WO2002037590A1 - Separation gazeuse ecoenergetique destinee a des piles a combustible - Google Patents

Separation gazeuse ecoenergetique destinee a des piles a combustible Download PDF

Info

Publication number
WO2002037590A1
WO2002037590A1 PCT/CA2001/001522 CA0101522W WO0237590A1 WO 2002037590 A1 WO2002037590 A1 WO 2002037590A1 CA 0101522 W CA0101522 W CA 0101522W WO 0237590 A1 WO0237590 A1 WO 0237590A1
Authority
WO
WIPO (PCT)
Prior art keywords
fuel cell
gas
gas stream
fuel
oxygen
Prior art date
Application number
PCT/CA2001/001522
Other languages
English (en)
Inventor
Bowie G. Keefer
Denis J. Connor
Carl F. Hunter
Original Assignee
Questair Technologies Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from CA002325072A external-priority patent/CA2325072A1/fr
Application filed by Questair Technologies Inc. filed Critical Questair Technologies Inc.
Priority to JP2002540232A priority Critical patent/JP2004512665A/ja
Priority to BR0107399-0A priority patent/BR0107399A/pt
Priority to CA002394924A priority patent/CA2394924A1/fr
Priority to EP01982015A priority patent/EP1334529A1/fr
Priority to AU13716/02A priority patent/AU780651B2/en
Publication of WO2002037590A1 publication Critical patent/WO2002037590A1/fr

Links

Classifications

    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01M—PROCESSES OR MEANS, e.g. BATTERIES, FOR THE DIRECT CONVERSION OF CHEMICAL ENERGY INTO ELECTRICAL ENERGY
    • H01M8/00—Fuel cells; Manufacture thereof
    • H01M8/04—Auxiliary arrangements, e.g. for control of pressure or for circulation of fluids
    • H01M8/04007—Auxiliary arrangements, e.g. for control of pressure or for circulation of fluids related to heat exchange
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/02—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by adsorption, e.g. preparative gas chromatography
    • B01D53/04—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by adsorption, e.g. preparative gas chromatography with stationary adsorbents
    • B01D53/047—Pressure swing adsorption
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B13/00—Oxygen; Ozone; Oxides or hydroxides in general
    • C01B13/02—Preparation of oxygen
    • C01B13/0229—Purification or separation processes
    • C01B13/0248—Physical processing only
    • C01B13/0259—Physical processing only by adsorption on solids
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B3/00—Hydrogen; Gaseous mixtures containing hydrogen; Separation of hydrogen from mixtures containing it; Purification of hydrogen
    • C01B3/50—Separation of hydrogen or hydrogen containing gases from gaseous mixtures, e.g. purification
    • C01B3/56—Separation of hydrogen or hydrogen containing gases from gaseous mixtures, e.g. purification by contacting with solids; Regeneration of used solids
    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01M—PROCESSES OR MEANS, e.g. BATTERIES, FOR THE DIRECT CONVERSION OF CHEMICAL ENERGY INTO ELECTRICAL ENERGY
    • H01M8/00—Fuel cells; Manufacture thereof
    • H01M8/04—Auxiliary arrangements, e.g. for control of pressure or for circulation of fluids
    • H01M8/04082—Arrangements for control of reactant parameters, e.g. pressure or concentration
    • H01M8/04089—Arrangements for control of reactant parameters, e.g. pressure or concentration of gaseous reactants
    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01M—PROCESSES OR MEANS, e.g. BATTERIES, FOR THE DIRECT CONVERSION OF CHEMICAL ENERGY INTO ELECTRICAL ENERGY
    • H01M8/00—Fuel cells; Manufacture thereof
    • H01M8/06—Combination of fuel cells with means for production of reactants or for treatment of residues
    • H01M8/0606—Combination of fuel cells with means for production of reactants or for treatment of residues with means for production of gaseous reactants
    • H01M8/0612—Combination of fuel cells with means for production of reactants or for treatment of residues with means for production of gaseous reactants from carbon-containing material
    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01M—PROCESSES OR MEANS, e.g. BATTERIES, FOR THE DIRECT CONVERSION OF CHEMICAL ENERGY INTO ELECTRICAL ENERGY
    • H01M8/00—Fuel cells; Manufacture thereof
    • H01M8/06—Combination of fuel cells with means for production of reactants or for treatment of residues
    • H01M8/0662—Treatment of gaseous reactants or gaseous residues, e.g. cleaning
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2253/00—Adsorbents used in seperation treatment of gases and vapours
    • B01D2253/10—Inorganic adsorbents
    • B01D2253/104—Alumina
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2253/00—Adsorbents used in seperation treatment of gases and vapours
    • B01D2253/10—Inorganic adsorbents
    • B01D2253/106—Silica or silicates
    • B01D2253/108—Zeolites
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2253/00—Adsorbents used in seperation treatment of gases and vapours
    • B01D2253/25—Coated, impregnated or composite adsorbents
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2256/00—Main component in the product gas stream after treatment
    • B01D2256/12—Oxygen
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2256/00—Main component in the product gas stream after treatment
    • B01D2256/16—Hydrogen
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2256/00—Main component in the product gas stream after treatment
    • B01D2256/22—Carbon dioxide
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/10—Single element gases other than halogens
    • B01D2257/102—Nitrogen
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/50—Carbon oxides
    • B01D2257/502—Carbon monoxide
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/50—Carbon oxides
    • B01D2257/504—Carbon dioxide
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/70—Organic compounds not provided for in groups B01D2257/00 - B01D2257/602
    • B01D2257/702—Hydrocarbons
    • B01D2257/7022—Aliphatic hydrocarbons
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/80—Water
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2258/00—Sources of waste gases
    • B01D2258/02—Other waste gases
    • B01D2258/0208—Other waste gases from fuel cells
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2258/00—Sources of waste gases
    • B01D2258/06—Polluted air
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2259/00—Type of treatment
    • B01D2259/40—Further details for adsorption processes and devices
    • B01D2259/40003—Methods relating to valve switching
    • B01D2259/40005—Methods relating to valve switching using rotary valves
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2259/00—Type of treatment
    • B01D2259/40—Further details for adsorption processes and devices
    • B01D2259/414—Further details for adsorption processes and devices using different types of adsorbents
    • B01D2259/4141—Further details for adsorption processes and devices using different types of adsorbents within a single bed
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/02—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by adsorption, e.g. preparative gas chromatography
    • B01D53/04—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by adsorption, e.g. preparative gas chromatography with stationary adsorbents
    • B01D53/047—Pressure swing adsorption
    • B01D53/0476—Vacuum pressure swing adsorption
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/02—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by adsorption, e.g. preparative gas chromatography
    • B01D53/06—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by adsorption, e.g. preparative gas chromatography with moving adsorbents, e.g. rotating beds
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/26—Drying gases or vapours
    • B01D53/261—Drying gases or vapours by adsorption
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/04—Integrated processes for the production of hydrogen or synthesis gas containing a purification step for the hydrogen or the synthesis gas
    • C01B2203/0465—Composition of the impurity
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/04—Integrated processes for the production of hydrogen or synthesis gas containing a purification step for the hydrogen or the synthesis gas
    • C01B2203/0465—Composition of the impurity
    • C01B2203/047—Composition of the impurity the impurity being carbon monoxide
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/04—Integrated processes for the production of hydrogen or synthesis gas containing a purification step for the hydrogen or the synthesis gas
    • C01B2203/0465—Composition of the impurity
    • C01B2203/0475—Composition of the impurity the impurity being carbon dioxide
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/04—Integrated processes for the production of hydrogen or synthesis gas containing a purification step for the hydrogen or the synthesis gas
    • C01B2203/0465—Composition of the impurity
    • C01B2203/048—Composition of the impurity the impurity being an organic compound
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/04—Integrated processes for the production of hydrogen or synthesis gas containing a purification step for the hydrogen or the synthesis gas
    • C01B2203/0465—Composition of the impurity
    • C01B2203/0495—Composition of the impurity the impurity being water
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/06—Integration with other chemical processes
    • C01B2203/066—Integration with other chemical processes with fuel cells
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2203/00—Integrated processes for the production of hydrogen or synthesis gas
    • C01B2203/80—Aspect of integrated processes for the production of hydrogen or synthesis gas not covered by groups C01B2203/02 - C01B2203/1695
    • C01B2203/86—Carbon dioxide sequestration
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2210/00—Purification or separation of specific gases
    • C01B2210/0043—Impurity removed
    • C01B2210/0046—Nitrogen
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2210/00—Purification or separation of specific gases
    • C01B2210/0043—Impurity removed
    • C01B2210/0062—Water
    • C—CHEMISTRY; METALLURGY
    • C01—INORGANIC CHEMISTRY
    • C01B—NON-METALLIC ELEMENTS; COMPOUNDS THEREOF; METALLOIDS OR COMPOUNDS THEREOF NOT COVERED BY SUBCLASS C01C
    • C01B2210/00—Purification or separation of specific gases
    • C01B2210/0043—Impurity removed
    • C01B2210/0078—Noble gases
    • C01B2210/0082—Argon
    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01M—PROCESSES OR MEANS, e.g. BATTERIES, FOR THE DIRECT CONVERSION OF CHEMICAL ENERGY INTO ELECTRICAL ENERGY
    • H01M8/00—Fuel cells; Manufacture thereof
    • H01M8/10—Fuel cells with solid electrolytes
    • H01M8/12—Fuel cells with solid electrolytes operating at high temperature, e.g. with stabilised ZrO2 electrolyte
    • H01M2008/1293—Fuel cells with solid oxide electrolytes
    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01M—PROCESSES OR MEANS, e.g. BATTERIES, FOR THE DIRECT CONVERSION OF CHEMICAL ENERGY INTO ELECTRICAL ENERGY
    • H01M8/00—Fuel cells; Manufacture thereof
    • H01M8/14—Fuel cells with fused electrolytes
    • H01M2008/147—Fuel cells with molten carbonates
    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01M—PROCESSES OR MEANS, e.g. BATTERIES, FOR THE DIRECT CONVERSION OF CHEMICAL ENERGY INTO ELECTRICAL ENERGY
    • H01M8/00—Fuel cells; Manufacture thereof
    • H01M8/04—Auxiliary arrangements, e.g. for control of pressure or for circulation of fluids
    • H01M8/04007—Auxiliary arrangements, e.g. for control of pressure or for circulation of fluids related to heat exchange
    • H01M8/04014—Heat exchange using gaseous fluids; Heat exchange by combustion of reactants
    • H01M8/04022—Heating by combustion
    • H—ELECTRICITY
    • H01—ELECTRIC ELEMENTS
    • H01M—PROCESSES OR MEANS, e.g. BATTERIES, FOR THE DIRECT CONVERSION OF CHEMICAL ENERGY INTO ELECTRICAL ENERGY
    • H01M8/00—Fuel cells; Manufacture thereof
    • H01M8/04—Auxiliary arrangements, e.g. for control of pressure or for circulation of fluids
    • H01M8/04082—Arrangements for control of reactant parameters, e.g. pressure or concentration
    • H01M8/04089—Arrangements for control of reactant parameters, e.g. pressure or concentration of gaseous reactants
    • H01M8/04119—Arrangements for control of reactant parameters, e.g. pressure or concentration of gaseous reactants with simultaneous supply or evacuation of electrolyte; Humidifying or dehumidifying
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
    • Y02C20/00—Capture or disposal of greenhouse gases
    • Y02C20/40—Capture or disposal of greenhouse gases of CO2
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y02E60/30—Hydrogen technology
    • Y02E60/50—Fuel cells
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P20/00—Technologies relating to chemical industry
    • Y02P20/10—Process efficiency
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P20/00—Technologies relating to chemical industry
    • Y02P20/10—Process efficiency
    • Y02P20/129—Energy recovery, e.g. by cogeneration, H2recovery or pressure recovery turbines
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P20/00—Technologies relating to chemical industry
    • Y02P20/151—Reduction of greenhouse gas [GHG] emissions, e.g. CO2
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P20/00—Technologies relating to chemical industry
    • Y02P20/50—Improvements relating to the production of bulk chemicals
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P30/00—Technologies relating to oil refining and petrochemical industry

