WO2007123776A2 - Procédés et systèmes pour la gazéification d'un flux à traiter - Google Patents

Procédés et systèmes pour la gazéification d'un flux à traiter Download PDF

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Publication number
WO2007123776A2
WO2007123776A2 PCT/US2007/008033 US2007008033W WO2007123776A2 WO 2007123776 A2 WO2007123776 A2 WO 2007123776A2 US 2007008033 W US2007008033 W US 2007008033W WO 2007123776 A2 WO2007123776 A2 WO 2007123776A2
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WO
WIPO (PCT)
Prior art keywords
chamber
process stream
carbon monoxide
gasification
hydrogen
Prior art date
Application number
PCT/US2007/008033
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English (en)
Other versions
WO2007123776A3 (fr
Inventor
Marco J. Castaldi
John Dooher
Klaus S. Lackner
Original Assignee
The Trustees Of Columbia University In The City Of New York
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by The Trustees Of Columbia University In The City Of New York filed Critical The Trustees Of Columbia University In The City Of New York
Priority to EP07754543.2A priority Critical patent/EP2007674A4/fr
Priority to US12/295,099 priority patent/US20090320368A1/en
Priority to AU2007240969A priority patent/AU2007240969B2/en
Publication of WO2007123776A2 publication Critical patent/WO2007123776A2/fr
Publication of WO2007123776A3 publication Critical patent/WO2007123776A3/fr

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    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J3/00—Production of combustible gases containing carbon monoxide from solid carbonaceous fuels
    • 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
    • C01B3/501—Separation of hydrogen or hydrogen containing gases from gaseous mixtures, e.g. purification by diffusion
    • C01B3/503—Separation of hydrogen or hydrogen containing gases from gaseous mixtures, e.g. purification by diffusion characterised by the membrane
    • C01B3/505—Membranes containing palladium
    • 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
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J3/00—Production of combustible gases containing carbon monoxide from solid carbonaceous fuels
    • C10J3/72—Other features
    • C10J3/82—Gas withdrawal means
    • C10J3/84—Gas withdrawal means with means for removing dust or tar from the gas
    • 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
    • H01M8/0606—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
    • H01M8/0643—Gasification of solid fuel
    • 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
    • H01M8/0668—Removal of carbon monoxide or carbon dioxide
    • 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
    • H01M8/0681—Reactant purification by the use of electrochemical 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
    • C01B2203/02—Processes for making hydrogen or synthesis gas
    • C01B2203/0283—Processes for making hydrogen or synthesis gas containing a CO-shift step, i.e. a water gas shift step
    • 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
    • C01B2203/0405—Purification by membrane separation
    • 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
    • C01B2203/042—Purification by adsorption on solids
    • C01B2203/043—Regenerative adsorption process in two or more beds, one for adsorption, the other for regeneration
    • 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
    • C01B2203/0495—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
    • C01B2203/80—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
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2200/00—Details of gasification apparatus
    • C10J2200/09—Mechanical details of gasifiers not otherwise provided for, e.g. sealing means
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/09—Details of the feed, e.g. feeding of spent catalyst, inert gas or halogens
    • C10J2300/0913—Carbonaceous raw material
    • C10J2300/0916—Biomass
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/09—Details of the feed, e.g. feeding of spent catalyst, inert gas or halogens
    • C10J2300/0913—Carbonaceous raw material
    • C10J2300/093—Coal
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/09—Details of the feed, e.g. feeding of spent catalyst, inert gas or halogens
    • C10J2300/0953—Gasifying agents
    • C10J2300/0969—Carbon dioxide
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/09—Details of the feed, e.g. feeding of spent catalyst, inert gas or halogens
    • C10J2300/0953—Gasifying agents
    • C10J2300/0973—Water
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/12—Heating the gasifier
    • C10J2300/1215—Heating the gasifier using synthesis gas as fuel
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/12—Heating the gasifier
    • C10J2300/1223—Heating the gasifier by burners
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/12—Heating the gasifier
    • C10J2300/1246—Heating the gasifier by external or indirect heating
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/16—Integration of gasification processes with another plant or parts within the plant
    • C10J2300/164—Integration of gasification processes with another plant or parts within the plant with conversion of synthesis gas
    • C10J2300/1643—Conversion of synthesis gas to energy
    • C10J2300/1646—Conversion of synthesis gas to energy integrated with a fuel cell
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10J—PRODUCTION OF PRODUCER GAS, WATER-GAS, SYNTHESIS GAS FROM SOLID CARBONACEOUS MATERIAL, OR MIXTURES CONTAINING THESE GASES; CARBURETTING AIR OR OTHER GASES
    • C10J2300/00—Details of gasification processes
    • C10J2300/18—Details of the gasification process, e.g. loops, autothermal operation
    • C10J2300/1807—Recycle loops, e.g. gas, solids, heating medium, water
    • 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
    • Y02E20/00—Combustion technologies with mitigation potential
    • Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
    • Y02E20/18—Integrated gasification combined cycle [IGCC], e.g. combined with carbon capture and storage [CCS]
    • 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
    • Y02P30/00—Technologies relating to oil refining and petrochemical industry

Definitions

  • gasifiers are known in industry.
