch 133 A can include a direct electric connection.
• the second branch 133B can comprise a step-down transformer 137, an AC manipulation device 139, such as an AC/AC converter or a variable frequency drive, and a step-up transformer 141.
• the AC manipulation device can be any of the above described variable frequency drives, i.e. a VSI, a CSI or a LCI.
• the AC/AC converter can be a voltage converter.
• the first branch 133 A can comprise a step-down transformer 130 and the second branch 133B can comprise a step-down transformer 137 and an AC manipulation device 139.
• the AC manipulation device 139 is a 3- phase electric device.
• the AC manipulation device 139 can be a six -phase device.
• Fig. 15 illustrates a six-phase AC/AC converter combined with step-down transformer which provides three input and six output phases, and further combined with a step-up transformer 141 with six input phases and three output phases.
• Fig. 16 illustrates a configuration wherein a 3-phase/6-phase step-down transformer 137 is provided along branch 133B upstream of the 6-phase AC manipulation device 139.
• a 3-phase/6-phase step-down transformer 138 is provided.
• the electric motor 124 can be a 6-phase electric motor. In all embodiments of Figs. 13, 14, 15 and 16 the electric motor 124 is started by connecting the electric motor 124 to the electric power distribution grid G via branch 133B. The rotation of the electric motor 124 is controlled by the AC manipulation device and is gradually accelerated from zero to the rated rotational speed.
• the switch 135 Upon reaching the rated rotational speed, the switch 135 switches the connection from branch 133B to branch 133A and the electric motor 124 will then maintain its rated speed, which is defined by the number of poles of the electric motor 124 and by the grid frequency. No speed adjustment is possible once the electric motor has reached a steady-state condition.
• both step-up and step-down transformers can be omitted.
• the electric motor 124 can be an induction motor or a synchronous motor.
• the AC manipulator device 139 can have a lower power rate than the power rate of the respective electric motor 124, since it is used only at start-up, while the variable frequency drive 129 of Figs. 10, 11 and 12 shall have a power rate sufficient to supply the maximum rated power of the electric motor 124.
• Fig. 17 a direct-on-line coupling of the electric motor 124 to the electric power distribution grid G is shown.
• a captive transformer 143 is arranged between the electric power distribution grid G and the electric motor 124 in this case.
• the electric motor 124 shall be a self-starting motor, e.g. an induction motor.
• the electric motor 124 of Fig. 17 is caused to rotate at a fixed speed, determined by the grid frequency and by the number of poles of said electric motor.
• the rotational speed is usually 3.000 rpm when the electric grid frequency is 50 Hz and 3.600 rpm when the electric grid frequency is 60 Hz. In some embodiments, the speed can be set at 1500 rpm or at 1800 rpm.
• Figs. 13, 14, 15 and 16 can be used to adjust the speed-up ramp of the electric motor, e.g. to control the time required to achieve a steady state rotational speed and/or to control the voltage drop at the grid connection during start-up of the electric motor.
• the driver section 1 1 can include a steam turbine or a vapor turbine, as schematically shown in Fig. 1 , where ST schematically represents a steam or vapor turbine.
• vapor turbine may be understood as a turbine wherein power is generated by the expansion of a fluid different from steam, processed in a substantially closed system, where the fluid undergoes cyclical thermodynamic transformations, to convert heat power into mechanical power.
• the vapor turbine can be a turbine of an ORC (Organic Rankine Cycle) arrangement, where an organic fluid is processed.
• ORC Organic Rankine Cycle
• a steam turbine can have a power rate of 100 MW or less, preferably of 60 MW or less.
• driver 1 1 can be an expander, labeled in Fig. 1 with "EX", for instance an expander where compressed C0 2 or any other gas is processed.
• the driver 1 1 can be a hydraulic turbine.
• the driver section 1 1 can comprise a reciprocating internal combustion engine, such as a gas engine or a diesel engine. This kind of driver is indicated w ith "GE" in the Fig. 1 .
• the driver section 1 1 can include a combination of two or more drivers, of the same or of different kinds, for instance two or more gas turbine engines, or one or more gas turbine engines and one or more electric motors in combination.
• a gas turbine engine can be used in combination with a steam or vapor turbine.
• one or more auxil iary machine aggregates 1 7, 1 9 can be prov ided along shaft line 2.
• Each auxil iary machine can be a driven machine, a driv ing machine or a reversible machine capable of operating in a driving machine mode and in a driven machine mode alternatively, e.g. depending upon the operating conditions of the driver section 1 1 and/or of the gas compressor section 13.
• One or each au iliary machine aggregate may include one or more machines selected from the group consisting of: a starter motor, a helper motor, an electric generator, a starter helper, a starter generator, a helper generator, a starter helper generator, an expander.
• auxil iary machine(s) can comprise one or more further compressor(s), in addition to those of the gas compressor section 1 3.
• starter can be understood as a driving machine which is configured and controlled to initiate rotation of a prime mover shaft, for instance of a gas turbine engine.
• helper can be understood as a drivi ng machine which is configured and controlled to provide supplemental mechanical power to the shaft line 2, when the prime mover of the driver section prov ides insufficient power to the shaft l ine 2.
• generator may be understood as an electric machine which can conv ert mechanical power av ailable from the shaft line 2 into electric power.
• starter/hel per/generator can be understood as an au iliary machine which is configured and controlled to operate as a helper or as a generator selectively.
• starter/hel per can be understood as an auxiliary machine which is configured and controlled to operate as a starter or as a helper selectively.
• starter/generator as used herein can be understood as an auxi l iary machine which is configured and controlled to operate selectively a starter or as a generator.
• starter/hel per/generator as used herein can be understood as an auxi ligey machine which is configured and controlled to operate selectively as a starter, a generator or a helper.
• no auxiliary machine aggregates are prov ided.
• one or more auxiliary machine aggregates in one or more positions along the shaft line 2 can be provided.
• the one or more auxiliary machines can be arranged on the cold side of the gas turbine engine, i.e. the side of the gas turbine engine wherein the compressor section and the air inlet are positioned, or on the hot side of the gas turbine engine, i.e. the side of the gas turbine engine wherein the turbine(s) and exhaust gas discharge are positioned.
• the auxiliary maehine(s) or machine aggregated ) can be also arranged in an intermediate position betw een the driv er and driven machines, for example between the gas turbine engine of driv er section 1 1 and the gas compressor section 13 or between two compressors of the gas compressor section 13.
• Exemplary embodiments can include a helper arranged adjacent the gas compressor section 1 3.
• the helper can be used to more efficiently drive the gas compressor section 1 3 into rotation in case of failure of the main driver section 1 1 .
• the helper can be located along shaft l ine 2 betw een the driv er section 1 1 and the gas compressor section 13.
• a single-shaft gas turbine engine is envisaged, such as in Fig.
• the helper can be located on a side of the driv er section 1 1 and the gas compressor section 1 3 can be arranged at the opposite side of said compressor section .
• a machine e.g. an electric machine, suitable for operating in a helper and/or starter and/or generator mode can be arranged on a side of the gas compressor section 13 opposite to the driver section 1 1 , i.e. the gas compressor section 13 can be located along shaft line 2 in an position between the driver section 1 1 and the auxiliary machine. Power from the driv er 1 1 does not require to flow through the auxiliary machine in this case.
• arranging the compressor section at the end of the compressor train 3 may, however, be preferable.
• a helper can include an electric motor, or a different driver, for instance an expander, or else a steam turbine, a reciprocating engine, such as a diesel engine, or a reciprocating gas engine, for instance.
• the auxiliary machine aggregate can include an electric starter and an electric helper.
• the helper can be configured as a helper generator.
• a single electric machine selectively operating as a starter, as a helper or as a generator can be preferred, since a more compact compressor train can thus be configured.
• separate electric machines arc provided to function as starter and as helper. The configuration thus obtained is redundant and leads to improved availability.
• a starter can be provided to accelerate a gas turbine engine from zero to a first rotational speed, prior to igniting the turbine. Once the first rotational speed has been achieved, the hel er can take ov er the function of turbine acceleration up to e.g. 60% or 70% of the rated turbine speed. The turbine can then be started and further accelerated prov iding power to the shaft line 2 in combination with the helper, until the rated rotational speed is achiev ed.
• an electric motor can be used as a starter or as a starter generator and a separate machine using a different source of power, such as a steam turbine or an expander (for instance a C0 2 or an ORC expander) can be used as a helper.
• a steam turbine or an expander for instance a C0 2 or an ORC expander
• a transmission 1 5 is prov ided.
• the transmission 1 5 may include a simple shaft.
• a transmission 15 can include two or more shafts or shaft portions. Consecutive shaft portions can be coupled to one another by means of a respective joint.
• rigid joints, or else flexible joints, or combined rigid and flexible joints can be arranged along the same transmission 1 5 between two sequentially arranged sections or machine aggregates. For instance, each transmission 1 5 in the schematic of Fig.
• Joints such as flexible joints, can be particularly useful to adjust axial or angular misal ignments between rotary machines.