Definitions

  • the present disclosure relates to a fuel cell-based electrical generation system, which employs pressure swing adsorption for enhancing the energy efficiency of fuel cells, particularly high temperature fuel cells such as molten carbonate and solid oxide fuel cells.
  • Fuel cells provide an environmentally friendly source of electrical current.
  • One type of high temperature fuel cell used for generating electrical power is the molten carbonate fuel cell (MCFC).
  • the MCFC includes an anode channel for receiving a flow of hydrogen gas (or a fuel gas which reacts in the anode channel to generate hydrogen by steam reforming and water gas shift reactions), a cathode channel for receiving a flow of oxygen gas, and a porous matrix containing a molten carbonate electrolyte which separates the anode channel from the cathode channel.
  • Oxygen and carbon dioxide in the cathode channel react to form carbonate ions, which cross the electrolyte to react with hydrogen in the anode channel to generate a flow of electrons. As the hydrogen is consumed, carbon monoxide is shifted by steam to generate additional hydrogen. Carbon dioxide and water vapor are produced in the anode channel by oxidation of fuel components, and by reduction of carbonate ions from the electrolyte.
  • Typical operating temperature of molten carbonate fuel cells is about 600° to about 650°C.
  • the SOFC includes an anode channel for receiving a flow of hydrogen gas (or a fuel gas which reacts in the anode channel to generate hydrogen by steam reforming and water gas shift reactions), a cathode channel for receiving a flow of oxygen gas, and a solid electrolyte which is a ceramic membrane conductive to oxygen ions and separates the anode channel from the cathode channel.
  • Oxygen in the cathode channel dissociates to oxygen ions, which cross the electrolyte to react with hydrogen in the anode channel to generate a flow of electrons.
  • carbon monoxide may be oxidized directly or may be shifted by steam to generate additional hydrogen.
  • Carbon dioxide and water vapor are produced in the anode channel by oxidation of fuel components.
  • Typical operating temperature of solid oxide fuel cells is about 500° to about 1000°C.
  • hydrogen e.g. recovered from refinery or chemical process off-gases, or else generated from renewable energy by electrolysis of water
  • hydrogen must be generated from fossil fuels by an appropriate fuel processing system.
  • steam reforming or partial oxidation to produce "syngas” comprising a mixture of hydrogen, carbon monoxide, carbon dioxide, steam and some unreacted methane.
  • Other carbonaceous feedstocks e.g. heavier hydrocarbons, coal, or biomass
  • the fuel cell may also be operated on hydrogen or syngas that has been generated externally.
  • MCFC and SOFC systems have high operating temperature facilitates close thermal integration between the fuel cell and the fuel processing system.
  • the high temperature also allows the elimination of noble metal catalysts required by lower temperature fuel cells.
  • Prior art MCFC systems have serious limitations associated with their high temperature operation, and with their inherent need to supply carbon dioxide to the cathode while removing it from the anode.
  • Prior art SOFC systems face even more challenging temperature regimes, and are disadvantaged by the degradation of cell voltages at very high temperatures under conventional operating conditions.
  • the lower heat of combustion of a fuel usefully defines the energy (enthalpy change of the reaction) that may be generated by oxidizing that fuel.
  • the electrochemical energy that can be generated by an ideal fuel cell is however the free energy change of the reaction, which is smaller than the enthalpy change.
  • the difference between the enthalpy change and the free energy change is the product of the entropy change of the reaction multiplied by the absolute temperature. This difference widens at higher temperatures, so higher temperature fuel cells inherently convert a lower fraction of the fuel energy to electrical power at high efficiency, while a larger fraction of the fuel energy is available only as heat which must be converted to electrical power by a thermodynamic bottoming cycle (e.g. steam or gas turbine plant) at lower efficiency.
  • a thermodynamic bottoming cycle e.g. steam or gas turbine plant
  • reaction products carbon dioxide and steam
  • higher partial pressure of oxygen and carbon dioxide over the cathode and higher partial pressure of hydrogen over the anode, drive the reaction forward so that the free energy is increased.
  • the reaction depletes the oxygen and carbon dioxide in the cathode channel and depletes hydrogen in the anode channel while rapidly increasing the backpressure of carbon dioxide in the anode channel.
  • the free energy change is reduced, directly reducing the cell voltage of the fuel stack. This degrades the electrical efficiency of the system, while increasing the heat that must be converted at already lower efficiency by the thermal bottoming cycle.
  • the free energy change is simply the product of the electromotive force ("E") of the cell and the charge transferred per mole by the reaction (“2F”), where the factor of two reflects the valency of the carbonate ion.
  • E electromotive force
  • 2F reaction
  • the factor of two reflects the valency of the carbonate ion.
  • the following Nernst relation for a MCFC expresses the above described sensitivity of the electromotive force to the partial pressures of the electrochemical reactants in the anode and cathode channels, where the standard electromotive force (“Eo”) is referred to all components at standard conditions and with water as vapor.
  • E E
  • the accepted method for supplying carbon dioxide to the MCFC cathode has been to burn a fraction of the anode exhaust gas (including unreacted hydrogen and other fuel components) to provide carbon dioxide mixed with steam and nitrogen to be mixed with additional air providing oxygen to the cathode.
  • This approach has serious limitations. Even more of the original fuel value is unavailable for relatively efficient electrochemical power generation, in view of additional combustion whose heat can only be absorbed usefully by the thermal bottoming cycle.
  • the oxygen/nitrogen ratio of the cathode gas is even more dilute than ambient air, further reducing cell voltage and hence transferring more power generation load less efficiently onto the thermal bottoming plant.
  • PSA Pressure swing adsorption
  • VPSA vacuum pressure swing adsorption systems
  • the less readily adsorbed component is concentrated adjacent the second end of the adsorber, while the more readily adsorbed component is concentrated adjacent the first end of the adsorber.
  • a "light" product a gas fraction depleted in the more readily adsorbed component and enriched in the less readily adsorbed component
  • a "heavy” product a gas fraction enriched in the more strongly adsorbed component
  • the conventional system for implementing pressure swing adsorption or vacuum pressure swing adsorption uses two or more stationary adsorbers in parallel, with multiple two-way directional valves at each end of each adsorber to connect the adsorbers in alternating sequence to pressure sources and sinks.
  • This system is often cumbersome and expensive to implement due to the large size of the adsorbers and the complexity of the valving required. The valves would not be capable of operation at MCFC working temperatures.
  • the conventional PSA system makes inefficient use of applied energy because of irreversible gas expansion steps as adsorbers are cyclically pressurized and depressurized within the PSA process.
  • Conventional PSA systems are bulky and heavy because of their low cycle frequency and consequent large adsorbent inventory.
  • prior art PSA technology may not be capable of operation at such high temperature.
  • adsorbents which can separate carbon dioxide in the presence of steam must be provided for any anode gas PSA separation working at elevated temperature.
  • Combined cycle power plants with a gas turbine cycle integrated with a fuel cell system have been disclosed.
  • commonly-assigned PCT Published International Patent Application No. WO 00/16425 provides examples of how PSA units may be integrated with gas turbine power plants, or with fuel cell power plants having a gas turbine auxiliary engine.
  • a further need addressed by the disclosed systems and processes is for mitigation of global warming driven by cumulative emissions of carbon dioxide from fossil-fuelled power generation.
  • the disclosed systems and processes also address the following environmental needs:
  • the disclosed MCFC or SOFC based electrical generation systems address the deficiencies of the prior art, in general to manipulate reactant concentrations for enhanced performance and economics, and in MCFC systems to transfer carbon dioxide from the anode to the cathode while enhancing electrical power output.
  • an electrical current generating system that includes at least one fuel cell operating at a temperature of at least about 250°C, a hydrogen gas separation system and/or oxygen gas delivery system that includes at least one device selected from a compressor or vacuum pump, and a drive system for the device that includes means for recovering energy from at least one of the hydrogen gas separation system, oxygen gas delivery system, or heat of the fuel cell.
  • a gas turbine system may be coupled to the hydrogen gas separation system or oxygen gas delivery system, wherein the gas turbine system is powered by energy recovered from at least one of the hydrogen gas separation system, oxygen gas delivery system, or heat of the fuel cell.
  • the hydrogen gas separation system or the oxygen gas delivery system may include a pressure swing adsorption module. These generating systems are particularly useful with molten carbonate fuel cells and solid oxide fuel cells.
  • the energy recovery means may include a gas turbine and/or a heat exchanger that receives a heated and/or pressurized gas stream from the hydrogen gas separation system, oxygen gas delivery system, or fuel cell.
  • a fuel cell heat recovery system may be coupled to the fuel cell and to the gas turbine system (in this case, a hydrogen gas separation system is optional).
  • the energy recovery means translates the recovered energy into a drive force for operating the compressor and vacuum pump.
  • a pressure swing adsorption module could establish a pressure gradient in a fuel-containing gas stream under conditions sufficient for separating the fuel-containing gas stream into a fuel-enriched gas stream and a fuel-depleted gas stream, and at least one of the fuel- enriched gas stream or fuel-depleted gas stream is recirculated to a gas turbine system coupled to a compressor and/or vacuum pump to capture the recirculation stream's energy.
  • a fuel cell heat recovery system that transfers heat from the fuel cell to a heat recovery working fluid that can undergo expansion to power the gas turbine system.
  • the gas turbine system coupled to the PSA may power all compressors and vacuum pumps for the 02 PSA, along with vacuum pump and/or heavy reflux compression for the H2 PSA.
  • This auxiliary gas turbine cycle allows a heavy reflux vacuum pump and compressor to be driven by the turboexpander which expands the products of hydrogen PSA tail gas combustion.
  • a feature of certain disclosed embodiments is integration of vacuum pump(s) and/or compressors with the gas turbine powered directly or indirectly by tail gas combustion or indirectly by heat exchange to fuel cell stack waste heat.
  • neither an electrical generator coupled to the thermal bottoming cycle nor an auxiliary power source is required to power all the compressors and vacuum pumps for the gas separation systems.
  • the gas turbine system may also be coupled to an auxiliary device such as an electrical current generator that could provide power to a vehicle air conditioning system.
  • Either single or multiple spool gas turbine configurations may be considered. Centrifugal or axial machines may be used as the compressors and pumps. Approaches based on integration of gas turbines and fuel cells are particularly favorable for larger power levels. Free spool gas generators (e.g. turbochargers) are used in some economically preferred embodiments.
  • the electrical current generating system comprises a MCFC or SOFC fuel cell, an oxygen gas delivery system, and/or a hydrogen gas delivery system.
  • the fuel cell can include an anode channel having an anode gas inlet for receiving a supply of hydrogen gas (or a fuel gas which reacts to form hydrogen in the anode channel), a cathode channel having a cathode gas inlet and a cathode gas outlet, and an electrolyte in communication with the anode and cathode channel for facilitating ion transport between the anode and cathode channel.
  • the hydrogen gas delivery system may include a hydrogen PSA system, including a rotary module having a stator and a rotor rotatable relative to the stator, for enriching hydrogen to the anode channel and extracting carbon dioxide therefrom.
  • the electrical current generating system also includes a PSA or VPSA system for enriching oxygen from air for supply to the cathode channel and/or to the fuel processing system.
  • the PSA unit for enriching hydrogen and separating carbon dioxide will be referred to as the first PSA unit, while a second PSA or VPSA unit maybe provided for oxygen enrichment.
  • the rotor of a PSA unit for use in the disclosed systems and processes includes a number of flow paths for receiving adsorbent material therein for preferentially adsorbing a first gas component in response to increasing pressure in the flow paths relative to a second gas component.
  • the pressure swing adsorption system also may include compression machinery coupled to the rotary module for facilitating gas flow through the flow paths for separating the first gas component from the second gas component.
  • the stator includes a first stator valve surface, a second stator valve surface, and plurality of function compartments opening into the stator valve surfaces.
  • the function compartments include a gas feed compartment, a light reflux exit compartment and a light reflux return compartment.