  • a variety of fixed bed, fluidized bed, and entrained flow gasifiers have been in use for decades.
  • a gasification agent such as steam, oxygen, and/or air flows through a fixed bed of fuel source, e.g., coal or biomass, thereby gasifying the fuel source.
  • the fuel source is fluidized in oxygen/air and steam.
  • the gas throughput of fluid bed gasifiers is higher than for fixed bed gasifiers, but not as high as for entrained flow gasifiers.
  • entrained flow gasifiers a slurry of particulates and fluids is gasified with oxygen.
  • Fixed bed and fluidized bed gasifiers typically have lower outlet temperatures, e.g., below the ash slagging temperatures, than single stage entrained gasifiers. At lower gasifier outlet temperatures, more methane from coal devolatization survives, which results in a loss in hydrogen output and is typically 10-15 percent of the coal's carbon content at 400-500 psig.
  • the method includes the following: providing a process stream including a fuel source; applying a primary heat source to a first chamber containing the process stream; gasifying the process stream in the first chamber so as to produce a gasified process stream including one or more product gases; conducting at least a portion of the one or more product gases to a second chamber; combusting the at least a portion of the one or more product gases in the presence of one or more catalysts in the second chamber to generate a heat energy; and conducting the heat energy from the second chamber to the first chamber so as to provide the primary heat source.
  • a system for gasifying a process stream includes the following: a first chamber for gasifying the process stream to produce a gasified process stream including at least one of one or more product gases, water, and particulates, the gasification chamber including sidewalls; a primary heat source for heating the first chamber; and a second chamber for combusting the process stream, said second chamber in fluid communication with the first chamber and at least a portion of the process stream, the second chamber including one or more portions that are in thermal communication with respective ones of the sidewalls of the gasification chamber, the second chamber including interior surfaces having a coating formed from one or more catalysts, the second chamber being configured to combust at least a portion of the process stream to generate a heat energy that serves as the primary heat source and is provided to the first chamber via the one or more portions that thermally communicate with the first chamber.
  • a catalytic reaction gasifier for gasifying a process stream includes the following: a housing including one or more inlets and one or more outlets; a combustion chamber defined within the housing, the combustion chamber including a plurality of interior surfaces; one or more catalysts positioned within the combustion chamber; and a gasification chamber separate from but positioned so as to be in thermal communication with the combustion chamber, the gasification chamber including a first end and a second end, the first end being operably connected with the one or more inlets for receiving the process stream and the second end being operably connected with the one or more outlets.
  • FIG. 1 is a schematic diagram of a system according to some embodiments of the disclosed subject matter
  • FIG. 2 is a cross-sectional view of a gasifier device according to some embodiments of the disclosed subject matter
  • FIG. 3 is a diagram of a process according to some embodiments of the disclosed subject matter.
  • FIG. 4 is a graph of the simulation results for hydrogen production and energy required versus the percentage of carbon dioxide recycled to the catalytic combustion chamber for systems and methods device according to some embodiments of the disclosed subject matter
  • FIG. 5 is a graph of the simulation results for hydrogen production and energy required versus the percentage of carbon dioxide recycled to the catalytic combustion chamber for systems and methods device according to some embodiments of the disclosed subject matter
  • FIG. 6 is a graph of the simulation results for hydrogen production and energy required versus the percentage of carbon dioxide recycled to the catalytic combustion chamber for systems and methods device according to some embodiments of the disclosed subject matter;
  • FIG. 7 is a graph of the simulation results for water and methane versus the percentage of carbon dioxide recycled to the catalytic combustion chamber for systems and methods according to some embodiments of the disclosed subject matter;
  • FIG. 8 is a graph of the simulation results for hydrogen production and energy required versus the percentage of carbon dioxide recycled to the catalytic combustion chamber for systems and methods device according to some embodiments of the disclosed subject matter;
  • FIG. 9 is a schematic diagram showing how heat is generated in a catalytic combustion chamber designed in accordance some embodiments of the disclosed subject matter.