• a clutch can be provided in one. some or all transmissions 1 5 along shaft l ine 2. This allows disconnection of one or some of the rotary machines arranged along shaft line 2.
• one or more transmissions 1 5 along shaft line 2 may include a speed manipulation device.
• speed manipulation device can be understood as any device which has at least one inlet shaft and at least one outlet shaft, and wherein the rotational speed of the outlet shaft is or can be different from the rotational speed of the inlet shaft.
• Exemplary embodiments of speed manipulation dev ices can be gearboxes with a fixed transmission ratio, or else gearboxes w ith a variable transmission ratio.
• the gearbox can include an epicycl ic gear train, i.e. a train of gears in w hich the axis of one gear revolves round the a is of another gear. In other embodiments the gearbox can comprise a simple gear train .
• the speed manipulation device can include a variable speed coupling.
• variable speed coupl ing can be understood as a coupling wherein the ratio between an inlet shaft and an outlet shaft can vary, either continuously or step-wise.
• the variable speed coupling can include a Vorecon variable speed coupling, avai lable from Voith Turbo GmbH & Co. KG. Crailsheim. Germany.
• the variable speed coupling can comprise a magnetic continuously variable transmission, a friction or a hydro-v iscous variable transmission.
• speed manipulation device can encompass both dev ices which provide a fixed transmission ratio, as well as dev ices which provide a variable and adjustable speed transmission ratio, between the inlet shaft and the outlet shaft.
• Speed manipulation devices and in particular variable speed couplings can be particularly advantageous when different rotational speeds are useful or necessary for different machines arranged along shaft line 2.
• the gas compressor section 13 can comprise two or more compressors, which require to be operated at different speeds.
• a first compressor can be mechanically coupled to the driver section 11 directly, such that the rotational speed of the driver is substantially the same as the rotational speed of the compressor.
• a speed manipulation device can be arranged between the first compressor and the second compressor, such that the second compressor can be driven at a rotational speed different from the rotational speed of the first compressor. If a variable speed coupling is used, the second compressor can be driven at a variable speed, even if the driver and the first compressor rotate at a constant speed.
• Single-compressor trains wherein the gas compressor section 13 comprise a single compressor can also take advantage from the use of a variable speed coupling arranged between the gas compressor section 13 and the driver section 11, e.g. if the driver is controlled to rotate at a fixed or substantially fixed rotational speed, while the compressor requires speed variations depending upon requirements of the LNG process.
• a variable speed coupling can be used to control rotation of one or more driven machines, including compressors of gas compressor section 13 and possibly one or more auxiliary machines, without changing the speed o the driver.
• Adjustable transmission ratios can be used e.g. when the driver is an electric motor rotating at a fixed rotational speed, set by the frequency of the electric power distribution grid, or when a driv er is used, the efficiency whereof is strongly dependent upon the rotational speed thereof, i.e. the efficiency whereof is strongly dependent upon the rotational speed.
• the gas compressor section 13 can include a variable number of compressors.
• Fig. 18 an embodiment is schematically shown, wherein the gas compressor section 13 comprises a single compressor 125.1.
• the gas compressor section 13 can include two compressors 125.1 , 125.2, as shown in Fig. 19.
• three compressors 125.1 , 125.2, 125.3 can be arranged in the gas compressor section 1 3, as illustrated in Fig. 20.
• a four-compressor arrangement including four compressors 125. 1 , 125.2, 1 25.3, 125.4 is shown in Fig. 2 1 .
• a larger number of compressors is not excluded, but may involve rotor-dynamic difficulties.
• Each gas compressor can comprise either axial stages, radial (typically centrifugal) stages, or both axial and centrifugal stages in a single common casing.
• the compressor is called mixed axial-centrifugal compressor.
• a mixed axial-centrifugal compressor one or more upstream stage(s) which are axial stages, and one or more downstream stages which are radial (centrifugal ) stages. This may be beneficial because the axial stages are usually capable of processing a larger volumetric flow rate, while the centrifugal stages are usually capable of providing more compression capability with respect to axial compressor stages.
• a mixed axial-radial compressor can be used to compress the mixed refrigerant in an APCI® propane mixed refrigerant LNG system described in detail below later on.
• upstream and downstream as used herein are referred to the general direction of the gas flow along the compressor, unless differently specified.
• the terms axial and radial as used herein are referred to the orientation of the rotation axis of the compressor, unless differently speci fied.
• Each mechanical transmission may include or may not include a speed manipulation device, such as for instance a variable speed transmission, or else a gear box with a fixed transmission ratio, as mentioned above.
• Speed manipulation devices can be envisaged whenever two or more sequentially arranged compressors on the same shaft l ine 2 shall rotate at different rotational speeds.
• One or more auxiliary machines can be arranged between two adjacent compressors.
• a starter, a helper or an electric generator, or a multifunctional electric machine e.g. acting as a starter and/or as a helper and/or as an electric generator, depending upon the operating conditions of the compressor train, can be arranged between a pair of sequentially arranged compressors.
• the gas compressor section 13 comprises a clutch, a portion of the train 1 can be disconnected so to make it independent from the other section(s). This disconnection can be used for disconnecting a main driver 11 , for example a gas turbine, from the rest of the train for the periodical maintenance; if the train 1 comprises a helper-motor, the gas compressor section 13 can be maintained operative by means of said helper-motor.
• Each compressor 125.i can be one of a positive-displacement compressor and a dynamic compressor.
• a positive-displacement compressor can be a reciprocating compressor, for instance.
• a reciprocating compressor can be a single-effect reciprocating compressor or a double-effect reciprocating compressor.
• a reciprocating compressor may, moreover, have a single or a multiple cylinder-piston arrangement.
• a dynamic compressor can be a centrifugal compressor or an axial compressor or a mixed axial-centrifugal compressor.
• a combination of one or more positive- displacement compressors and/or one or more dynamic compressors can be arranged in the same compressor train.
• an axial compressor comprises (Fig.22) a plurality of stages, each including a set of stationary (i.e. non-rotating) vanes 147 and a set of rotary blades 149. Stages of rotary blades are alternated by stages of stationary vanes.
• the axial compressor comprises from 1 to 15 stationary stages and from 2 to 16 rotary stages.
• the stationary vanes of one, some or all the sets of stationary vanes can be variable stationary vanes, i.e. their angular position can be adjustable around a respective radial axis.
• Actuators 151 can be provided for varying the angular position of the stationary vanes.
• Stationary vanes having a variable geometry may contribute to improve the overall efficiency of the axial compressor, specifically when the operating parameters of the natural gas liquefaction process vary over time.
• Axial compressors can be used alone or in combination with in-between bearings or overhung centrifugal compressors or both.
• a ial compressors may provide for high flow rate and high efficiency.
• Centrifugal compressors of the gas compressor section 13 can be vertically split compressors, i.e. so-called barrel type compressors. Vertically split compressors are particularly efficient when high gas pressures must be achieved.
• the compressors can be horizontally split compressors.
• Horizontally split compressors are particularly advantageous in terms of maintenance, since the compressor bundle, i.e. the inner components of the compressor, can be removed from the outer casing without the need for removing other machinery arranged along the shaft line 2.
• the compressor bundle i.e. the inner components of the compressor
• the compressor bundle i.e. the inner components of the compressor
• the compressor bundle can be removed from the outer casing without the need for removing other machinery arranged along the shaft line 2.
• a combination of one or more vertically spl it compressors and one or more horizontally split compressors can be envisaged.
• Horizontally spl it compressors are provided with compressor diaphragms and a compressor rotor arranged in a casing 1 5 1 , which is comprised of at least two casing portions 1 5 1 . 1 , 1 5 1 .2 matching along a horizontal plane P-P, see Fig. 23.
• the diaphragms are normally divided into upper and lower portions respectively configured to be positioned in the upper and lower casing portions 1 5 1 . 1 . 1 5 1 .2.
• Access to the interior of the compressor, and removal of diaphragm components, rotor, bearings and other machine components from the casing is easy, since this requires only l ifting of the upper casing portion 1 5 1 . 1 without requiring dismantl ing of adjacent machinery along shaft line 2.
• a vertically split compressor is provided with a compressor rotor and a compressor bundle arranged in a casing 1 53 (Fig.24), comprised of a central barrel 1 53. 1 and two casing end portions 1 53.2, 1 53.3.
• a casing 1 53 (Fig.24)
• a central barrel 1 53. 1 and two casing end portions 1 53.2, 1 53.3.
• One or both casing end portions 1 53.2. 1 53.3 can be removably coupled to the central barrel 1 53. 1 along respective vertical planes P I -P I , P2-P2.
• the compressor bundle and rotor can be removed from the central barrel 1 53. 1 by opening either one or the other of said casing end portions - JO -
• one of the end portions 153.2, 1 53.3 is monol ithically connected to the central barrel 1 53. 1 , i.e. formed (e.g. forged) as a single component.