  • the hydrogen PSA system may itself operate at a working high temperature.
  • the operating temperature of the adsorbers in the first or hydrogen PSA unit may range from approximately ambient temperature to an elevated temperature up to about 450°C, as may be facilitated by recuperative or regenerative heat exchange between the first PSA unit and the fuel cell anode channel.
  • the operating temperature of the adsorbers may range from about the operating temperature of the MCFC stack (e.g., about 600 to about 650°C) or SOFC stack (e.g., about 500 to about 1000°C) down to about 450°C, as maybe facilitated by recuperative or regenerative heat exchange.
  • the operating temperature of the hydrogen PSA adsorbers may range from ambient to about 800°C, especially about 150°C to about 800°C for PSA units that contain catalysts and ambient to 200°C for PSA units that do not contain catalysts.
  • This PSA unit may be configured to support a temperature gradient along the length of the flow channels, so that the temperature at the second end of the adsorbers is higher than the temperature at the first end of the adsorbers.
  • "operating temperature of the adsorbers" denotes the temperature of a gas flowing through the adsorbers and/or the temperature of the adsorber beds.
  • an electrical current generating system that includes a MCFC or SOFC, and a H2 PSA coupled to the MCFC or SOFC, wherein the H2 PSA includes a first adsorbent and at least one second material selected from a second adsorbent and a steam reforming catalyst or water gas shift reaction catalyst.
  • the first adsorbent is chemically distinct from the second adsorbent.
  • the adsorbent in the adsorbers of the first or hydrogen PSA may include a first zone of adsorbent, which is selective at an elevated operating temperature (e.g., about 250°C to about 800°C) for carbon dioxide in preference to water vapor.
  • Suitable such adsorbents known in the art include alkali-promoted materials.
  • Illustrative alkali- promoted materials include those containing cations of alkali metals such as Li, Na, K, Cs, Rb, and/or alkaline earth metals such as Ca, St, and Ba.
  • the materials typically may be provided as the hydroxide, carbonate, bicarbonate, acetate, phosphate, nitrate or organic acid salt compound of the alkali or alkaline earth metals.
  • Such compounds may be deposited on any suitable substrate such as alumina. Examples of specific materials include alumina impregnated with potassium carbonate and hydrotalcite promoted with potassium carbonate.
  • suitable adsorbents include alumina gel, activated carbons, hydrophilic zeolites (e.g. type 13X zeolite and many other zeolites known in the art), and hydrophobic zeolites (e.g. type Y zeolite or silicalite).
  • the adsorbent in the same or another zone of the adsorbers may include a component catalytically active at the operating temperature of that zone for the steam reforming reaction (e.g. methane fuel or methanol fuel) and/or for the water gas shift reaction.
  • the catalytically active component may be a reduced transition group metal or mixture of metals, or may be a transition group metal dispersed in zeolite cages and reversibly forming a metal carbonyl complex at the operating temperature of the second zone.
  • Industrial H2 PSA is normally conducted at considerably elevated pressures (> 10 bars) to achieve simultaneous high purity and high recovery ( ⁇ 80%-85%).
  • Fuel cell systems operating with pressurized methanol reformers or in integration with gas turbine cycles may operate at relatively high pressures.
  • Molten carbonate fuel cells operate at pressures from atmospheric up to about at most 10 bars, with lower pressures strongly preferred at present as required to achieve extended stack life.
  • Solid oxide fuel cells may be designed to operate at any pressure, with working pressures of about 5- 20 bars being preferred in the present invention.
  • the pressure of the light product gas exiting from the hydrogen PSA and oxygen PSA may vary widely in the disclosed systems and processes. Compressors or other pressure-increasing mechanisms may be employed to boost the light product gas pressure if necessary prior to introduction into the fuel cell. At very low feed pressures (e.g., 2-3 bars), the first PSA may utilize supplemental compression to achieve higher recovery of hydrogen and simultaneously higher concentration of carbon dioxide. Alternative approaches include vacuum pumping to widen the working pressure ratio, or alternatively "heavy reflux" which is recompression and recycle to the PSA feed of a fraction of its exhaust stream at full pressure. Vacuum and heavy reflux options may be combined by using an oversized vacuum pump.
  • the disclosed systems and processes can improve overall efficiency of fuel cell systems to reduce the proportionate amount of carbon dioxide formed, while enabling delivery as and when desired of that carbon dioxide in highly concentrated form for most convenient sequestration from the atmosphere, e.g. by underground disposal in depleted natural gas reservoirs or for enhanced oil recovery from petroleum reservoirs.
  • exported power may be delivered only from the fuel cell stack, thus there is no export of power from a thermal bottoming cycle, or generators and associated gear boxes on the thermal bottoming turbines which are thus reduced to simple turbochargers.
  • the system utilizes high grade waste heat from the fuel cell stack to drive free rotor turbochargers as required for feed air compression, vacuum pumping of exhaust nitrogen-enriched air, and heavy reflux compression of carbon dioxide enriched anode tail gas; with the stack waste heat matched to these auxiliary loads so as to facilitate operation at high current density.
  • the fuel cell stack can run at relatively high current density (e.g., about 200 to about 400 mA/cm2) to generate the required amount of waste heat for the auxiliary compression loads, since the disclosed PSA systems have dramatically raised open circuit voltages (e.g., about 0.75 to about 0.95 volts).
  • the necessary size of the fuel cell stack size per kW can be reduced greatly at high current density. Equivalently, the same size fuel cell stack can achieve the full power output formerly achieved by the stack plus the thermal bottoming generator, which can be eliminated in certain disclosed embodiments.
  • FIG. 1 shows an axial section of a rotary PSA module.
  • FIGS. 2 through 5B show transverse sections of the module of FIG. 1.
  • FIGS. 6 through 9 show simplified schematics of alternative MCFC cell plants embodiments. '
  • FIGS. 10 through 14 show simplified schematics of alternative SOFC cell plants embodiments.
  • a "rotary PSA” includes, but is not limited to, either a PSA wherein an array of adsorbers rotates relative to a fixed valve face or stator or a PSA wherein the valve face or stator rotates relative to an array of adsorbers.
  • FIG. 1 shows a rotary PSA module 1, which includes a number "N" of adsorbers 3 in adsorber housing body 4.
  • Each adsorber has a first end 5 and a second end 6, with a flow path therebetween contacting a nitrogen-selective adsorbent (for oxygen enrichment).
  • the adsorbers are deployed in an axisymmetric array about axis 7 of the adsorber housing body.
  • the housing body 4 is in relative rotary motion about axis 7 with first and second functional bodies 8 and 9, being engaged across a first valve face 10 with the first functional body 8 to which feed gas mixture is supplied and from which the heavy product is withdrawn, and across a second valve face 11 with the second functional body 9 from which the light product is withdrawn.
  • the adsorber housing 4 rotates and shall henceforth be referred to as the adsorber rotor 4, while the first and second functional bodies are stationary and together constitute a stator assembly 12 of the module.
  • the first functional body shall henceforth be referred to as the first valve stator 8
  • the second functional body shall henceforth be referred to as the second valve stator 9.
  • the adsorber housing 4 may be stationary, while the first and second functional bodies are rotary distributor valve rotors.
  • the flow path through the adsorbers is parallel to axis 7, so that the flow direction is axial, while the first and second valve faces are shown as flat annular discs normal to axis 7.
  • the flow direction in the adsorbers may be axial or radial, and the first and second valve faces may be any figure of revolution centred on axis 7.
  • the steps of the process and the functional compartments to be defined will be in the same angular relationship regardless of a radial or axial flow direction in the adsorbers.
  • FIGS. 2-5 are cross-sections of module 1 in the planes defined by arrows 12'-13', 14'-15', and 16'-17'. Arrow 20 in each section shows the direction of rotation of the rotor 4.
  • FIG. 2 shows section 12'- 13' across FIG.l, which crosses the adsorber rotor.
  • N 72.
  • the adsorbers 3 are mounted between outer wall 21 and inner wall 22 of adsorber wheel 208.
  • Each adsorber comprises a rectangular flat pack 3 of adsorbent sheets 23, with spacers 24 between the sheets to define flow channels here in the axial direction.
  • Separators 25 are provided between the adsorbers to fill void space and prevent leakage between the adsorbers.
  • the adsorbers 3 may include a plurality of distinct zones between the first end 5 and the second end 6 of the flow channels, here shown as three zones respectively a first zone 26 adjacent the first end 5, a second zone 27 in the middle of the adsorbers, and a third zone 28 adjacent the second end 6.
  • the different adsorbents may be provided in layers or mixtures that include varying gradients of adsorbent concentrations along the gas flow path. The transition from one adsorbent to another may also be a blended mixture of the two adsorbents rather than a distinct transition.
  • a further option is to provide a mixture of the different adsorbents that may or may not be homogeneous.
  • the first zone may contain an adsorbent or desiccant selected for removing very strongly adsorbed components of the feed gas mixture, such as water or methanol vapor, and some carbon dioxide.
  • the second zone may contain an adsorbent typically selected for bulk separation of impurities at relatively high concentration
  • the third zone may contain an adsorbent typically selected for polishing removal of impurities at relatively low concentration.
  • the first zone may contain an adsorbent that preferentially adsorbs C02 relative to water vapor as described above.
  • the second zone may contain an adsorbent (e.g., zeolite, Cu(I)-containing material, or Ag(I)-containing material) that preferentially adsorbs CO relative to water vapor.
  • the third zone may contain a desiccant for removing water vapor such as alumina gel.
  • the C02-selective adsorbent and the CO-selective adsorbent maybe included or mixed together in a single zone rather than in two distinct zones.
  • the reforming and/or water gas shift reaction catalyst(s) described above may be included in any part of the adsorber bed, but typically are included in the section prior to removal of the water vapor since water vapor is a reactant for the reforming and water gas shift reactions.
  • nickel supported on alumina is an effective catalyst for steam reforming of methane and the water gas shift reaction.
  • iron/chromia catalysts are effective for the water gas shift reaction.
  • copper/zinc oxide catalysts are effective for the water gas shift reaction.
  • any excess heat may be removed from the PSA by providing, for example, heat exchange means in a wall of the PSA or in the adsorber beds.
  • any required additional heat may be delivered to the PSA by providing, for example, heat exchange means in a wall of the PSA or in the adsorber beds or by integrating a burner with the PSA.
  • the adsorbent sheets comprise a reinforcement material (e.g., glass fibre, metal foil or wire mesh) to which the adsorbent material is attached with a suitable binder.
  • alumina gel may be used in the first zone to remove water vapor
  • typical nitrogen-effective adsorbents in the second and third zones are X, A or chabazite type zeolites, typically exchanged with lithium, calcium, strontium, magnesium and/or other cations, and with optimized silicon/aluminium ratios as well known in the art.
  • the zeolite crystals are bound with silica, clay and other binders, or self-bound, within the adsorbent sheet matrix.
  • the nitrogen- selective zeolite adsorbents tend to be effective in the temperature range from ambient up to about lOOoC.
  • Satisfactory adsorbent sheets have been made by coating a slurry of zeolite crystals with binder constituents onto the reinforcement material, with successful examples including nonwoven fibreglass scrims, woven metal fabrics, and expanded aluminium foils.
  • Spacers are provided by printing or embossing the adsorbent sheet with a raised pattern, or by placing a fabricated spacer between adjacent pairs of adsorbent sheets.
  • Alternative satisfactory spacers have been provided as woven metal screens, non-woven fibreglass scrims, and metal foils with etched flow channels in a photolithographic pattern.
  • Adsorbers of the layered adsorbent sheet material may be formed by stacking flat or curved sheets; or by forming a spiral roll, with the flow channels between the sheets extending from the first end of the adsorber to the second end thereof; to fill the volume of the adsorber housing of the desired shape. Examples of methods and structures with packed, spirally wound adsorbents are disclosed in commonly-owned, co-pending U.S. Provisional Application No. 60/285,527, filed April 20, 2001, and incorporated herein by reference.
  • Typical experimental sheet thicknesses have been 150 microns, with spacer heights in the range of 100 to 150 microns, and adsorber flow channel length approximately 20 cm.
  • excellent performance has been achieved in oxygen separation from air at PSA cycle frequencies in the range of 1 to at least 150 cycles per minute, particularly at least 25 cycles per minute.
  • FIG. 3 shows the porting of rotor 4 in the first and second valve faces respectively in the planes defined by arrows 14'-15', and 16'-17 ⁇
  • An adsorber port 30 provides fluid communication directly from the first or second end of each adsorber to respectively the first or second valve face.