  • FIG. 10 is a schematic diagram showing how heat is generated in a prior art combustion chamber.
  • the disclosed subject matter of the present application relates to systems, methods, and devices that can be used to gasify a process stream containing a fuel source.
  • Gasification is a process that converts a fuel source, such as coal, petroleum, petroleum coke, and biomass, into carbon monoxide and hydrogen.
  • the systems, methods, and devices according to the disclosed subject matter utilize heat energy produced from combusting gases produced during the gasification of the fuel source to drive the gasification process.
  • Gasification of the fuel source is generally conducted in the presence of one or more catalysts.
  • a supplemental heat energy source is typically used to initiate the gasification process.
  • the heat energy produced during combustion of the gases produced during the gasification is used as the primary energy source for driving gasification after it has commenced.
  • catalytic combustion which can provides reaction and heat transfer rates that are significantly greater than those generated by bulk combustion used in conventional indirectly heated gasification schemes, allows the efficient use of indirect heating for entrained flow configurations, e.g., coal/biosolids + steam and/or CO 2 , for a wide range of scales and applications.
  • Carbon monoxide and hydrogen can be separated from the gases generated in the gasification process to generate electricity.
  • Carbon dioxide generated during the combustion of the gasification gases can be recycled for gasification with the fuel source or contained as a sequestration-ready source of carbon dioxide.
  • hydrogen can be recycled and catalytically combusted with air to provide the required heat without carbon dioxide generation.
  • System 20 includes a gasification chamber 24 in fluid and thermal communication with a combustion chamber 26.
  • Fuel source 22 which is typically coal or a biomass, but can alternatively be other combustible materials, is gasified in a first chamber, e.g., gasification chamber 24, to produce a process stream 28.
  • Process stream 28 includes at least one of one or more product gases, water, and particulates, e.g., ash.
  • process stream 28 is used in reference to a dynamic process stream that is altered as it travels through system 20.
  • One or more product gases (not shown) can include at least one of hydrogen, carbon monoxide, and combinations thereof.
  • a primary heat source 30 is indirectly applied to gasification chamber 24 to heat the gasification chamber and drive the gasification of process stream 28.
  • the components illustrated in FIG. 1 are not drawn to scale and may be sized according to the requirements of a particular application or as determined by one skilled in the art.
  • a second chamber e.g., combustion chamber 26, which is separate from but in fluid communication with gasification chamber 24 to receive a portion of process stream 28, includes one or more portions 32 that thermally communicate with the gasification chamber.
  • Combustion chamber 26 is configured to combust at least a portion of process stream 28 to generate a heat energy 34.
  • heat energy 34 indirectly serves as primary heat source 30 and thermally communicates with gasification chamber 24 via one or more portions 32 that are common to or coextensive with respective ones of side walls 35 of the gasification chamber.
  • An auxiliary heat source (not shown) can be used to begin the gasification of fuel source 22.
  • Combustion chamber 26 also includes interior surfaces 40 having a coating (not shown) disposed thereon and formed from one or more catalysts (not shown).
  • suitable catalysts include the following: one or more precious group metal formulation catalysts such as rhuthenium, rhodium, palladium, osmium, indium, platinum, and the like; one or more hexaaluminates such as AxB(i.
  • A can be Rh or Ni
  • B can be La, Mn, or Sr, barium hexaaluminate, manganese hexaaluminate, platinum-barium hexxaaluminate, and the like
  • one or more spinel catalysts such as CuCr 2 O 4 , MnFei 95RU0.05O4, MnCO 2 O 4 , and the like
  • one or more zeolite catalysts such as lovdarite and those sold under the trademarks YZSM-5, LINDE ZEOLITE-A, PENTASILS, and the like
  • base metal formulation catalysts such as Cu, Co, Fe, Ni, and the like.
  • System 20 can also include a hydrogen separator 42 for separating hydrogen from process stream 28. Separated hydrogen can be stored in a hydrogen storage tank 44 and/or utilized as an energy source in other processes, such as a proton exchange membrane fuel cell (not shown in FIG. 1).