• the vertically split compressor is arranged at the end of the shaft line, such that access to the interior thereof is possible from the front end of the train, without requiring dismantling of other machinery on the shaft line 2.
• Each compressor may have one or more compressor stages.
• Each centrifugal compressor can have an in-between bearings or an overhung arrangement.
• the "i n-between bearing” arrangement can be understood as an arrangement wherein one or more compressor stages are arranged between end bearings.
• An in-between bearing arrangement is also referred to as a "beam type " arrangement.
• One or more centrifugal impellers are mounted on a shaft for rotation and the shaft is supported at opposite sides by respective bearings.
• overhung arrangement can be understood as a arrangement wherein one or more compressor impellers are mounted on a shaft, which is supported for rotation by bearings which are located on one and the same side of the impellers. Overhung arrangements may provide advantages over in-between arrangements, since less components are required.
• a portion of a centrifugal multi-stage compressor comprised of a plurality of compressor stages in an in-between arrangement is schematically show n in Fig. 25.
• Each compressor stage comprises a rotating im eller 1 55 and a diffuser 1 57.
• Each compressor stage but the last one further comprises a return channel.
• the rotating impeller 1 55 comprises a hub 1 55. 1 and a plurality of blades 1 55.2.
• the impeller can be a shrouded impeller, or an un shrouded impeller.
• a shrouded impeller comprises a shroud which forms closed flow passages between adjacent impeller blades.
• Each blade can be a two-dimensional or a three-dimensional blade.
• a three- dimensional (or 3D-blade) means a twisted blade (three-dimensional curvature) and two-dimensional (or 2D-blade) means constant blade angle from hub to shroud (bi- dimensional curvature).
• a compressor can include only 3D-impellers, i.e. impellers having 3D-blades, only 2D-impellers, i.e. impellers hav ing 2D-blades, or a combination of 3D-impeliers and 2D-impeilers.
• the compressor may include only shrouded impellers, or only unshrouded impellers.
• both shrouded impellers and unshrouded impellers can be combined in the same compressor, such as in HPRC (High Pressure Ratio Compressors), wherein unshrouded impellers are preferably positioned in most upstream stages and shrouded impellers are positioned most downstream stages.
• HPRC High Pressure Ratio Compressors
• Each diffiiser can be a bladed diffuser or an un bladed. diffiiser.
• a bladed diffuser stationary blades (i.e. blades which do not rotate with the impeller) are arranged within the diffuser to orient the flow exiting the impeller.
• variable-geometry bladed diffusers can be provided.
• a variable- geometry diffuser comprises diffuser blades each or some of which comprises at least an adjustable blade portion, the inclination whereof can be adjusted to suite different operating conditions.
• a return channel 1 59 re-directs the gas flow exiting the diffuser of the upstream stage towards the inlet of the impeller of the downstream stage.
• Compressors 125 of the gas compressor section 13 can be single-phase, straight-through compressors as schematically shown in Fig. 25. Gas enters the compressor through an inlet 122 and exits the compressor at a discharge side 124, ail compressor stages being arranged between the inlet 122 and the discharge side 124.
• one or more compressors of the gas compressor sect ion 13 can be double-flow compressors, as shown in Fig. 26, comprised of a first inlet 122.1 and a second inlet 122.2 and two sets of substantial ly symmetrically arranged compressor stages, each comprising one or more impellers and relevant diffusers and return channels.
• a combined discharge 124 collects the compressed gas from the two most downstream compressor stages of the two sets of symmetrically arranged compressor stages.
• double-flow compressors may have advantages over straight through compressors.
• the inlet flow is split into to partial inlet flows entering the compressor at the first inlet 122.1 and second inlet 122.2.
• the inlet speed is reduced and the axial loads on the shaft are balanced.
• a balance drum can thus be dispensed with.
• each of those substantially symmetrically arranged set of compressor stages has its own discharge volute and compressed gas flows are recollected together downstream of the discharge volutes.
• cooling of the gas during the compressor process can be provided, to keep operating temperatures below material or process limits and or to improve the overall efficiency of the compressor.
• a multi-phase compressor can be envisaged for this purpose, wherein cooling nozzles permit partially compressed, hot gas to be extracted from a first compressor phase. The extracted gas can be cooled in an external heat exchanger and finally returned through a cooler return to the inlet of a subsequent compressor phase.
• Fig. 27 schematically illustrates a straight-through compound two-phase centrifugal compressor comprising a first compressor phase 125 A and a second compressor phase 1 25 B.
• the first compressor phase 1 25 A comprises three compressor stages and the second compressor phase 125B comprises two compressor stages.
• a different number of compressor stages for each compressor phase can be provided.
• a cooler outlet 161 collects partly compressed, hot gas from the diffuser of the most downstream. compressor stage of compressor phase 125 A.
• the cooler outlet 161 is in fluid communication with a heat exchanger 1 62, where the partially compressed gas is cooled, e.g. by heat exchange against a cooling fluid, such as air or water, or else a flow of refrigerant from the LNG process. Cooled, partly compressed gas is returned to the most upstream compressor stage of the second compressor phase 125B through a cooler return 163 and further sequentially compressed in the compressor stages of the second compressor phase 125B.
• a multi-stage straight-through compressor as shown for instance in Fig. 25 or 27 may provide higher compression ratios than a single stage compressor. While in Fig.27 the multi-phase compressor configuration with intermediate cool ing is illustrated in a straight through compressor configuration, simila intermediate cooling arrangements can be provided also in a double-flow compressor as shown in Fig.26. Different arrangements of extraction(s) of partially compressed gas from the compressor and different arrangements of injection(s) of partially compressed gas, in the compressor can be provided, with or without cool ing of the gas prior to re- injection. For balancing the axial thrusts caused by the gas compression action on the compressor shaft, in some arrangements the compressor stages are arranged in a back- to-back configuration, as schematically shown in Fig.28.
• the compressor stages are div ided into two sets or phases 125C, 125D, and the impellers of the two phases are back-to-back, the impeller inlets of the first set facing opposite the impeller inlets of the second set.
• a heat exchanger 162 can be arranged between the first discharge 124. 1 and the second inlet 122.2, such that partly compressed gas can be cooled prior to entering the second compressor phase 125D, increasing the overall efficiency of the back-to-back compressor.
• Especially straight-through compressors can include a balancing piston to balance the axial thrust generated by the gas being processed by the impelier(s) on the shaft, as shown at 126 in Fig.25 by way of example.
• one or more compressors in gas compressor section 13 can be provided with side stream inlets or nozzles, such that a main compressed gas stream can be split into a plurality of side streams, which are expanded at different pressure lev els to exchange heat with the natural gas and or with a further refrigerant gas.
• the lowest pressure stream is returned at the gas inlet of the compressor while the side streams at intermediate gas pressures are returned to intermediate compressor stages through said side stream nozzles.
• Fi . 29 illustrates an exemplary embodiment of side stream nozzles in a straight through com ressor, but it shall be understood that a side-stream nozzle arrangement can be provide in any one of the above mentioned compressors, for instance in a double-flow compressor or in a back-to-back compressor arrangement.
• a five-stage centrifugal compressor is shown by way of example, which comprises a compressor inlet 122 and a - - compressor discharge 124.
• Side stream nozzles 1 22 A, 122B, 122B are shown at the inlet of the second, third and fourth compressor stage.
• One or more compressors of gas compressor section 13 can be provided with inlet guide vanes at one, some or all compressor stages.
• the inlet guide vanes of one, some or all compressor stages can be variable inlet guide vanes, i.e. actuators can be provided to vary the geometry of the vanes according to the operating conditions of the compressor.
• actuators can be provided to vary the geometry of the vanes according to the operating conditions of the compressor.
• inlet guide vanes are shown by way of example at 1 71 , but it shall be understood that similar inlet guide vanes can be provided also in combination with the other compressor configurations described in connection with Figs. 25, 26, 27 and 28.
• any one of the above described compressors can be configured as vertically split or horizontally split compressors.
• the compressor comprises a central shaft or beam whereon the impellers are mounted on the shaft to form a rotor.
• impellers can be stacked one onto the other and torsionally coupled to one another by means of Hirth coupling or the l ike.
• a central rod a ially locks the impellers thus forming a rotor.
• compressor impellers are placed between bearings arranged at the ends of the beam or shaft which supports the compressor impellers.
• one or more impellers can be overhung.
• the compressor may include only overhung impellers or a combination of overhung and in-between-bearings impellers.
• compressors of different typology can be combined on the same shaft line.
• One or more compressors can be arranged in the same casing.
• a compressor can have in the same casing, and arranged on the same shaft l ine, both one or more beam-type impellers and an overhung impel ler, in combination. Intercooling can be prov ided between sequentially arranged - - compressors or compressor phases for improved efficiency.
• a compressor can be integrated in a casing along with a respective electric motor.
• the gas compressor section 13 can comprise one or more integrally geared compressors.
• integrally-geared compressors comprise a plurality of compressor stages mounted on a plurality of shafts, the shafts being drivingly coupled to a central bull gear and can rotate at different rotational speeds.