  • FIG. 4 shows the first stator valve face 100 of the first stator 8 in the first valve face 10, in the plane defined by arrows 14'-15 ⁇ Fluid connections are shown to a feed compressor 101 inducting feed air from inlet filter 102, and to an exhauster 103 delivering nitrogen-enriched second product to a second product delivery conduit 104. Compressor 101 and exhauster 103 are shown coupled to a drive motor 105.
  • Arrow 20 indicates the direction of rotation by the adsorber rotor.
  • the open area of first stator valve face 100 ported to the feed and exhaust compartments is indicated by clear angular segments 111-116 corresponding to the first functional ports communicating directly to functional compartments identified by the same reference numerals 111-116.
  • the substantially closed area of valve face 100 between functional compartments is indicated by hatched sectors 118 and 119, which are slippers with, zero clearance, or preferably a narrow clearance to reduce friction and wear without excessive leakage.
  • Typical closed sector 118 provides a transition for an adsorber, between being open to compartment 114 and open to compartment 115.
  • a gradual opening is provided by a tapering clearance channel between the slipper and the sealing face, so as to achieve gentle pressure equalization of an adsorber being opened to a new compartment.
  • Much wider closed sectors e.g. 119 are provided to substantially close flow to or from one end of the adsorbers when pressurization or blowdown is being performed from the other end.
  • the feed compressor provides feed gas to feed pressurization compartments 111 and 112, and to feed production compartment 113.
  • Compartments 111 and 112 have successively increasing working pressures, while compartment 113 is at the higher working pressure of the PSA cycle.
  • Compressor 101 may thus be a multistage or split stream compressor system delivering the appropriate volume of feed flow to each compartment so as to achieve the pressurization of adsorbers through the intermediate pressure levels of compartments 111 and 112, and then the final pressurization and production through compartment 113.
  • a split stream compressor system may be provided in series as a multistage compressor with interstage delivery ports; or as a plurality of compressors in parallel, each delivering feed gas to the working pressure of a compartment 111 to 113.
  • compressor 101 may deliver all the feed gas to the higher pressure, with throttling of some of that gas to supply feed pressurization compartments 111 and 112 at their respective intermediate pressures.
  • exhauster 103 exhausts heavy product gas from countercurrent blowdown compartments 114 and 115 at the successively decreasing working pressures of those compartments, and finally from exhaust compartment 116 which is at the lower pressure of the cycle.
  • exhauster 103 maybe provided as a multistage or split stream machine, with stages in series or in parallel to accept each flow at the appropriate intermediate pressure descending to the lower pressure.
  • the lower pressure is ambient pressure, so exhaust compartment 116 exhaust directly to heavy product delivery conduit 104.
  • Exhauster 103 thus provides pressure letdown with energy recovery to assist motor 105 from the countercurrrent blowdown compartments 114 and 115.
  • exhauster 103 may be replaced by throttling orifices as countercurrent blowdown pressure letdown means from compartments 114 and 115.
  • the lower pressure of the PSA cycle is subatmospheric.
  • Exhauster 103 is then provided as a vacuum pump, as shown in FIG. 4B.
  • the vacuum pump may be multistage or split stream, with separate stages in series or in parallel, to accept countercurrent blowdown streams exiting their compartments at working pressures greater than the lower pressure which is the deepest vacuum pressure.
  • the early countercurrent blowdown stream from compartment 114 is released at ambient pressure directly to heavy product delivery conduit 104. If for simplicity a single stage vacuum pump were used, the countercurrent blowdown stream from compartment 115 would be throttled down to the lower pressure over an orifice to join the stream from compartment 116 at the inlet of the vacuum pump.
  • a vacuum pump can allow the PSA to operate at lower pressures that may be advantageous when the PSA is coupled to a fuel cell operating at lower pressures such as a MCFC operating at ambient pressure.
  • Vacuum PSA operation favors high oxygen yield or fractional recovery, and hence high-energy efficiency, in air separation.
  • FIGS. 5A and 5B shows the second stator valve face, at section 16'-17' of FIG. 1.
  • Open ports of the valve face are second valve function ports communicating directly to a light product delivery compartment 121; a number of light reflux exit compartments 122, 123, 124 and 125; and the same number of light reflux return compartments 126, 127, 128 and 129 within the second stator.
  • the second valve function ports are in the annular ring defined by circumferential seals 131 and 132.
  • Each pair of light reflux exit and return compartments provides a stage of light reflux pressure letdown, respectively for the PSA process functions of supply to backfill, full or partial pressure equalization, and cocurrent blowdown to purge.
  • a split stream light reflux expander 140 is shown in FIGS. 1 and 5A to provide pressure let-down of four light reflux stages with energy recovery.
  • the light reflux expander provides pressure let-down for each of four light reflux stages, respectively between light reflux exit and return compartments 122 and 129, 123 and 128, 124 and 127, and 125 and 126 as illustrated.
  • the light reflux expander 140 may power a light product booster compressor 145 by drive shaft 146, which delivers the oxygen enriched light product to oxygen delivery conduit 147 and compressed to a delivery pressure above the higher pressure of the PSA cycle.
  • a split stream light reflux expander 140 is provided to provide pressure letdown of four light reflux stages with energy recovery.
  • the light reflux expander serves as pressure let-down means for each of four light reflux stages, respectively between light reflux exit and return compartments 122 and 129, 123 and 128, 124 and 127, and 125 and 126 as illustrated. Since the light reflux and light product have approximately the same purity, expander 140 and light product compressor 145 may be hermetically enclosed in a single housing which may conveniently be integrated with the second stator as shown in FIG. 1.
  • This configuration of a "turbocompressor" booster without a separate drive motor is advantageous, as a useful pressure boost can be achieved without an external motor and corresponding shaft seals, and can also be very compact when designed to operate at high shaft speeds.
  • FIG. 5B shows the simpler alternative of using a throttle orifice 150 as the pressure letdown means for each of the light reflux stages.
  • compressed feed gas is supplied to compartment 113 as indicated by arrow 125, while heavy product is exhausted from compartment 117 as indicated by arrow 126.
  • the rotor is supported by bearing 160 with shaft seal 161 on rotor drive shaft 162 in the first stator 8, which is integrally assembled with the first and second valve stators.
  • the adsorber rotor is driven by motor 163 as rotor drive means.
  • a buffer seal 170 is provided to provide more positive sealing of a buffer chamber 171 between seals 131 and 171.
  • buffer seal 171 seals on a sealing face 172 at a much smaller diameter than the diameter of circumferential seal 131.
  • Buffer seal 170 seals between a rotor extension 175 of adsorber rotor 4 and the sealing face 172 on the second valve stator 9, with rotor extension 175 enveloping the rear portion of second valve stator 9 to form buffer chamber 171.
  • a stator-housing member 180 is provided as structural connection between first valve stator 8 and second valve stator 9.
  • FIGS. 6-14 disclose various energy recovery systems using different heat recovery working fluids.
  • the oxygen PSA compressor is integrated with an indirectly-heated gas turbine bottoming cycle using air as the working fluid. At least a portion of the air is provided to an oxygen enrichment PSA at suitable feed pressures for the PSA process; and the remainder of the air is compressed to a higher pressure as a gas turbine cycle working fluid indirectly heated by the fuel cell stack through heat exchangers coupled to the cathode and/or anode flow loops.
  • the thermal bottoming working fluid is an anode loop gas in a gas turbine or Brayton cycle.
  • a recuperative heat exchanger is used to achieve high thermodynamic efficiency of the thermal bottoming cycle.
  • the hydrogen enrichment PSA is operated with its second end at an elevated temperature approaching that of the fuel cell stack while its first end is maintained at a heat rejection temperature near ambient, it may be used as a thermal rotary regenerator for the gas turbine cycle using anode gas as working fluid.
  • Hydrogen may be used as the fuel for SOFC power plants.
  • the anode gas as a thermal bottoming cycle working fluid, hydrogen containing a substantial fraction of steam (e.g.
  • radial flow expander may be used for the hydrogen/steam mixture exiting the fuel cell anode.
  • compressors include high-speed centrifugal, multistage centrifugal, and positive displacement (e.g. twin screw) compressors.
  • the thermal bottoming cycle may use a separate working fluid from the cathode or anode gases, such as steam in a Rankine cycle or hydrogen in a Stirling cycle.
  • a separate working fluid from the cathode or anode gases, such as steam in a Rankine cycle or hydrogen in a Stirling cycle.
  • the use of a Stirling engine for thermal bottoming is particularly attractive because the engine working fluid may be replenished from the hydrogen fuel supply. The need for completely leak-tight Stirling engine seals for working fluid containment is thus relaxed in the present application.
  • the present disclosed systems and processes use oxygen enrichment and hydrogen enrichment by PSA to elevate the voltage and/or current density delivered by the fuel cell stack, the fractional amount of fuel heating value delivered as high grade waste heat to a thermal bottoming cycle is greatly reduced over the prior art. Accordingly, the thermal bottoming working fluid flow rates and heat exchange duties are correspondingly reduced.
  • the power rating of the thermal bottoming cycle is reduced in proportion to increased power delivered directly by the fuel cell stack.
  • the net mechanical power delivered by the thermal bottoming cycle is applied predominantly or exclusively to the compression loads associated with the PSA auxiliaries.
  • FIGS. 6-9 Each of FIGS. 6-9 is a simplified schematic of an example of a molten carbonate fuel cell power plant 200, including the fuel cell 202, a high temperature PSA unit 204 co-operating with a combustor 206 to transfer carbon dioxide from the anode side to the cathode side of the fuel cell, and an integrated gas turbine unit 208 for gas compression and expansion.
  • the PSA unit 204 increases hydrogen concentration and reduces carbon dioxide concentration over the cathode, thus increasing cell voltage. This directly increases fuel cell stack efficiency and electrical output, while also reducing the heat generated by the fuel cell so that the fraction of plant power output to be recovered less efficiently by a thermal bottoming cycle is reduced.
  • Molten carbonate fuel cell stack 202 includes the molten carbonate electrolyte 210 supported on a porous ceramic matrix, interposed between anode channel 212 and cathode channel 214.
  • the anode channel has an inlet 216 and an outlet 218, while the cathode channel 214 has an inlet 220 and an outlet 222.
  • FIG. 6 illustrates two alternatives for feed gas supply in combination. More typically, either of these feed gas supply alternatives might be used separately in any given MCFC installation. These alternatives correspond to the suitability of the feed gas for direct admission to the fuel cell anode, or for admission only after treatment by the first PSA unit. For the case of natural gas being the fuel, these alternatives also correspond to the fuel processing options or combinations of (1) "internal reforming" within the fuel cell stack, (2) “sorption enhanced reforming" within the first PSA unit, or (3) “external reforming" outside the immediate MCFC system as here described.
  • Endothermic reforming reactions are CH4 + H20 - ⁇ CO + 3H2 and CH4 + 2H20 ⁇ C02 + 4H2, with exothermic water gas shift CO + H20 ⁇ C02 + H2 , supplemented by partial combustion in the case of autothermal reforming
  • a first feed gas supply inlet 230 communicates to anode inlet 214, introducing a first feed gas already compressed and preheated to the MCFC working conditions.
  • the first feed gas might be hydrogen, syngas generated by an external fuel processor (e.g. coal gasifier or steam methane reformer), or natural gas for internal reforming within the anode channel 212 which would then be modified as known in the art to contain a suitable steam reforming catalysts such as nickel supported on alumina.
  • a second feed gas supply inlet 240 communicates to a feed production compartment in first rotary valve face 10 of the first PSA unit 204, again introducing feed gas already compressed and preheated to the first PSA unit higher pressure and working temperature.
  • the carbon dioxide and steam enriched heavy product stream is released from the blowdown and exhaust compartments in first rotary valve face 10 into conduit 242 at the lower pressure of the first unit PSA cycle.
  • the higher pressure of the first PSA is slightly above the working pressure of the MCFC, while the lower pressure may be atmospheric or subatmospheric. If the MCFC working pressure is selected to be near atmospheric, the first PSA would be a vacuum PSA with the lower cycle pressure in the range of about 0.1 to 0.5 bars absolute.
  • the heavy product stream from conduit 242 is compressed back up to the higher pressure of first PSA by carbon dioxide compressor 244, which delivers the compressed heavy product stream to conduit 246 which branches to heavy reflux conduit 247 communicating to a feed production compartment in first rotary valve face 10 of the first PSA unit 204, and to gas turbine combustor 206.