  • System 20 can also include a particle separator 46 such as a cyclone or the like for separating particulate matter such as ash from process stream 28.
  • the separated particulate matter can be disposed of using conventional means.
  • particle separator 46 can also remove some water in addition to removing particulates from the process stream 28.
  • System 20 can also include a water separator 48 for separating water 50 from process stream 28. Separated water 50 can be recycled in system 20 by mixing it with fuel source 22 before introduction to gasification chamber 24. An additional source of water, a make-up water supply 52, can also be included in system 20 to supplement separated water 50 as necessary.
  • a water separator 48 for separating water 50 from process stream 28. Separated water 50 can be recycled in system 20 by mixing it with fuel source 22 before introduction to gasification chamber 24.
  • An additional source of water, a make-up water supply 52 can also be included in system 20 to supplement separated water 50 as necessary.
  • System 20 can also include a divider 54 for dividing process stream 28 after water is separated from the process stream.
  • Divider 54 can be used to adjustably divide the process stream into first and second process streams, a process stream 28' and a process stream 28", respectively, both of which are primarily made-up of carbon monoxide after process stream 28 has passed through hydrogen, particle, and water separators 42, 46, and 48, respectively.
  • divider 54 merely divides process stream 28 in to various portions.
  • divider 54 may serve as a carbon monoxide filter to remove only carbon monoxide from process stream 28.
  • Process stream 28' can be utilized in one or more power generating systems such as, but not limited to a gas turbine engine, an internal combustion engine, a solid oxide fuel cell (SOFC) 56, and/or other similar power generating systems known by those of ordinary skill in the art.
  • SOFC 56 typically produces electricity and sequestration-ready carbon dioxide.
  • Process stream 28" can be recycled directly to combustion chamber 26 for catalytic combustion or mixed with an oxygen supply 58 at a mixer 60 and then recycled to the combustion chamber.
  • Combustion chamber 26 generally produces sequestration-ready carbon dioxide, which can be stored in a carbon dioxide holding tank 62 and either disposed of using conventional means or recycled back to gasification chamber 24.
  • system 20 is designed to be modular. As a modular system, the specific components of system 20 can vary from those illustrated and FIG. 1 but generally include some or all of gasification chamber 24, combustion chamber 26, hydrogen separator 42, particle separator 46, water separator 48, and divider 54. In addition, the components that make-up system 20 can be individually skid-mounted, individually self-contained, and generally designed to be connected in the field.
  • Gasifier 70 for gasifying a fuel source, such as, but not limited to, coal, a biomass, and/or other combustible materials selected by those skilled in the art, is disclosed.
  • Gasifier 70 includes a housing 72, which includes wall partitions 73 that define a combustion chamber 74, and one or more tubes 75 that define a separate gasification chamber 76 that is positioned in thermal communication with the combustion chamber.
  • Combustion chamber 74 and gasification chamber 76 are configured so that a portion of heat energy (not shown) generated in the combustion chamber indirectly heats the gasification chamber thereby gasifying the fuel source into a process stream containing hydrogen.
  • Housing 72 includes a first inlet 78 for allowing the fuel source to enter gasification chamber 76 and a second inlet 80 for allowing carbon monoxide, oxygen, or a combination thereof to enter combustion chamber 74. Housing 72 also includes a one or more outlets including a first outlet 82 for exhausting gases from combustion chamber 74, a second outlet 84 for exhausting solid wastes from gasification chamber 76, a third outlet 86 for exhausting gaseous wastes from the gasification chambers, and a fourth outlet 88 for exhausting hydrogen from the gasification chambers.
  • combustion chamber 74 generally includes a plurality of exterior surfaces 89 and interior surfaces 90.
  • Interior surfaces 90 typically include a coating deposited thereon that is substantially made-up of one or more catalysts.
  • examples of acceptable catalysts include precious group metals, hexaaluminates, spinels, zeolites, base metal formulations, and combinations thereof.
  • gasification chamber 76 is typically made-up of one or more tubes 75 that extend through combustion chamber 74.
  • Each of one or more tubes 75 includes a first end 94 that is generally operably connected with first inlet 78 and a second end 96 that is generally operably connected with one or more of the outlets of housing 72.
  • Each of one or more tubes 75 includes a sidewall 97 that is common to and in thermal communication with interior surfaces 90 of combustion chamber 74.
  • second end 96 can be flared, which would serve to increase the space between the ash particles and tube walls, while resulting in a "jet" of particles down the center of the flared section.