• Fig. 30 illustrates a schematic arrangement of an integrally geared compressor.
• the integrally geared compressor comprises four compressor stages, each comprised of a respective impeller 155A, 155B, 155C, 155D.
• the impellers 155A, 155B of the first and second stage are mounted overhung on a first shaft 172A and the impellers 155C, 155D are mounted overhung on a second shaft 172B.
• Ail impellers 155A-115D can hyave different sizes.
• the two shafts 172A, 172B are mechanically coupled through respective toothed wheels to a bull gear 173.
• the arrangement allows the impellers of different stages to rotate at different rotational speeds.
• Each compressor stage can be provided with inlet guide vanes, one, some or all of which can be variable inlet guide vanes.
• Bladed or un-bladed diffusers can be used in one or more of each compressor stage.
• Side streams and/or intermediate cooler outlets and cooler inlets can be provided in an integrally geared compressor in quite the same way as disclosed above in connection with beam-type compressors described above.
• integrally geared compressors can be advantageous as they can provide higher efficiency since different compressor stages can rotate at different rotational speeds. Highly compact arrangements can be achieved. Each compressor stage of an integrally geared compressor can moreover be easily provided with variable inlet guide vanes.
• Integrally geared compressors can be combined with in-between bearings centrifugal compressors or overhung centrifugal compressors as described above on the same shaft line, or with axial compressors.
• Axial compressors, as well as centrifugal compressors may be provided with side streams, to provide refrigerant gas at multiple pressure levels.
• One, some or all compressors or compressor phases may include one or more gas extraction ducts (al so referred to as "extractions " herei n ), to provide partially compressed gas for various needs. For instance, partially compressed natural gas can be extracted at a required intermediate pressure to be used as fuel in one or more gas turbine engines used as drivers of one or more compressor trains.
• the gas compressor section 13 can be comprised of a variable number N of compressors, wherein N is usually comprised between 1 and 4, as shown in Figs. 18, 19, 20 and 21.
• Each compressor can be alternatively a vertically split or a horizontally split compressor or an integrally geared compressor.
• Each compressor can be an integral ly geared compressor or a beam-type compressor or an overhung compressor.
• each compressor can be a single phase or multiphase compressor.
• Each compressor can have a simple or a back-to-back configuration.
• Each compressor can be a simple straight through compressor or a double-flow compressor. Interceding can be provided between compressor phases or between serially arranged compressors.
• two or more compressors arc prov ided in the gas compressor section 13, they may all be di fferent from one another. In other embodiments, there may be two, three or four compressors hav ing the same configuration. For instance, if two compressors are provided, they can be both vertical ly split, both horizontally split. or one can be vertically spl it and the other can be horizontally spl it.
• gas inlet and outlet ducts have been represented as upwardly oriented or downwardly oriented for mere pictorial reasons. It shall be understood, however, that the arrangement of the gas inlet and out let ducts of each compressor, including any intermediate gas outlet and gas inlet flu idly connecting different phases of a compressor, as well as any side stream duct or extraction duct can be oriented upwardly or dow nwardly with respect to the rotation axis of the respective compressor.
• Inlet duct(s) and/or outlet duct(s) can be vertical or inclined, i.e. can form an - - angle equal to or different from 0° with a vertical direction.
• the vertical direction is the direction of gravity.
• inlet and/or outlet ducts can be arranged sideways, for instance horizontally, i.e. such as to form an angle of about 90° with the vertical direction and can be arranged symmetrically with respect to a horizontal plane containing the rotation axis of the compressor.
• upwardly oriented inlet and/or outlet gas ducts may have the advantage of simplified erection, since they do not need a baseplate.
• downwardly oriented gas ducts may be advantageous in terms of easiness of mount ing and demounting interventions, especially in case of horizontally split compressors. Sideways arrangement may result in simpler duct layout.
• one, some or ail inlet duct(s), outlet duct(s), side stream(s) and/or extraction(s) may be approximately horizontally oriented.
• CI , C2, C3, be three compressors having different configurations and service, for instance in terms of shaft structure (beam-type vs. integrally geared ), casing structure (horizontally vs. vertically split), number of stages, number of phases, kind of impel ler arrangements (back-to-back or straight in line), number of side stream and or extraction nozzles (0, 1 or more side stream nozzles).
• the gas compressor section 13 can have any one of the following combinations of compressors, wherein the symbol "-" schematically i ndicates a mechanical coupli ng between sequentially arranged compressors:
• compressors CI, C2, C3 are different from one another and wherein each compressor C1-C3 can be:
• a positive-displacement compressor such as a reciprocating compressor, selected from the group consisting of: a single-stage reciprocating compressor and a multistage reciprocating compressor, wherein the multi-stage reciprocating compressor can be a single-effect or a double-effect reciprocating compressor;
• a dynamic compressor selected from the group consisting of: a ial compressors and centrifugal compressors: wherein the axial compressor can comprise one or more of the following features: a plurality of sequentially arranged stages; one or more sets of variable- - - geometry stationary vanes; variable inlet guide vanes; an axiaiiy-spiit casing; a vertically-split casing; one or more side streams; one or more extraction nozzles; the centrifugal compressor can comprise one or more of the following features: a single compressor stage; a plurality of compressor stages; an integrally-geared compressor arrangement; an in-between bearing arrangement; an overhung arrangement; a single impeller or a plurality of impellers per compressor stage; a combination of one or more overhung impellers and one or more in-between-bearings impellers; one or more 2D- impellers; one or more 3D-impellers; one or more shrouded impellers; one or more unshrouded impellers
• gas compressor section 13 and the driver section 1 1 are represented as two separate entities located in two separate positions along shaft line 2, if either the driver section 1 1 or the gas compressor section 13 or both contain more than one component, compressors and drivers can be distributed along the shaft line such that a driver is arranged between two compressors, and/or a compressor is arranged between two drivers. While in the above description some exemplary embodiments of compressor trains and relevant machinery have been disclosed, a more comprehensive disclosure of several configurations of a compressor train according to the present disclosure are given here below.
• Each compressor train disclosed hereafter can include additional machinery, ancillary devices or the like, such as intercoolers between sequentially arranged compressors or compressor phases, air chillers at the inlet of the gas turbine engine, waste heat recovery heat exchangers at the discharge of one or more gas turbine engines, air filters or air treatment equipment, and the like.
• additional machinery such as intercoolers between sequentially arranged compressors or compressor phases, air chillers at the inlet of the gas turbine engine, waste heat recovery heat exchangers at the discharge of one or more gas turbine engines, air filters or air treatment equipment, and the like.
• a compressor train can comprise a driver section and compressor section.
• the driver section usually comprises one driver machine, or prime mover.
• the compressor section can comprise one or more compressors.
• the compressor train comprises a main driver machine, at least a compressor and, optionally, an auxiliary machine.
• the auxiliary machine can be a driven machine, i.e. a machine which absorbs mechanical power provided by a driver machine.
• the auxiliary machine can alternatively be a driving machine, i.e. a machine which generates mechanical power and which can be used as a starter and/or as a helper for the main driver or prime mover, providing additional mechanical power to drive the compressor train.
• the auxiliary machine may also include an electric generator, which can convert mechanical power into useful electric power.
• Each compressor train can further comprise two or more main machines and, optionally, a certain number of secondary machines such as a gear-box, a clutch, a flexible joint, a rigid joint, a variable speed transmission device, etc.
• the main machines can be of three main categories: driver machines, compressors, or auxiliary machines.
• the auxiliary machine can also be in turn a compressor.
• the compressor train can comprise two main machines, i.e. a driver machine and a compressor.
• the compressor train can comprise three main machines, i.e. a driver machine, a first compressor and an auxiliary machine which can in turn be a further compressor.
• the compressor train can comprise four main machines, namely e.g. a driver machine, a first compressor, a second compressor and an auxiliary machine which can in turn be a further compressor.
• main machines namely e.g. a driver machine, a first compressor, a second compressor and an auxiliary machine which can in turn be a further compressor.
• the compressor train can comprise five main machines, such as e.g. a driver machine, a first compressor, a second compressor, a third compressor and an auxiliary machine which can in turn be a further compressor.
• the main machines and the auxiliary machines can be of different types and can be arranged along the shaft line in different positions. Therefore a large number of permutations of these machines is possible.
• a purpose of the present invention is thus to provide a method of generation, and a generator, able to generate and disclose all possible arrangements of said compressor train.
• Figs. 42A, 42B, 42C, 42D and 42E a flow chart is shown which represents the architecture of said method of generation., The flow chart is split in five sections shown in Fig. 42A, 42B, 42C, 42D and 42E for the sake of clarity
• the outcome of the method of generation is a list of arrangements of main machines in the compressor train. Said list of arrangements depends on the number "m max" of main machines constituting the compressor train and the number of different types of main machines which can be combined in the compressor train.