  • carbon dioxide compressor 244 delivers the compressed heavy product stream to conduit 246 which branches to heavy reflux conduit 247 communicating to a feed production compartment in first rotary valve face 10 of the first PSA unit 204, and to gas turbine combustor 206.
  • device 244 could be a vacuum pump for extracting the heavy product stream.
  • Enriched hydrogen light product gas from first PSA 204 is delivered by conduit 250 from the second rotary valve face 11 of the first PSA unit to anode inlet 216.
  • Three stages of light reflux are shown, in which separate streams of light product gas at successively declining pressures are withdrawn from the second rotary valve face 11 for pressure letdown in respective stages of light reflux expander 140, and then returned to the second rotary valve face for purging and repressurization of the adsorbers.
  • anode gas depleted in hydrogen and enriched in carbon dioxide and steam is withdrawn from anode exit 218 through conduit 255 for treatment by first PSA unit 204 to recover hydrogen, carbon dioxide, and methane fuel components, while removing carbon dioxide and at least a portion of the steam.
  • Anode channel 212, conduit 255, the PSA unit 204, and conduit 250 comprise an anode loop in which hydrogen is recirculated and replenished for substantially complete utilization of the hydrogen and other fuel components, while carbon dioxide is continually removed by PSA 204.
  • a pressure booster means may be useful to overcome flow pressure drop around the anode loop.
  • the pressure booster means is the PSA unit 204, with no mechanical pressure booster being required.
  • the anode exit gas in conduit 255 is at a moderately lower pressure than the feed gas in feed conduit 240 and the heavy reflux gas in conduit 247. Hence the anode exhaust gas is introduced to a feed repressurization compartment in first rotary valve face 10. After the anode exhaust gas has entered the adsorbers 3, it is there compressed back up to the higher pressure by feed gas and heavy reflux gas entering the adsorbers from conduits 240 and 247.
  • the heavy reflux step and conduit 247 may be eliminated, which will increase the fraction of fuel gas components (hydrogen, carbon monoxide and methane) delivered to combustor 206.
  • fuel gas components hydrogen, carbon monoxide and methane
  • With a relatively high-pressure ratio between the higher and lower pressures in the first PSA relatively high recovery of the fuel gas components in the light product gas (for recycle to the fuel cell anode) will be achieved.
  • fuel gas components may be substantially removed from the heavy product of carbon dioxide and/or water vapour so that combustor 206 might be eliminated or replaced with a small catalytic combustor.
  • a first heat exchanger 256 may be provided for the feed, heavy reflux and exhaust conduits communicating to the first valve face 10, so as to establish a first temperature at the first end of the adsorbers.
  • a second heat exchanger 257 may be provided for the light product, light reflux exit and light reflux return conduits communicating to the second valve face 11, so as to establish a second temperature at the second end of the adsorbers.
  • a third heat exchanger 258 may be provided to transfer heat from the anode exit conduit 255 to the light reflux exit conduits communicating to the inlets of the light reflux expander stages 140, so that high grade heat from the fuel cell stack is recovered at least in part in the expander 140.
  • Gas turbine assembly 208 includes compressor 260 and turbine 262, coupled to a motor/generator 264 by shaft 266 and to heavy product compressor 244 and light reflux expander 140 by shaft 267.
  • Ambient air is introduced to compressor 260 by infeed conduit 270, and is there compressed to working pressure for delivery by conduit 272 to combustor 206.
  • Combustor 206 burns residual fuel values (including some hydrogen and unconverted carbon monoxide and fuel) in the carbon dioxide rich heavy product stream.
  • a catalyst may be provided in combustor 206 to ensure stable combustion with high inert concentrations, or supplemental fuel may be added thereto. According to the embodiment shown in FIG.
  • the hot gas (i.e., the combustion product) exiting combustor 206 by conduit 280 is cooled in recuperative heat exchanger 285 to approximately the MCFC operating temperature for admission as cathode gas to cathode inlet 220.
  • the cathode gas contains carbon dioxide and residual oxygen, diluted by steam and nitrogen.
  • the depleted cathode gas is conveyed from cathode exit 222 by conduit 290 back to recuperator 285 for reheat to an elevated turbine entry temperature for admission by conduit 291 to turbine 262.
  • turbine 262 After expansion through turbine 262, the exhaust cathode gas is discharged through conduit 292 where further heat exchange would preferably take place to obtain most efficient heat recovery, e.g. for preheating the feed gas to inlets 230 and 240.
  • turbine 262 drives turbine assembly 208.
  • a portion of the hot gas (i.e., the combustion product) exiting combustor 206 may be diverted directly to turbine 262 rather than passing through the cathode channel 214.
  • a further variant would involve providing a second heavy product gas stream from PSA 204 into a second combustor and then introducing the hot combustion product directly into turbine 262.
  • FIG. 6 Also shown in FIG. 6 is the removal of water from the heavy product in conduit 242, either prior to compression by carbon dioxide compressor 244 as shown in FIG. 6, or after compression if a vacuum pump is used as compressor 244 as shown in FIG. 7.
  • a condenser 320 may be provided in conduit 242 for water removal and for cooling the heavy product gas so as to reduce the compression power required by compressor 244. Liquid water is removed by drain 321. The condensation temperature may be established by cooler 322.
  • a fourth heat exchanger 325 may be provided for recuperative heat exchange between conduits 242 and 246.
  • a further feature in FIG. 7 is the provision of a mechanical pressure booster for the anode loop, as booster compressor 330 which is powered directly by light reflux expander 140 through shaft 267.
  • Recompressed anode gas from conduit 255 is boosted back to the higher pressure by booster 330, and is delivered by conduit 331 to a production feed compartment in the first rotary valve face 10.
  • a portion of the anode exhaust gas in conduit 255 may still be delivered directly to a feed pressurization compartment by conduit 333.
  • the sole power source for booster 330 is expander 140, which is now separated from gas turbine assembly 208.
  • FIGS. 8 and 9 further embodiments are shown incorporating an oxygen VPSA in order to boost the oxygen and carbon dioxide partial pressures in the cathode channel, so as to increase the cell electromotive force and thus reduce the thermal bottoming load while enhancing overall plant efficiency.
  • FIGS. 8 and 9 as in FIGS. 6 and 7, various details of recuperative heat recovery and water condensation from the heavy product are shown in simplified schematic form.
  • the oxygen PSA or VPSA unit 400 includes a rotary module 401 with nitrogen-selective adsorbent in adsorbers 403, a first rotary valve face 410 and a second rotary valve face 411.
  • the first rotary valve face 410 receives compressed feed air at a feed production compartment from feed air compressor 260 via conduit 420, and discharges exhaust nitrogen enriched air from an exhaust compartment via conduit 422 to an optional vacuum pump 424 (to be included for VPSA or excluded for simple PSA) for discharge to atmosphere or any other use for moderately enriched nitrogen.
  • the second rotary valve face 411 delivers enriched light product oxygen at e.g.
  • the anode exhaust gas exiting anode outlet 218 could be introduced directly into a combustor 206 without first passing through a hydrogen PSA unit.
  • the anode exhaust gas then could be burned with the enriched oxygen stream produced by the oxygen PSA unit 400.
  • Oxygen enrichment of the air provided to combustor 206 may substantially reduce the inert load of nitrogen and argon in the cathode channel, thus enhancing electrochemical energy conversion performance as discussed above.
  • the working fluid for the gas turbine expander 262 is thus largely concentrated carbon dioxide with only small amounts of atmospheric gases.
  • oxygen enrichment may provide more complete combustion without a catalyst or with a smaller amount of catalyst and it may substantially eliminate the production of NOX emissions.
  • FIG. 9 shows the additional feature that a portion of the enriched oxygen from PSA 400 is used for fuel processing, either within the plant as here shown, or externally as in the example that coal gasification is used to generate syngas feed.
  • a portion of the compressed oxygen in conduit 434 is conveyed by conduit 440 to reformer 310, which here is an autothermal reformer for e.g., steam reforming natural gas.
  • FIG. 10 shows a simplified schematic of an example of an SOFC system embodiment 450 to which fuel gas (which may be natural gas, syngas or hydrogen) is provided by fuel inlet 230.
  • fuel gas which may be natural gas, syngas or hydrogen
  • Embodiment 450 includes an oxygen VPSA whose compression machinery is primarily powered by a regenerative gas turbine cycle using the anode gas as working fluid to recover cell stack waste heat as a thermal bottoming cycle to power system auxiliary compression loads.
  • enriched oxygen may be delivered by a positive pressure PSA process as illustrated in FIG. 4A.
  • Components and reference numerals generally follow the description as given above for FIGS 8 and 9.
  • the systems shown in FIGS. 10-14 are only examples and other systems with different arrangements of devices and conduits, or with additional or less devices and conduits could also be used.
  • Solid oxide fuel cell stack 502 includes a solid oxide electrolyte membrane 510 interposed between anode channel 512 and cathode channel 514.
  • the anode channel has an inlet 516 and an outlet 518 connected by anode loop 519, while the cathode channel 514 has an inlet 520 and an outlet 522. If the fuel is natural gas, it is internally reformed within the anode channel 512, while a suitable steam concentration is maintained in anode loop 519 so as to prevent ' carbon deposition.
  • the heavy product gas from the first PSA is in part exhausted by conduit 455 branching from conduit 242 and conveying the anode loop exhaust to combustor 206.
  • Cathode tail gas may be used as oxidant in combustor 206, and is conveyed from cathode outlet 522 by conduit 457 to the combustor.
  • Flue gas from combustor 206 is discharged by exhaust conduit 459 after heat recovery in heat exchanger 460, superheating the light reflux gas before entry to the stages of light reflux expander 140.
  • the working fluid in expander 140 is a mixture of steam and hydrogen if hydrogen is the fuel, also including carbon dioxide if methane or syngas is the fuel, introduced by fuel feed inlet 230.
  • the adsorber working temperature of the first PSA may be close to ambient temperature, in which case heat exchangers 256 and 257 will be heavily loaded recuperators.
  • the first PSA may operate at elevated temperature, in which case the second temperature adjacent the second valve face is preferably elevated relative to the first temperature adjacent the first valve face, so that the adsorber rotor functions as a thermal rotary regenerator.
  • the first zone 26 of the adsorbers operates in the temperature range from substantially ambient to about 300oC using, for example, alumina, zeolite 13X, or an at least moderately hydrophobic zeolite such as zeolite Y as the adsorbent.
  • the second zone 27 of the adsorbers may operate in the temperature range from about 300oC to about 500oC using, for example, alumina or a promoted hydrotalcite adsorbent.
  • the third zone 28 of the adsorbers may operate in the temperature range from about 5300oC to about 8OO0C using, for example, alumina or ultrastable Y zeolite hydrotalcite adsorbent.
  • the third zone 28 may contain (instead of adsorbent) a substantially nonadsorptive ceramic or metal material selected for utility in the high temperature zone of a rotary regenerator.
  • FIG. 11 shows a simplified schematic of another embodiment 475 of a SOFC fuel cell system, for which the fuel is hydrogen.
  • a Stirling engine 480 is used as the thermal bottoming system to recover waste heat.
  • Engine 480 has a hot end 481 in which expansion of a Stirling cycle working fluid is performed to take up heat from a thermally insulated jacket 482 enclosing the fuel cell stack.
  • Engine 480 has a cool end 483 in which compression of the Stirling cycle working fluid is performed to reject heat at substantially ambient temperature from cooler 484. Compressed hydrogen may be used as the Stirling cycle working fluid.
  • the Stirling engine may have a crank mechanism 485 to drive shaft 486 coupled to anode gas recirculation blower 490, the oxygen PSA feed blower 260, an optional PSA vacuum pump 424, and an optional generator 264.
  • a free piston Stirling engine mechanism may be used to drive all or some of the above compression loads directly without a shaft coupling.
  • FIG. 12 shows a simplified schematic of an example of an SOFC system embodiment 500 to which externally generated and purified hydrogen is provided by fuel inlet 230.
  • Embodiment 500 illustrates an oxygen VPSA whose compression machinery is primarily powered by free rotor gas turbines (turbochargers) recovering fuel cell stack waste heat as a thermal bottoming cycle used only to power system auxiliary compression loads. Enriched oxygen may alternatively be delivered by a positive pressure PSA process as illustrated in FIG. 4A.
  • Solid oxide fuel cell stack 502 includes a solid oxide electrolyte membrane 510 interposed between anode channel 512 and cathode channel 514.
  • the anode channel has an inlet 516 and an outlet 518 connected by anode loop 519, while the cathode channel 514 has an inlet 520 and an outlet 522 connected by cathode loop 523.
  • the anode and cathode loops pass through a heat exchanger 525 to reject stack waste heat at substantially the fuel cell working temperature.