  • Each of one or more tubes 75 generally includes an exterior surface 98 having a coating deposited thereon that is substantially made-up of one or more catalysts similar of the same as those coating interior surfaces 90 of combustion chamber 26.
  • Energy transfer to the reactants can be accomplished by indirect radiation in systems and methods according to the disclosed subject matter.
  • coal as the fuel source
  • the energy transfer to the particle via radiation can be about 100 kW/m2.
  • the transfer of this energy can result in a 20 micron spherical coal particle completely reacting on the order 0.5-1.0 seconds. Therefore, it is possible to transfer enough energy to sustain the gasification reaction, which was assumed to need about 150 kJ/mol with reasonable particle residence times. These residence times are roughly the same as that observed in conventional coal gasifiers.
  • gasification chamber 76 When operating with coal, slagging issues can be at least partially addressed orienting gasification chamber 76 in a particular manner. For example, if the ash fusion temperature is below 1000 degrees Celsius, gasification chamber 76 can be designed in a vertical configuration to allow slag to run down the walls. However, most coals can have ash fusion temperatures well above 1000 degrees Celsius. If this is the case, although ash deposition on surfaces (not shown) of gasification chamber 76 can cause problems, there are certain effects that will limit the amount of ash that is deposited to the surfaces of one or more tubes 75. First, since the walls are hot and the core gas is cold, a driving force will push the particles (ash) toward the center (also known as the Soret effect).
  • evaporation of volatiles off the coal particle surface facing the hot wall of one or more tubes 75 can be significantly faster than the evaporation of volatiles off the coal particle surface facing the center. Therefore, there can be a volume expansion of gases near the hot walls of one or more tubes 75 forcing the ash particles to the center.
  • Housing 72 can also include a carbon monoxide separator 100 and a hydrogen separator 102 for separating both carbon monoxide and hydrogen from the process stream after it exits gasification chamber 76.
  • Carbon monoxide separator 100 generally includes a polymeric membrane, ceramic membrane, filter, or other suitable means.
  • Hydrogen separator 102 is typically a palladium membrane or similar. Pressure swing absorption can also be used to separate hydrogen from the process stream.
  • gasification chamber 76 is in the form of tubes that extend through combustion chamber 74.
  • the combustion chamber can include at least one tube that extends through the gasification chamber.
  • the fuel source can be combustible materials such as, but not limited to, coal, biomass, and/or other combustible materials selected by those skilled in the art.
  • biomass such as, but not limited to, leaves, garden wastes, wood chips, waste paper, municipal solid wastes, agricultural waste (e.g., switch grass, wheat straw, etc.), animal wastes (e.g., chicken, cow, sheep, dog, etc. litter), treated sewage sludge, grease, waste oils, and/or other combustible biomass.
  • the fuel source utilized is coal.
  • the mixture can be gasified in a gasification chamber according to reaction [I]: C + H 2 O ⁇ - CO + H 2 • [1]
  • Reaction [1] involves reforming carbon by steam and can be referred to as a steam reforming (SR) reaction.
  • SR steam reforming
  • systems and methods of the disclosed subject matter include SR reactions that are carried out at temperatures of less than 1000 degrees Celsius.
  • the SR reaction can be carried out at temperatures between 600-1000 degrees Celsius.
  • the SR reaction can be carried out at temperatures between 700-900 degrees Celsius.
  • the SR reaction can be carried out at temperatures between 800-850 degrees Celsius.
  • coal is selected as the fuel source, any suitable ratio of water to coal can be utilized. For example, water can be mixed with coal at a particular ratio to obtain a slurry having a suitable viscosity. In some embodiments, a viscosity of from about 20 centipoises to about 500 centipoises can be utilized. In certain embodiments, a viscosity of from about 100 to 200 centipoises can be utilized.
  • Water can also be mixed with coal at a particular ratio to obtain a desired energy conversion efficiency. Water can also be mixed with coal at a particular ratio to obtain a desired syngas output capacity. Coal particle size ranging from approximately 20 ⁇ m to 250 ⁇ m can be utilized. As discussed in greater detail below with respect to the simulation results, typically, the portion of water is mixed with the fuel source so that a water to fuel source ratio ranges from about 0.7 to about 1.0.
  • process stream 214 is gasified in a first chamber.
  • a primary heat source 218, which is discussed further below, is generally applied to the first chamber to carry out the gasification process.