• the method is configured to generate four lists: a first list is generated if the number of main machines in the compressor train is two, i.e. if the compressor train contains two main machines; a second list is generated if the number of main machines in the compressor train is three, i.e. if the compressor train contains three main machines; a third list is generated if the number of main machines in the compressor train is four, i.e. if the compressor train contains four main machines; and a fourth list is generated if the number of machines of the compressor train is five, i.e. if the compressor train contains five main machines.
• Figs.42A, 42B, 42C, 42D, 42E the maximum number
• m max of main machines comprised in the compressor train and the maximum number of types of main machines per each category (driver machine, compressor, auxiliary machine), are set as input of the method in an input section 2001.
• the input section 2001 comprises a step 2006 where the total number "m max" of main machines of the compressor train is defined.
• the input section 2001 further comprises a step 2007 wherein the maximum number of types of main machines per each category is set. More specifically: "D” is the maximum number of types of driver machines, "C” the maximum number of types of compressors, and “M” is the maximum number of types of auxiliary machines or further compressors.
• "m max" can be 1, 2, 3, 4 or 5.
• Each row of the lists that can be generated by the method is identified by a specific value of an index "r", wherein "r" is an integer equal to or greater than 1.
• the main machines are arranged in a specific position of the shaft line.
• the specific position of the main machines along the shaft line is defined by the indexes "i”, “j", “h”, “g” or “k”.
• Each of these indexes is an integer and can take a value from 1 to "m max”.
• Each main machine has its corresponding index: "i” is the index of driver machine, "j” is the index of the first compressor, “h” is the index of the second compressor, “g” is the index of the third compressor, "k” is the index of the auxiliary machine or further compressor.
• the machines will be arranged as follows: first compressor, driver machine, second compressor and auxiliary machine or further compressor.
• Each category of main machines can be of one or more types.
• each main machine is defined by an index
• "x” is the index defining the type of driver machine
• "y” is the index defining the type of the first compressor
• "s” is the index defining the type of the second compressor
• "v” is the index defining the type of the third compressor
• "z” is the index defining the type of the auxiliary machine or of the further compressor.
• the value of index "x" ranges from 1 to 9 and each value of "x" identifies a specific type of driver machine.
• the flow chart of Figs. 42A, 42B, 42C, 42D, 42E comprises four main generating sections 2002, 2003, 2004, 2005, representing respective generating routines. These four sections of the flow chart are used alternatively, depending upon the number of main machines of the compressor train. More specifically: first section 2002(i.e. the routine represented by section 2002) is executed if the compressor train has two main machines; second section 2003 is executed if the compressor train has three main machines; third section 2004 is executed if the compressor train has four main machines; fourth section 2005 is executed if the compressor train has five main machines.
• first section 2002 i.e. the routine represented by section 2002
• second section 2003 is executed if the compressor train has three main machines
• third section 2004 is executed if the compressor train has four main machines
• fourth section 2005 is executed if the compressor train has five main machines.
• Each generating section 2002, 2003, 2004, 2005 has three macro steps: a first routine cycle, labelled 2008, 2009, 2010, 2011 for each section 2002, 2003, 2004, 2005 respectively, for determining the values of the indexes "i", “j", “h”, “g” or "k”, i.e. for selecting the positions of each main machine along the shaft line;
• the indexes "i”, “j”, “h”, “g”, “k” are varied from 1 to “m_max” in order to be always different from one another and in order to cover all their possible combinations.
• the index "x” is varied from 1 to "D”
• the indexes "y”, “s”, “v” are varied from 1 to "C”
• the index "z” is varied from 1 to "M”, in order to select all possible types of main machines for each category of main machine.
• Each row of one of the lists is generated in blocks 2016, 2017, 2018, 2019.
• D(x) (r,i) which means that in the row "r” of possible machine arrangements the driver machine is a driver machine of the type "x" and is arranged in position "i"
• C(y) (r,j) which means that a compressor of the type "y” is arranged in the position "j" for in said arrangement of row "r”.
• the blocks 2020, 2021, 2022, 2023, 2024, 2025, 2026 and 2027 are used for changing and determining the value of the row index "r" of each list.
• a new Excel file can be created having a first Excel sheet filled as follows, and a second sheet called "arrangements" wherein the list of arrangements will be written launching the Excel macro.
• An Excel macro can be written with the following Visual Basic code, which implements the method of generation according to the present invention: :
• D() is the specific type of Driver
• C() is the specific type of Compressor
• M() is the specific type of Auxiliary Machines or Further Compressors
• i, j, h, g, k are the indexes used for selecting the specific position of the main machine along the shaft line
• x, y, s, v, z are the indexes used for selecting the types of main machines to be positioned
• driver machines are selected from the group consisting of:
• auxiliary machines or further compressors are selected from the group consisting of:
• CI a single stage beam type centrifugal compressor
• C2 a single stage overhung type centrifugal compressor
• - C3 a multi-stage straight-through centrifugal compressor
• C4 a multi-stage back-to-back centrifugal compressor
• C5 a multi-stage double-flow centrifugal compressor
• C6 a multi-stage centrifugal compressor with side stream/s and/or extractions
• C9 an axial compressor with side stream/s and/or extractions
• Ml an electric generator
• M2 an electric or steam helper
• M3 an electric or steam starter
• M4 an electric or steam starter-helper
• M5 an electric or steam starter-helper-generator
• CI a single stage beam type centrifugal compressor
• C3 a multi-stage straight-through centrifugal compressor
• C4 a multi-stage back-to-back centrifugal compressor
• C5 a multi-stage double-flow centrifugal compressor
• C6 a multi-stage centrifugal compressor with side stream/s and/or extraction/s;
• each dash can be any one of several possible coupling arrangements.
• two subsequently arranged machines of a compressor train can be drivingly coupled to one another for instance by a mechanical coupling arrangement selected from the following group: a shaft, a rigid coupling, a flexible coupling, a clutch, a gearbox, a variable speed transmission device.
• Dl-Cl D2-C1; D3-C1; D4-C1; D5-C1; D6-C1; D7-C1; D8-C1; D9-C1; D1-C2; D2- C2; D3-C2; D4-C2; D5-C2; D6-C2; D7-C2; D8-C2; D9-C2; D1-C3; D2-C3; D3-C3; D4-C3; D5-C3; D6-C3; D7-C3; D8-C3; D9-C3; D1-C4; D2-C4; D3-C4; D4-C4; D5- C4; D6-C4; D7-C4; D8-C4; D9-C4; D1-C5; D2-C5; D3-C5; D4-C5; D6-C4; D7-C4; D8-C4; D9
• 6804 different machine arrangements can be generated by the method of generation described above. These 6804 arrangements are generated using generating section 2003 of Figs. 42A, 42B, 42C, 42D, 42E and are listed here below:
• D4-C4-M4 D5-C4-M4; D6-C4-M4; D7-C4-M4; D8-C4-M4; D9-C4-M4; D1-C5-M4;
• D1-C9-M4 D2-C9-M4; D3-C9-M4; D4-C9-M4; D5-C9-M4; D6-C9-M4; D7-C9-M4;
• D4-C4-C2 D5-C4-C2; D6-C4-C2; D7-C4-C2; D8-C4-C2; D9-C4-C2; D1-C5-C2; D2-
• D9-C4-C9 D1-C5-C9; D2-C5-C9; D3-C5-C9; D4-C5-C9; D5-C5-C9; D6-C5-C9; D7-
• M3-C3-D6 M3- -C3 -D7
• M3- -C3 -D8 M3- -C3 -D9
• M3- -C4- -Dl M3-C4 D2;
• M3-C6-D7 M3- -C6- -D8 M3- -C6- -D9 M3- -CI- -Dl M3- -CI- -D2 M3-C7 D3; M3-C7-D4
• M3-C7-D5 M3- -CI- -D6 M3- -CI- -D7 M3- -CI- -D8 M3- -CI- -D9 M3-C8 Dl; M3-C8-D2
• M4-C5-D5 M4- -C5 -D6 M4- -C5 -D7 M4- -C5 -D8 M4- -C5 -D9 M4-C6 Dl; M4-C6-D2
• M4-C7-D1 M4- -CI- -D2 M4- -CI- -D3 M4- -CI- -D4 M4- -CI- -D5 M4-C7 D6; M4-C7-D7
• M5-C7-D4 M5- -CI- -D5 M5- -CI- -D6 M5- -CI- -D7 M5- -CI- -D8 M5-C7 D9; M5-C8-D1
• the first 800 arrangements are:
• the first 2000 arrangements are:
• Each compressor train 1 can include a gas compressor section 13 with one, two, three or four compressors, as described above.
• Each one of the several compressor trains can include a combination of compressors as set forth above.
• the two, three or four compressor trains 1 can be arranged in parallel, or can be fin idly coupled to one another, in that compressor inlets or discharge sides of one or more compressors of one train are flu idly coupled to one or more inlets or discharge sides of one or more compressors of another train.