  • Recirculation blowers or
  • first thermal recuperator 542 which also has a second end 543 at a temperature approaching the working temperature of the fuel cell stack.
  • the heat recovery working fluid is heated in recuperator 542 and then by heat exchanger 525 before being delivered to the inlet 549 of a first expander turbine 550.
  • the heat recovery working fluid is conveyed by conduit 551 to be reheated in heat exchanger 525 before being delivered to the inlet 559 of a second expander turbine 560.
  • the heat recovery working fluid After expansion to substantially atmospheric pressure in second turbine 560, the heat recovery working fluid is conveyed by conduit 561 through recuperator 542 where its remaining sensible heat is recovered for preheating air in conduit 540 and enriched oxygen in conduit 567, and then the spent heat recovery working fluid is discharged by conduit 565.
  • first turbine 550 is used to drive feed compressor 101 in a turbocharger 570
  • second turbine 560 is used to drive vacuum pump 103 in a turbocharger 572.
  • an electrical generator may also be connected to either turbine or to a third turbine.
  • the turbines may be supplied with the heat recovery working fluid in parallel rather than in series. Operation in series with reheat is thermodynamically more efficient. Intercooling may also be provided between stages of the feed compressor 101.
  • Enriched oxygen from the VPSA unit 401 is delivered through non-return valve 430 to an oxygen compressor 145 to boost the pressure of the enriched oxygen to substantially the working pressure of the cathode loop channel 514.
  • compressor 145 may include several stages, and the stages may be powered by any suitable motor or other drive means.
  • FIG. 12 shows a light reflux expander turbine 140 as the power source for oxygen compressor 145 as shown in FIG. 5A. This arrangement achieves highest energy efficiency by recovering energy from the pressure letdown of the light reflux gas, and has the advantage that the oxygen compressor 145 is driven by an oxygen expander 140 in a free rotor assembly which may be hermetically enclosed. For high working pressures (e.g. > 5 bars) it may be necessary to provide additional oxygen compression stages with a power source different or supplementary to light reflux expansion.
  • enriched oxygen delivered by simple VPSA systems typically contains about 5% argon and some minor amount of nitrogen impurity, it may be useful to remove a purge stream from the cathode loop 523 by a purge conduit 580.
  • Purge conduit 580 passes through recuperator 542 for recovery of sensible heat energy from the purge stream, and includes a throttle valve 581 or other means for pressure letdown before reaching the purge discharge port 582. If desired, all or a portion of the purge may be discharged to ambient, or alternatively all or a portion of the purge may be recycled from port 582 to a feed pressurization compartment of the VPSA unit 401 in order to retain enriched oxygen and also for recovery of compression energy in the VPSA process.
  • the fractional amount of the purge stream to be recycled into the VPSA unit will depend on optimisation analysis to determine the allowable accumulation of recycled argon impurity within the cathode loop.
  • moderately concentrated argon may be recovered as a commercially useful by product of the power plant 500.
  • a second thermal recuperator 590 may be provided for preheating hydrogen fuel delivered to the anode side at substantially the anode channel working pressure by fuel inlet 230.
  • First end 591 of recuperator 590 may be at substantially ambient temperature (or at a temperature at which hydrogen is stored).
  • Second end 592 of recuperator 590 is at substantially the stack working temperature.
  • a fraction of recirculated anode gas is diverted through a condensation loop including a cooling conduit 593 through recuperator 590 to condenser 595 and a reheating conduit 596 through recuperator 590 back to the anode inlet 516.
  • a cooling coil 597 and a liquid water discharge throttle valve 598 are included in condenser 595.
  • oxygen VPSA unit and the associated compression machinery provided therein as free rotor "turbocharger" machines for fuel cell stack waste heat recovery may also be applied to MCFC systems, subject to a stream of concentrated C02 also being supplied to the cathode loop so that two moles of C02 are available for each mole of 02 consumed in the MCFC cathode reaction.
  • FIGS. 13 and 14 show SOFC embodiments 600 with steam reformed natural gas fuelling.
  • Desulphurized natural gas is introduced at substantially the fuel cell working pressure to inlet 601, and thence by conduit 602 to first end 603 of reformer thermal recuperator 604, which preheats the natural gas feed as it flows to the second end 605 of the reformer recuperator.
  • Second end 605 is at an elevated temperature approaching the fuel cell stack working temperature.
  • the preheated natural gas flows by conduit 610 from the second end 605 of the reformer recuperator to inlet 619 of reformer reactor 620.
  • the natural gas reacts with steam in reactor 620 to produce syngas containing hydrogen, carbon monoxide and carbon dioxide; and some of the carbon monoxide may further react with steam to produce more hydrogen.
  • the syngas generated in reactor 620 is delivered from exit 621 thereof by conduit 622 back through the reformer recuperator (or a portion thereof) to cool the syngas down to the working temperature of the first PSA unit (for carbon dioxide extraction from the hydrogen anode fuel), and is thence delivered by conduit 623 to a feed compartment of the first H2 PSA unit 204.
  • the working temperature of the first PSA unit 204 may be close to that of the fuel cell stack or the reformer reactor.
  • the working temperature of the H2 PSA unit may be within about 100 to about 200°C of fuel cell stack or the reformer reactor.
  • the steam reforming reaction may be conducted as sorption enhanced reaction within the PSA unit in an adsorber zone approaching or exceeding about 600°C.
  • water gas shift may be conducted by sorption enhanced reaction over a suitable catalyst within the adsorbers.
  • the first PSA unit may be operated with conventional adsorbents for adsorbing C02 from hydrogen.
  • Enriched hydrogen product from the first PSA unit is delivered as light product by conduit 630 to anode loop conduit 632, and thence after pressure boost by anode recirculation blower 526 to the anode inlet 516 of the fuel cell stack.
  • Anode gas is withdrawn from anode exit 518 into conduit 640, which passes through reformer reactor heater 642 and thence to loop conduit 632.
  • Enriched carbon dioxide from the first PSA unit is withdrawn as heavy product at lower pressure by conduit 242 to the inlet of carbon dioxide compressor (or vacuum pump) 244 which serves as a heavy reflux compressor, and compresses the enriched carbon dioxide stream back to substantially the upper pressure of the first PSA unit cycle.
  • a portion of the C02 is recycled back to the PSA unit by conduit 247 to a heavy reflux feed compartment of the first PSA unit.
  • the balance of the compressed C02 is withdrawn by conduit 650 for disposal in the depicted case of a SOFC plant.
  • this C02 steam would be transferred by conduit 651 (shown as a dashed line in FIG. 13) for mixing into the enriched oxygen stream between non-return valve 430 and enriched oxygen compressor 145 so as to provide a suitable MCFC cathode oxidant stream with two moles of C02 for each mole of 02 consumed.
  • the carbon dioxide compressor or heavy reflux compressor 244 is shown in FIGS. 13 and 14 as powered by a third expander turbine 670 in a free rotor "turbocharger" assembly 672.
  • the third turbine 670 is shown in parallel operation with first turbine 550, so that the inlet conduit
  • conduit 540 which is the inlet to turbine 550, and exhaust conduit
  • conduit 676 from turbine 670 is connected to conduit 551 which is the exhaust conduit from turbine 550.
  • Conduit 540 admits heated air to the inlet of turbine 550, then conduit 677 admits the partially expanded air to the inlet of turbine 670, and conduit 678 admits the further expanded air to heat exchanger 525 for reheat and thence by conduit 551 to the inlet of turbine 560 for final expansion to atmospheric pressure. Desirably, conduit 677 would also be looped though heat exchanger 525 for reheat so that the inlet to each turbine stage is heated to the highest available temperature.
  • Superheating or reheating in FIGS. 13 and 14 may also be provided by an anode tail gas (or first PSA exhaust gas) combustor, which is not shown in these simplified schematics.
  • the anode tail gas burner will not generate any NOx emissions if the oxidant is highly enriched oxygen generated by the oxygen PSA or VPSA unit 401. Since anode tail gas will be mostly C02 with very little heating value of fuel components, enriched oxygen is desirably used as the oxidant, to avoid or minimize the need for a catalyst that would be needed for combustion of such extremely low BTU gas in air.
  • anode tail gas or first PSA exhaust gas
  • the fuel gas in the anode channel includes hydrogen and will probably also include carbon monoxide as a fuel component, so that water vapor and carbon dioxide are continually formed as reaction products.
  • a slipstream of anode gas is continually withdrawn from adjacent the anode exit 518 by conduit 680, and cooled through reformer recuperator 604 to the appropriate temperature for admission to a feed compartment for the first PSA unit by conduit 681.
  • the first PSA unit thus receives three feed streams in order of ascending C02 concentration: (1) the anode gas slip stream in conduit 680, (2) steam reforming reactor syngas in conduit 622, and (3) heavy reflux concentrated C02 from conduit 247.
  • each adsorber should receive those three feed streams in the same order (from conduit 681, then conduit 623, then conduit 247), so as to maintain the correct sequence of ascending C02 concentration.
  • Care must be taken with water vapor management in the embodiment of FIG. 13, so as to maintain an adequate steam/carbon ratio in the reformer and in the anode channel to prevent any carbon deposition and consequent catalyst deactivation.
  • Water vapor must be supplied with or into the natural gas feed gas. It may be necessary to use a somewhat hydrophobic adsorbent in the first PSA unit, or alternatively to inject supplemental water vapor into the fuel cell anode channel. In this embodiment, the separation is less stringent, since CO need not be separated while C02 is being extracted and concentrated.
  • the fuel gas in the anode channel is envisaged as purified hydrogen that has been separated by the first PSA unit, here designed and operated to remove CO and CH4 impurities as well as C02.
  • a tail gas burner may be used for combustion of residual fuel components in the PSA heavy reflux C02 enriched product stream, with the useful heat applied to preheating or reheating applications for waste heat recovery into expander turbines.
  • the first PSA unit of FIG. 14 receives two feed streams, the steam methane reformer reactor syngas from conduit 623, followed by the compressed heavy reflux from conduit 247, and has no recycle from the anode loop to which it delivered purified hydrogen. In this case, no C02 is formed in the anode channel, whose only reaction product is water vapor.
  • Water vapor could be extracted from the anode loop by recuperative heat exchange to a condenser as shown in FIG. 12, but in FIG. 14 water vapor is extracted by a rotary desiccant humidity exchanger 690 coupled between conduits 610 and 640.
  • Humidity exchanger 690 includes a desiccant wheel 691 engaged at first and second ends with valve faces 692 and 693. The humidity exchanger transfers anode product water vapor from anode exit conduit 640 to steam reforming reactor feed conduit 610, so as to remove water vapor from the anode loop while providing all of the water vapor required for steam methane reforming.
  • FIG. 1 Water vapor could be extracted from the anode loop by recuperative heat exchange to a condenser as shown in FIG. 12, but in FIG. 14 water vapor is extracted by a rotary desiccant humidity exchanger 690 coupled between conduits 610 and 640.
  • Humidity exchanger 690 includes a desiccant wheel 691 engaged at first and second ends with valve
  • conduit 640 carries humid anode gas through valve face 692 into one side of the desiccant wheel from which dried anode gas is delivered through valve face 693 to conduit 640' connecting to anode loop conduit 632.
  • Conduit 610 delivers humidified steam reformer feed gas through valve face 692 from the other side of the desiccant wheel to which dry preheated natural gas was feed through valve face 693 from conduit 610'.
  • the driving force for humidity transfer may be augmented by either establishing a higher temperature in conduit 610' relative to a lower temperature in conduit 640, or by establishing a higher pressure in conduits 640 and 640' relative to a lower pressure in conduits 610' and 610.
  • Estimated efficiencies based on fuel lower heating value are in the rough range of 60% for the MCFC embodiments, 70% for fossil fueled SOFC and 80% for hydrogen fueled SOFC at commercially attractive current densities.
  • the disclosed systems and process can avoid accumulation of C02 on the anode where C02 is generated by the reactions of CH4 and CO and well as by carbonate transport through the electrolyte, while also avoiding accumulation of inert nitrogen on the cathode.
  • the C02 mass flow from anode per unit of fuel may be only about 20% as large as the C02 mass flow in an MCFC anode into which most of the C02 is delivered from the electrolyte, hence the heavy reflux compressor or vacuum pump may be much smaller and will need less power; and 3. higher grade waste heat improves efficiency of heat recovery turbochargers.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Organic Chemistry (AREA)
  • Manufacturing & Machinery (AREA)
  • Sustainable Development (AREA)
  • Sustainable Energy (AREA)
  • Electrochemistry (AREA)
  • Inorganic Chemistry (AREA)
  • Analytical Chemistry (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Combustion & Propulsion (AREA)
  • Fuel Cell (AREA)
  • Separation Of Gases By Adsorption (AREA)