• Fig. 31 illustrates a schematic arrangement of four compressor trains 1.1, 1.2, 1 .3 and 1 .4. coupled to a cooling and liquefaction system schematically shown at 5 and each provided with a respective driver section 11.1, 11.2, 11.3, 1 1 .4 and a gas compressor section 13. 1 , 13.2, 13.3. 13.4.
• each compressor of the compressor train can be flu idly coupled to the cooling and liquefaction system 5.
• at least one or more compressors are flu idly coupled to one or more compressors of the same compressor train or of a parallel compressor train.
• the inlet of at least one compressor of the compressor train can be flu idly coupled to the cooling and liquefaction system 5 to receive therefrom a gas flow to be processed by the compressor.
• the inlet of at least one compressor of the compressor train can be flu idly cou led to the discharge side of another compressor of the same compressor train or of another compressor train, to receive partly compressed gas therefrom and further compress said gas.
• Said at least one compressor can in turn include a compressor discharge fluidly coupled to the cool ing and liquefaction system 5 to provide compressed gas thereto.
• the discharge side of the compressor can be fluidly coupled to the inlet of one or more compressors of the same compressor train or of another compressor train.
• the cooling and liquefaction system 5 can be a cooling system for cooling the natural gas stream, or a prc-cool ing system used for prc-cooling a refrigerant which is in turn employed for cooling the natural gas stream.
• the cooling and liquefaction system 5 can include heat exchanger arrangements for pre-cooling a refrigerant which is processed in a separate cooling and l iquefaction system and at the same time for cooling the natural gas. Exemplary embodiments of cooling and liquefaction systems will be described later on.
• Fig. 32 illustrates a compressor train 1. 1 comprising a gas compressor section 1 . 1 , wherein three compressors 1 25. 1 , 125.2, 125.3 each have a gas inlet and a gas discharge side in direct fluid connection with the cool ing and liquefaction system 5.
• compressor 1 25. 1 has a gas inlet and a gas discharge side directly coupled to the cooling and l iquefaction system 5
• compressor 125.2 has a gas inlet fluidly coupled to the cool ing and liquefaction system 5 to receive gas therefrom, and a gas discharge side which is fluidly coupled to the gas inlet of the third compressor 1 25.3. the gas discharge side whereof is in turn fluidly coupled to the cool ing and liquefaction system 5.
• Fig.34 illustrates a first compressor train 1.1 and a second compressor train 1.2.
• the first compressor train 1.1 is comprised of a first compressor 125.1 and a second compressor 125.2.
• a different number of compressors can be provide, e.g. a single compressor 125.2, or more than two compressors.
• the second compressor train 1 .2 comprises four compressors 125.3. 125.4, 1 25.5, 125.6.
• Compressor 1 25. 1 has a compressor inlet fluidly coupled to the cooling and liquefaction system 5 and receiving gas therefrom.
• the gas discharge side of compressor 125.1 can be coupled to the gas inlet of the second compressor 125.2 of the first compressor train 1.1.
• the discharge side of the second compressor 125.2 can be fluidly coupled to the cooling and liquefaction system 5 or, as shown in the schemat ic of Fig. 34, to the gas inlet of one of the compressors of the second train 1.2, for instance the fourth compressor 125.6.
• the three compressors 125.3, 125.4 and 125.5 of second compressor train 1.2 are arranged in series, such that gas from the cooling and liquefaction system 5 is sequentially processed by the three compressors 125.3, 125.4, 125.5 prior to be returned to the cooling and liquefaction system 5.
• the number of trains and the fluid coupling between the various compressors and the cooling and liquefaction system 5, as well as among compressors of the same or of different compressor trains may depend upon the structure of the liquefaction cycle used, as well as upon the power required to process the refrigerants.
• the natural gas cooling and liquefaction system 5 can be configured in various different ways, depending upon the specific refrigeration cycle or combination of refrigeration cycles used.
• the cooling and refrigeration system can comprise one or more refrigerant cycles, using one or more refrigerant fluids, of the same or different nature, for instance refrigerants having different molecular weights and/or operating at different levels of pressure and temperature.
• the above described compressor train configurations can be used in any possible natural gas liquefaction system 5.
• One or more compressor trains can be used for one system 5, as schematically shown by exemplary embodiments of Figs. 31, 32, 33 and 34.
• Figs. 35 36, 37, 38, 39, 40 and 41 schematically show some exemplary embodiments of LNG systems which can be used as cooling and liquefaction systems 5 in combination with one or more compressor trains disclosed herein.
• the LNG systems of Figs. 35 36, 37, 38, 39, 40 and 41 are known to those skilled in the art and will therefore not be described in detail.
• one or more blocks schematically represent one or more compressor trains. These blocks are labeled with reference number 1. It shall be understood that each block 1 can in actual fact include more than one compressor train.
• Each compressor train can be configured according to one of the above described configurations.
• Fig. 35 illustrates a Single Mixed Refrigerant cycle, marketed under the trademark PRICO®, wherein a single mixed refrigerant is used to liquefy the natural gas.
• One or more compressor trains 1 can be provided to process the single mixed refrigerant flow.
• the liquefaction system 5 - lUo - comprises a cold box 302, where to natural gas is del ivered through a duct 301.
• Liquefied natural gas (LNG) exits the cold box 303 through a duct 303.
• LNG Liquefied natural gas
• heat is removed from the natural gas flow by heat exchange against a flow of refrigerant gas, such as a mixed refrigerant containing a mixture of two or more refrigerant fluids, for instance selected from methane, propane, ethylene, nitrogen.
• refrigerant gas such as a mixed refrigerant containing a mixture of two or more refrigerant fluids, for instance selected from methane, propane, ethylene, nitrogen.
• a compressor train 1 including a refrigerant gas compressor section with two refrigerant gas compressors 13 A, 13 B and a driver section 1 1.
• Refrigerant gas is compressed sequentially by compressors 13 A and 13B, an intercooler 304 being arranged betw een the two compressors 13 A, 13B.
• the intercooler removes heat from the partly compressed refrigerant gas e.g. by heat exchange against water or air.
• the refrigerant circuit further comprises a heat exchanger 305 downstream of the second compressor 13B, to remove heat from the compressed refrigerant, e.g. by heat exchange against air or water.
• Compressed refrigerant from the heat exchanger 305 flows through the cold box 302 to be pre- cooled and is then expanded in an expander 306.
• the expansion causes a temperature drop in the refrigerant.
• Expanded refrigerant flows through the cold box 302 to chill and liquefy the natural gas and pre-cool the refrigerant itself.
• the refrigerant ci cuit can further comprising a suction drum 308, where through the expanded refrigerant is returned to the compressor train 1.
• Additional components, such as gas/liquid separators 3 1 1 , 3 1 2 can be arranged in various positions along the gas circuit, as known to those skilled in the art.
• a gas/liquid separator can also be arranged on the LNG exit side of the liquefaction system 5, l iquefied natural gas being deliv ered from the liquid/gas separator 315 through a duct 3 1 7.
• Fig.36 il lustrates an LNG single mi ed refrigerant cycle, marketed by Linde under the trademark LIMUM®.
• the LNG liquefaction system 5 comprises a natural gas deliver duct 401 . a cold-bo 402 and an LNG deliv ery duct 403. Tw o streams of a refrigerant flow at different pressures are delivered from a compressor train 1 to the liquefaction system 5 through ducts 405 and 406.
• Expansion valves or expanders 407, 408, 409 expand the refrigerant flow to prov ide low -pressure and chil led gaseous refrigerant to the cold box 402. to remov e heat from the natural gas and liquefy the natural gas.
• Expanded and exhausted refrigerant gas is returned through a duct 41 1 to the compressor train 1 .
• the refrigerant gas is compressed by low pressure compressor 13A and high pressure compressor 13B. Heat can be remov ed from the medium pressure mixed refrigerant (heat exchanger 413) and from the high-pressure mixed refrigerant (heat exchanger 414). Gas/liquid separators 415, 416 and 417 are further provided in the mixed refrigerant circuit.
• Fig.37 illustrates a triple cycle mixed refrigerant cascade system, marketed by Linde under the trademark MFC® (Mixed Fluid Cascade), which uses three mixed refrigerant circuits 501, 502, 503. Each cycle comprises a cold box 504, 505, 506, respectively. The combination of three refrigerant cycles is labeled globally as a liquefaction system 5.
• a single block 1 represent the compressor train(s).
• the various compressors used to process the mixed refrigerant flow in the three circuits 501, 502, 503 can be variously arranged.
• a first refrigerant gas compressor 13 A is included in the first refrigerant circuit 501 to process a first refrigerant.
• a second refrigerant gas compressor 13B and a third refrigerant gas compressor 13C are arranged in the second refrigerant circuit 502.
• a fourth compressor 13D and fifth compressor 13E are arranged in the third refrigerant circuit 503.
• the first refrigerant circuit 501 comprises a first expander or expansion valve 507 and a first heat exchanger 508 downstream of the first compressor 13 A
• the second refrigerant circuit 502 comprises a second expander or expansion valve 509 and a second heat exchanger 510 downstream of the third compressor 13C
• the third refrigerant circuit 503 comprises a third expander or expansion valve 511 and a third heat exchanger 512 downstream of the fifth compressor 13E.
• An intercooier 513 can be provided between the fourth compressor 13D and the fifth compressor 13E.
• Natural gas NG to be chilled and liquefied is delivered through the three cold boxes 504, 505 and 506 sequentially and exits the most downstream cold box 506 at 514.
• the refrigerant gas compressors of the three circuits are operated by three driver sections 11 A, 11B, 11C, respectively.
• Each driver section can be configured with any one of the above described drivers.
• Those skilled in the art will however understand that a different arrangement of refrigerant gas compressors and driver sections can be envisaged.
• compressors of two or three circuits 501, 502, 503 can be arranged on the same shaft line of the same gas compressor train, driven by a common driver, e.g. an electric motor or a gas turbine.
• refrigerant gas compressors 13 A, 13B, 13C can be arranged to form a first gas compressor train and the compressors 13D, 13E can be arranged to form another gas compressor train, or two compressor trains.
• refrigerant gas compressors 13 A, i 3D, 13E can be arranged to form a first compressor train with a driver section, and compressors 13B, 13C can be arranged to form another compressor train.
• Fig. 38 illustrates an optimized LNG cycle using a plurality of refrigerant fluids, marketed by Conoco Phillips under the trademark CASCADE®.
• the liquefaction system again labeled 5 as a whole, may include three refrigerant gas cycles 601 , 602, 603. Different refrigerant gases are processed in the three cycles, namely methane, ethylene and propane, respectively. Natural gas NG is delivered sequentially through cold boxes 604, 605 and 606 until liquefied natural gas LNG is obtained.
• the first refrigerant gas cycle 601 comprises a first refrigerant gas compressor or compressor section 13 A, a first heat exchanger 610 and a first expander or a first expansion valve 61 1.
• Methane can be compressed by the first refrigerant gas compressor 13 A, cooled in first heat exchanger 610 and expanded by flowing through the first expansion valve or expander 61 1. Expansion causes the first refrigerant gas to chill and the chilled, low-pressure refrigerant gas is used to cool the natural gas and to pre-cool the second refrigerant gas circulating in the second refrigerant gas cycle 602, e.g. ethylene.
• the second refrigerant gas is compressed by the second refrigerant gas compressor 13B or compressor section 13B and is cooled in a second heat exchanger 612, arranged in the second refrigerant gas cycle 602. Compressed and cooled second refrigerant gas is further pre-cooled in the first cold box 604 by heat exchange against the first refrigerant gas and is then expanded in a second expander or a second expansion valve 613. The low-pressure, chilled second refrigerant gas is then used to further cool the natural gas and pre-cool the third refrigerant gas in the second cold box 605 and is finally returned to the second refrigerant gas compressor or compressor section 13B.
• the third refrigerant gas is compressed in the third refrigerant gas compressor or compressor section 13C and is cooled in a third heat exchanger 614.
• the compressed and cooled third refrigerant gas is then further pre-cooled in the first cold box 604 by heat exchange against the expanded first refrigerant gas and in the second cold box 605 by heat exchange against the expanded second refrigerant gas.
• a third expander or a third expansion valve 615 expands the third refrigerant gas to lower the temperature thereof.
• the low-pressure, chilled third refrigerant gas is then caused to remove further heat from the natural gas and liquefy the natural gas in the third cold box 606. Exhausted third refrigerant gas is then returned to the third compressor or compressor section 13C.
• reference number 1 designates the entire arrangement of compressor train(s).
• a respective driver section 11A, 11B, 11C is shown for each refrigerant gas cycle. It shall however be understood that other embodiments are possible.
• a single compressor train with a single driver section can be provided, including all the compressors of all three cycles.
• two or just one compressor or compressor section can be arranged in one compressor train with a respective driver section.
• one, two or all three cycles may include more than one compressor or compressor phase.
• a low-pressure, medium-pressure and high-pressure compressor or compressor set can be envisaged for the first and/or the second and/or the third cycle.
• Fig. 39 illustrates a schematic of a Shell Double Mixed Refrigerant (DMR) system.
• the liquefaction system is again labeled 5 as a whole.
• the system comprises a first refrigerant gas cycle 701 and a second refrigerant cycle 702.
• Different mixed refrigerants can be used in the two cycles. Natural gas flow through a first cold box 703 and a second cold box 704 and is chilled and finally liquefied by heat exchange against the refrigerant gas flow circulating in the two cycles 701 and 702.
• the first refrigerant gas is compressed in a first compressor or in a first compressor section 13A of the first refrigerant cycle 701 and cooled by heat exchange against water or air, for instance, in a first heat exchanger 705 prior to be pre-cooled in the first cold box 703 and expanded in a first expansion valve or a first expander 706.
• Low-pressure, low temperature first refrigerant gas is then used to remove heat from the natural gas flow in the first cold box 703. Exhausted first refrigerant gas is returned to the first compressor or compressor section 13 A.
• the second refrigerant gas is compressed in a second compressor or in a second compressor section 13B of the second refrigerant cycle 702 and cooled by heat exchange against water or air, for instance, in a second heat exchanger 707prior to be pre-cooled in the second cold box 704 and expanded in a second expansion valve or a second expander 708.
• Low-pressure, low temperature second refrigerant gas is then used to further remove heat from the natural gas flow and liquefy the natural gas in the second cold box 704. Exhausted second refrigerant gas is returned to the second compressor or compressor section 13B.
• the two compressors 13 A, 13B are illustrated as separate compressors, driven by respective driver sections 1 lA, 1 IB. It shall, however be understood that other arrangement are possible, e.g. a single compressor train with one driver section can be provided, wherein both compressor sections 13 A, 13B are arranged. Two or more compressor trains in parallel can be used in case of larger refrigerant gas flow-rates. In some embodiments two or more parallel compressors can be provided in the first cycle and a different number of compressors, e.g. just one compressor, can be prov ided in the second cycle, or vice- versa.
• Fig. 40 illustrates an APCI® propane mixed refrigerant I NG system.
• a first refrigerant gas cycle 801 contains a first refrigerant gas, e.g. propane, which is used to pre-cool natural gas NG and to further pre-cool a second refrigerant gas, e.g. a mixed refrigerant gas. which is processed in a second refrigerant gas cycle 802.
• a first refrigerant gas e.g. propane
• a second refrigerant gas e.g. a mixed refrigerant gas.
• two separate compressor trains 1A, IB are shown, including a respective first compressor first compressor section 13 A and a respective second compressor or second compressor section 13B.
• Each compressor section may include one or more compressors or compressor phases.
• FIG. 40 illustrates an APCI® propane mixed refrigerant I NG system.
• a first refrigerant gas cycle 801 contains a first refrigerant gas, e.g. propane, which is
• each compressor train 1 A, 1 B has a respective driver section 1 1 A, 1 1 B, coupled to the compressor or compressor section 13 A, 13B.
• a single compressor train may include both the first and the second compressor section 13 A, 13B, both driven by the same driver section.
• two compressor trains in parallel can be used, each including a respective compressor section of the first and second refrigerant gas cycle 801 , 802.
• two compressor trains can be provided, one including compressors) processing the first or the second refrigerant gas and the other containing separate compressors for processing both the first and the second - - refrigerant gas.
• reference 803 represents pre-cool ing heat exchangers, wherein side flows of the first refrigerant gas at different pressure levels, processed by the first compressor or compressor section 13 A, are uses to pre-cool the natural gas and to further pre-cool the second refrigerant gas.
• Pre-cooled, second refrigerant gas, processed by the second compressor or compressor section 13B is delivered to a main cryogenic heat exchanger 804, and expanded in expanders or expansion valves 805, 806.
• the expanded, low-temperature and low-pressure second refrigerant gas chills and liquefies the natural gas in the main cryogenic heat exchanger 804, to produce liquefied natural gas LNG.
• Reference number 807 and 808 designate heat exchangers arranged at the delivery side of the first compressor 13 A and of the second compressor 13B, to remove heat from the compressed first and second refrigerant gas by heat exchange, e.g. against water or air.
• Fig 4 1 illustrates a dual-refrigerant LNG cycle, marketed under the trademark AP-X®.
• the LNG system is again labeled 5 as a whole.
• a first refrigerant gas cycle 901 contains a first refrigerant gas, e.g. propane, which is used to pre-cool natural gas NG and to further pre-cool a second refrigerant gas, e.g. a mixed refrigerant gas, which is processed in a second refrigerant gas cycle 902.
• a first refrigerant gas e.g. propane
• a second refrigerant gas e.g. a mixed refrigerant gas
• two separate compressor trains 1A, 1 B are shown, including a respective first compressor first compressor section 13A and a respective second compressor or second compressor section 13B.
• Each compressor section may include one or more compressors or compressor phases.