Abstract

L'invention concerne un système générant du courant électrique. Ce système comprend une pile à combustible fonctionnant à une température d'au moins environ 250 °C (par exemple, une pile à combustible à carbonate fondu ou une pile à combustible à oxyde solide), un système de séparation de gaz hydrogène ou un système de distribution de gaz oxygène comprenant un compresseur ou une pompe, ainsi qu'un système d'entraînement destiné au compresseur ou à la pompe comprenant des moyens permettant de récupérer de l'énergie à partir d'au moins un des systèmes de séparation de gaz hydrogène ou de distribution de gaz oxygène ou de la chaleur de la pile à combustible. Le système d'entraînement peut se présenter sous la forme d'un système de turbine à gaz. Le système de séparation de gaz hydrogène ou le système de distribution de gaz oxygène peut comprendre un module d'adsorption par variation de la pression.
PCT/CA2001/001522 2000-10-30 2001-10-26 Separation gazeuse ecoenergetique destinee a des piles a combustible WO2002037590A1 (fr)

Priority Applications (5)

Application Number Priority Date Filing Date Title
JP2002540232A JP2004512665A (ja) 2000-10-30 2001-10-26 燃料電池用エネルギー高効率ガス分離
BR0107399-0A BR0107399A (pt) 2000-10-30 2001-10-26 Separação de gás com energia eficiente para células de combustìvel
CA002394924A CA2394924A1 (fr) 2000-10-30 2001-10-26 Separation gazeuse ecoenergetique destinee a des piles a combustible
EP01982015A EP1334529A1 (fr) 2000-10-30 2001-10-26 Separation gazeuse ecoenergetique destinee a des piles a combustible
AU13716/02A AU780651B2 (en) 2000-10-30 2001-10-26 Energy efficient gas separation for fuel cells

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
CA002325072A CA2325072A1 (fr) 2000-10-30 2000-10-30 Systeme de separation de gaz pour pile a combustible a carbonates fondus
CA2,325,072 2000-10-30
US32316901P 2001-09-17 2001-09-17
US60/323,169 2001-09-17

Publications (1)

Publication Number Publication Date
WO2002037590A1 true WO2002037590A1 (fr) 2002-05-10

Family

ID=25682204

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/CA2001/001522 WO2002037590A1 (fr) 2000-10-30 2001-10-26 Separation gazeuse ecoenergetique destinee a des piles a combustible

Country Status (7)