• each compressor train 1A, 1 B has a respective driver section 1 1A, 1 1B, coupled to the compressor or compressor section 13 A, 13B. It shall, however, be understood that different arrangements are possible. For instance a single compressor train may include both the first and the second compressor section 1 A, 13B, both driven by the same driver section. In other embodiments, two compressor trains in parallel can be used, each including a respective compressor section of the first and second refrigerant gas cycle 901 . 902. In yet further embodiments, two compressor trains can be provided, one including compressor(s) processing the first or the second refrigerant gas and the other containing separate compressors for processing both the first and the second refrigerant gas. In the schematic of Fig.
• reference 903 represents pre-cool ing heat exchangers, wherein side flows of the first refrigerant gas at different pressure levels, processed by the first compressor or compressor section 13 A, are uses to pre-cool the natural gas and to further pre-cool the second refrigerant gas.
• Pre-cooled, second refrigerant gas, processed by the second compressor or compressor section 13B is delivered to a main cryogenic heat exchanger 904, and expanded in an expander or an expansion valve 905.
• the expanded, low-temperature and low-pressure second refrigerant gas chilis and possibly liquefies the natural gas in the main cryogenic heat exchanger 904.
• Reference number 907 and 908 designate heat exchangers arranged at the delivery side of the first compressor 13A and of the second compressor 13B, to remove heat from the compressed first and second refrigerant gas by heat exchange, e.g. against water or air.
• Liquefied natural gas from the main cryogenic heat exchanger 904 can be sub- cooled in a sub-cooler 912, where a third refrigerant gas circulates.
• the third refrigerant gas e.g. nitrogen
• the third refrigerant gas can be processed by the third compressor section or compressor 13C, cooled in a heat exchanger 911 against water or air, for instance and expanded in an expander 913 or an expansion valve.
• An economizer 914 can be further comprised in the third refrigerant gas cycle 910.
• the compressors or compressor sections 13 A, 13B, 13C and the relevant driver sections 1 1 A, 1 1 B. 1 1 C can be variously combined with one another, by providing e.g. more compressors on one and the same train, even for processing different refrigerant gases, and/or more compressors in parallel for processing the same refrigerant gas may be arranged in different trains, if suitable e.g. in view of the requested flow rates.
• Refrigerants which can be used in the cool ing and liquefaction systems 5 may include: methane, propane, ethylene, nitrogen or mixtures thereof (mixed refrigerants).
• compressors can be differently arranged and combined on one or more compressor trains, depending upon needs, in particular depending upon the number of refrigerant gas circuits, the requested flow rate in each circuit, the rotational speed of each refrigerant gas compressor, the number of compressors in each cycle, wh ich i n turn can depend upon how the compression ratios are distributed among one or more compressors or compressor sections, wherein each compressor or compressor section can in turn include one or more compressor stages, as above described in more detail.
• power rates ranging between approximately 30 and 40 MW are required for each mega tons per year (MTPA) of l iquefied natural gas produced by the system 5.
• MTPA mega tons per year
• the compressor train can be configured for on-shore or off-shore installations.
• one or more machines of the compressor train preferably all machines of the compressor train, including some or ail auxil iaries, can be arranged on a transportable module.
• a waste heat recovery exchanger can be configured and arranged to remove heat from combustion gas at the exhaust stack of a gas turbine engine or of a reciprocating internal combustion engine used as a main driver in a compressor train according to the above described arrangements.
• Recovered waste heat can be used in a bottom thermodynamic cycle, for instance a steam Rankine cycle or an ORC (Organic Rankine Cycle), wherein a steam or vapor turbine or expander converts part of the - - low-temperature heat into further mechanical power for driving the shaft line of the same compressor train where the gas turbine engine or reciprocating engine is arranged, or else to drive a separate additional compressor train.
• a steam Rankine cycle or an ORC (Organic Rankine Cycle)
• ORC Organic Rankine Cycle
• the driver section can comprise a combustion engine producing waste heat which can be exploited in a bottom thermodynamic cycle through a waste heat recovery heat exchanger which is in heat exchange relationship with a closed circuit, wherein a heat-carrying fluid circulates to remove heat from the combustion gas.
• the waste heat recovery heat exchanger can be in heat exchange relationship with a thermodynamic cycle; wherein a mechanical work producing machine is arranged in the thermodynamic cycle, and wherein the thermodynamic cycle is configured to convert thermal power from the waste heat recovery heat exchanger into mechanical power.
• the mechanical work producing machine can be drivingly coupled to either the compressor train or to a separate rotating load, preferably an electric generator, to convert mechanical power generated by the mechanical work producing machine into electrical power.
• FIG. 43, 44 and 45 Exemplary embodiments of compressor trains using combined top cycle and bottom cycle are shown in Figs. 43, 44 and 45.
• a compressor train 1 comprises a driver section 1 1 which may comprise a gas turbine engine or another internal combustion engine, a refrigerant gas compressor section 13 and an auxiliary machine 17.
• the compressor train 1 can be configured according to any one of the above disclosed arrangements.
• a waste heat recovery exchanger (WHR exchanger) 1 00 is arranged at the discharge of the gas turbine engine 1 1 .
• the combust ion gas of the gas turbine engine 1 1 flows through the hot side of the WH R exchanger 100.
• a working fluid of a closed bottom thermodynamic cycle 101 flows through the cold side of the WHR exchanger 100.
• the bottom thermodynamic cycle 101 comprises a steam or vapor turbine or an expander 102, a condenser 104 and a pump 106.
• High-pressure working fluid is heated and vaporized in the WHR exchanger 1 00 by exchanging heat against the combustion gas.
• Hot pressurized working fluid is expanded in turbine 102.
• the enthalpy drop in turbine 1 02 generates mechanical power.
• the turbine 1 02 is arranged along the shaft l ine 2 such that mechanical power generated therewith is used to drive the gas compressor section 13 in combination with the power - - generated by the gas turbine engine 1 1 .
• a compressor train 1 . 1 comprises a driver section 1 1 which may comprise a gas turbine engine or another internal combustion engine, a gas compressor section 13.1 and an auxiliary machine 17.1.
• the compressor train 1 can be configured according to any one of the above disclosed arrangements.
• a waste heat recover exchanger (WHR exchanger) 100 is arranged at the discharge of the gas turbine engine 1 1.
• the combustion gas of the gas turbine engine 1 1 flows through the hot side of the WH R exchanger 100.
• a working fluid of a closed bottom thermodynamic cycle 101 flows through the cold side of the WHR exchanger 1 00.
• the bottom thermodynamic cycle 1 01 comprises a steam or vapor turbine or an expander 102, a condenser 1 04 and a pump 106.
• High-pressure working fluid is heated and vaporized in the WHR exchanger 1 00 by exchanging heat again t the combustion gas.
• Hot pressurized working fluid is expanded in turbine 102.
• the enthalpy drop in turbine 102 generates mechanical power.
• the turbine 102 forms part of a second compressor train 1 .2, which further comprises a gas compressor section 13.2 and can comprise an auxiliary machine 1 7.2.
• the mechanical power generated by the enthalpy drop across turbine 102 is thus used to drive a separate compressor train 1 .2, different from compressor train 1. 1 where the gas turbine engine of the top thermodynamic cycle is arranged. While in Figs.
• thermodynamic cycle com rising the gas turbine engine 1 1 is coupled to a bottom thermodynamic cycle 1 01 .
• the turbine 102 of the bottom thermodynamic cycle 1 0 1 converts the enthalpy drop of the low-temperature working fluid of the bottom thermodynamic cycle into mechanical power that is used to drive an electric generator 108 to convert the mechanical power into electric power, which can be used to power any generic electric load or which can be delivered to an electrical power distribution grid G.
• heat recovered at the WHR exchanger 100 can be used as such, for instance for heating a fluid in another process, for air conditioning or for any other purpose.
• the WHR exchanger 100 can be used to produce steam or vapor, or to heat a stream of a heat transfer fluid in a gaseous, vapor, liquid or combined liquid-vapor state, to be used to purify the Natural Gas upstream from the LNG plant or to supply heat to other processing units such as those installed to purify and distillate crude oil, LPGs, and other by-products.

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• Engineering & Computer Science (AREA)
• Mechanical Engineering (AREA)
• General Engineering & Computer Science (AREA)
• Physics & Mathematics (AREA)
• Thermal Sciences (AREA)
• Chemical & Material Sciences (AREA)
• Chemical Kinetics & Catalysis (AREA)
• General Chemical & Material Sciences (AREA)
• Oil, Petroleum & Natural Gas (AREA)
• Structures Of Non-Positive Displacement Pumps (AREA)

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• 2017
  • 2017-05-09 US US16/611,552 patent/US20210080172A1/en not_active Abandoned
  • 2017-05-10 WO PCT/EP2017/061211 patent/WO2018206102A1/en unknown
  • 2017-05-10 CN CN201780092757.XA patent/CN110809702A/zh active Pending
  • 2017-05-10 EP EP17723071.1A patent/EP3622233A1/de not_active Withdrawn

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