Country Link
EP (1) EP1334529A1 (fr)
JP (1) JP2004512665A (fr)
CN (1) CN1258829C (fr)
AU (1) AU780651B2 (fr)
BR (1) BR0107399A (fr)
RU (1) RU2280925C2 (fr)
WO (1) WO2002037590A1 (fr)

Cited By (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2002067353A1 (fr) * 2001-02-21 2002-08-29 Ballard Power Systems Inc. Systeme de pile a combustible muni d'une unite d'adsorption modulee en pression a.m.p.
WO2002073728A1 (fr) * 2001-03-14 2002-09-19 Questair Technologies Inc. Systeme de generation de courant electrique comprenant une pile a combustible et une unite rotative d'adsorption modulee en pression
WO2004025767A2 (fr) * 2002-09-13 2004-03-25 Prototech As Appareil de generation de puissance
WO2004030130A2 (fr) * 2002-09-27 2004-04-08 Questair Technologies Inc. Systèmes améliorés de pile à combustible à oxyde solide
EP1620906A2 (fr) * 2003-04-09 2006-02-01 Ion America Corporation Coproduction d'hydrogene et d'electricite dans un systeme electrochimique haute temperature
JP2006515106A (ja) * 2003-01-14 2006-05-18 シエル・インターナシヨネイル・リサーチ・マーチヤツピイ・ベー・ウイ 電気及び高濃度二酸化炭素の生成方法
FR2881578A1 (fr) * 2005-02-01 2006-08-04 Renault Sas Dispositif de pile a combustible equipe d'un element d'enrichissement en oxygene
EP2112709A1 (fr) * 2007-02-07 2009-10-28 Central Research Institute of Electric Power Industry Installation génératrice
WO2010094391A1 (fr) * 2009-02-19 2010-08-26 Daimler Ag Système de pile à combustible comportant au moins une pile à combustible
US8071246B2 (en) 2003-04-09 2011-12-06 Bloom Energy Corporation Method of optimizing operating efficiency of fuel cells
AT507853B1 (de) * 2009-02-11 2014-09-15 Vaillant Group Austria Gmbh Sofc-brennstoffzelle mit einem externen dampfreformer
WO2024078724A1 (fr) * 2022-10-14 2024-04-18 Volvo Truck Corporation Système de pile à combustible

Families Citing this family (15)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2067937A2 (fr) * 2007-08-27 2009-06-10 Siemens Aktiengesellschaft Procédé de fonctionnement d'une centrale électrique avec gazage intégré tout comme centrale électrique
US20090155645A1 (en) * 2007-12-17 2009-06-18 Jingyu Cui System and process for generating electrical power
US7923162B2 (en) * 2008-03-19 2011-04-12 Dana Canada Corporation Fuel cell assemblies with integrated reactant-conditioning heat exchangers
EP2336083A1 (fr) 2009-12-17 2011-06-22 Topsøe Fuel Cell A/S Générateur de gaz et procédés pour la conversion de carburant en gaz désoxygéné et/ou gaz enrichi en hydrogène
US9647286B2 (en) * 2011-11-16 2017-05-09 Saudi Arabian Oil Company System and method for generating power and enhanced oil recovery
RU2485330C1 (ru) * 2011-11-16 2013-06-20 Федеральное государственное бюджетное учреждение "Национальный исследовательский центр "Курчатовский институт" Способ генерации энергии
CN102569859B (zh) * 2012-01-11 2014-05-14 华北电力大学 集成otm的加压co2零排放sofc/gt/at/st复合动力系统
US9540960B2 (en) * 2012-03-29 2017-01-10 Lenr Cars Sarl Low energy nuclear thermoelectric system
EP2877269B1 (fr) * 2012-07-25 2020-12-23 Koninklijke Philips N.V. Dispositif de séparation d'oxygène destiné à un système d'adsorption modulée en pression
CA2902986C (fr) * 2013-03-15 2019-09-17 Paul J. Berlowitz Fonctionnement integre de piles a combustible a carbonate fondu
NO3136728T3 (fr) * 2014-06-30 2018-07-28
JP6546398B2 (ja) * 2015-01-23 2019-07-17 東京瓦斯株式会社 燃料電池システム
CN112201810B (zh) * 2020-09-25 2024-05-28 上海华熵能源科技有限公司 一种稳压供气的氢燃料电池装置
WO2023033682A1 (fr) * 2021-09-05 2023-03-09 Александр Олегович МАЙБОРОДА Procédé concentration de dioxyde de carbone et dispositif de mise en œuvre
RU2771380C1 (ru) * 2021-09-05 2022-05-04 Сергей Станиславович Беднаржевский Устройство для утилизации углекислого газа

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5175061A (en) * 1989-04-25 1992-12-29 Linde Aktiengesellschaft High-temperature fuel cells with oxygen-enriched gas
US5955039A (en) * 1996-12-19 1999-09-21 Siemens Westinghouse Power Corporation Coal gasification and hydrogen production system and method
US5981096A (en) * 1997-01-17 1999-11-09 Daimlerchrysler Ag Fuel cell system
WO2000016425A1 (fr) * 1998-09-14 2000-03-23 Questor Industries Inc. Generateur de courant electrique

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5175061A (en) * 1989-04-25 1992-12-29 Linde Aktiengesellschaft High-temperature fuel cells with oxygen-enriched gas
US5955039A (en) * 1996-12-19 1999-09-21 Siemens Westinghouse Power Corporation Coal gasification and hydrogen production system and method
US5981096A (en) * 1997-01-17 1999-11-09 Daimlerchrysler Ag Fuel cell system
WO2000016425A1 (fr) * 1998-09-14 2000-03-23 Questor Industries Inc. Generateur de courant electrique

Cited By (19)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2002067353A1 (fr) * 2001-02-21 2002-08-29 Ballard Power Systems Inc. Systeme de pile a combustible muni d'une unite d'adsorption modulee en pression a.m.p.
WO2002073728A1 (fr) * 2001-03-14 2002-09-19 Questair Technologies Inc. Systeme de generation de courant electrique comprenant une pile a combustible et une unite rotative d'adsorption modulee en pression
WO2004025767A2 (fr) * 2002-09-13 2004-03-25 Prototech As Appareil de generation de puissance
WO2004025767A3 (fr) * 2002-09-13 2004-07-29 Prototech As Appareil de generation de puissance
WO2004030130A2 (fr) * 2002-09-27 2004-04-08 Questair Technologies Inc. Systèmes améliorés de pile à combustible à oxyde solide
WO2004030130A3 (fr) * 2002-09-27 2004-09-16 Questair Technologies Inc Systèmes améliorés de pile à combustible à oxyde solide
JP4800919B2 (ja) * 2003-01-14 2011-10-26 シエル・インターナシヨネイル・リサーチ・マーチヤツピイ・ベー・ウイ 電気及び高濃度二酸化炭素の生成方法
JP2006515106A (ja) * 2003-01-14 2006-05-18 シエル・インターナシヨネイル・リサーチ・マーチヤツピイ・ベー・ウイ 電気及び高濃度二酸化炭素の生成方法
EP1620906A2 (fr) * 2003-04-09 2006-02-01 Ion America Corporation Coproduction d'hydrogene et d'electricite dans un systeme electrochimique haute temperature
US8663859B2 (en) 2003-04-09 2014-03-04 Bloom Energy Corporation Method of optimizing operating efficiency of fuel cells
EP1620906A4 (fr) * 2003-04-09 2010-03-24 Bloom Energy Corp Coproduction d'hydrogene et d'electricite dans un systeme electrochimique haute temperature
US8071241B2 (en) 2003-04-09 2011-12-06 Bloom Energy Corporation Method for the co-production of hydrogen and electricity in a high temperature electrochemical system
US8071246B2 (en) 2003-04-09 2011-12-06 Bloom Energy Corporation Method of optimizing operating efficiency of fuel cells
FR2881578A1 (fr) * 2005-02-01 2006-08-04 Renault Sas Dispositif de pile a combustible equipe d'un element d'enrichissement en oxygene
EP2112709A4 (fr) * 2007-02-07 2011-03-30 Central Res Inst Elect Installation génératrice
EP2112709A1 (fr) * 2007-02-07 2009-10-28 Central Research Institute of Electric Power Industry Installation génératrice
AT507853B1 (de) * 2009-02-11 2014-09-15 Vaillant Group Austria Gmbh Sofc-brennstoffzelle mit einem externen dampfreformer
WO2010094391A1 (fr) * 2009-02-19 2010-08-26 Daimler Ag Système de pile à combustible comportant au moins une pile à combustible
WO2024078724A1 (fr) * 2022-10-14 2024-04-18 Volvo Truck Corporation Système de pile à combustible

Also Published As

Publication number Publication date
CN1258829C (zh) 2006-06-07
EP1334529A1 (fr) 2003-08-13
JP2004512665A (ja) 2004-04-22
RU2002120185A (ru) 2004-02-20
AU1371602A (en) 2002-05-15
AU780651B2 (en) 2005-04-07
CN1394368A (zh) 2003-01-29
RU2280925C2 (ru) 2006-07-27
BR0107399A (pt) 2002-10-22

Similar Documents

Publication Publication Date Title
US7087331B2 (en) Energy efficient gas separation for fuel cells
AU780651B2 (en) Energy efficient gas separation for fuel cells
US7097925B2 (en) High temperature fuel cell power plant
US7758988B2 (en) System that includes a fuel cell and an oxygen gas delivery system
EP1344270B1 (fr) Systemes et procedes d'alimentation d'hydrogene dans des piles a combustible
US7387849B2 (en) Hydrogen recycle for solid oxide fuel cell
US20040197612A1 (en) Hydrogen recycle for high temperature fuel cells
EP1468461A2 (fr) Systeme de piles a combustible a haute temperature
EP1114485A1 (fr) Generateur de courant electrique
CA2394924A1 (fr) Separation gazeuse ecoenergetique destinee a des piles a combustible
CA2324702A1 (fr) Purification de reformat et recuperation de chaleur pour des piles a combustible
CA2516300A1 (fr) Recyclage d'hydrogene pour piles a combustible a haute temperature
CA2424615A1 (fr) Systemes et procedes d'alimentation d'hydrogene dans des piles a combustible

Legal Events

Date Code Title Description
WWE Wipo information: entry into national phase

Ref document number: 2394924

Country of ref document: CA

WWE Wipo information: entry into national phase

Ref document number: 018033725

Country of ref document: CN

ENP Entry into the national phase

Ref country code: JP

Ref document number: 2002 540232

Kind code of ref document: A

Format of ref document f/p: F

WWE Wipo information: entry into national phase

Ref document number: 13716/02

Country of ref document: AU

WWE Wipo information: entry into national phase

Ref document number: 2001982015

Country of ref document: EP

121 Ep: the epo has been informed by wipo that ep was designated in this application
WWP Wipo information: published in national office

Ref document number: 2001982015

Country of ref document: EP

REG Reference to national code

Ref country code: DE

Ref legal event code: 8642

WWG Wipo information: grant in national office

Ref document number: 13716/02

Country of ref document: AU

WWW Wipo information: withdrawn in national office

Ref document number: 2001982015

Country of ref document: EP