  • process stream 214 generally contains one or more product gases, including carbon monoxide and hydrogen, particulate matter including ash, impurities, and/or unreacted fuel source, e.g., coal, and water.
  • product gases including carbon monoxide and hydrogen, particulate matter including ash, impurities, and/or unreacted fuel source, e.g., coal, and water.
  • hydrogen is separated from process stream 214. A portion of the hydrogen can be used to generate a consumable energy such as, but not limited to, electricity.
  • particulate matter is separated from a hydrogen-depleted process stream 214.
  • water is separated from a hydrogen and particulate matter depleted process stream 214.
  • a separated water stream 226 can then optionally be mixed with the fuel source at 212 and gasified at 216.
  • process stream 214 which primarily includes carbon monoxide, is divided according to predetermined ratios.
  • process stream 214 can be further processed before to refine the carbon monoxide present in the stream prior to division of the stream.
  • a first portion 230 is divided from process stream 214 and forwarded to an energy producing process such as, but not limited to, a SOFC at 232 to produce consumable energy such as, but not limited to, electricity and sequestration-ready carbon dioxide.
  • an energy producing process such as, but not limited to, a SOFC at 232 to produce consumable energy such as, but not limited to, electricity and sequestration-ready carbon dioxide.
  • any suitable power-generating systems can be utilized in systems and methods according to the disclosed subject matter, as will be readily apparent to one of ordinary skill in the art.
  • the remaining portion of process stream 214, a second portion 234, can be mixed at 236 with a predetermined amount of oxygen 238.
  • second portion 234 of the carbon monoxide is generally about 20 to about 60 percent of the carbon monoxide contained in the process stream.
  • second portion 234 of the carbon monoxide is generally about 30 to about 50 percent of the carbon monoxide contained in the process stream.
  • second portion 234 which can include a portion of oxygen 238, is combusted in a second chamber in the presence of one or more catalysts to generate a heat energy 242.
  • the catalytic combustion reaction can be represented by reaction [2]:
  • Heat energy 242 is generally indirectly applied from the second chamber to the first chamber as primary heat source 218 to gasify process stream 214. It is preferred that the gasification of second portion 234 is substantially driven from heat energy 242, which is generated from combusting at least a portion of the one or more product gases, which generally include carbon monoxide, in the presence of one or more catalysts. A maximum temperature while combusting second portion 234, which includes one or more product gases, is about 1300 degrees Celsius.
  • Carbon dioxide 244 is typically generated while combusting at least a portion of the one or more product gases, e.g., second portion 234.
  • the carbon dioxide that is generated can be sequestration-ready.
  • At least a portion of carbon dioxide 244 can be recycled by gasifying it with process stream 214.
  • hydrogen can be recycled and catalytically combusted with air to provide the required heat without carbon dioxide generation.
  • a moisture or water separator and a hydrogen separator were combined as one unit and a cool down heat exchanger was inserted between the gasification chamber and water/hydrogen separator to drop the temperature from the gasification chamber outlet to a typical temperature for a separation unit.
  • the water/hydrogen separator, carbon monoxide separator, and carbon dioxide separator were modeled as ideal separators.
  • One option available in the systems and methods of the disclosed subject matter is the possibility of recycling a portion of the carbon dioxide that is produced in the catalytic combustion chamber to the gasification chamber. As shown in FIG. 5, if 25% of the carbon dioxide is recycled to the gasification chamber, more hydrogen is produced as compared to when 0% carbon dioxide is recycled to the gasification chamber. Moreover, less carbon monoxide needs to be recycled to the catalytic combustion chamber to generate enough power to run the gasification chamber without additional input of energy.
  • SR reaction is the primary reaction taking place although some methanation reaction occurs.
  • the amount of methane and water generally remains constant. This can be because the temperature of the reformer is fixed and additional heat generated or required factors into the heat balance calculations. Hence, the reactions occurring in the gasification chamber do not change with varying amounts of carbon monoxide in the catalytic combustion chamber.
  • the Boudouard reaction which has a slightly lower enthalpy of reaction than the SR reaction, appears to be favored.
  • the Boudouard reaction generates two carbon monoxide molecules for each carbon (coal) molecule reacted with carbon dioxide.
  • the carbon monoxide can then be shifted to hydrogen by the WGS reaction, which is exothermic and, hence, more efficient than the SR reaction, which can explain the lower energies requirement observed for the same amount of carbon monoxide supplied to the combustion chamber with increasing values of R (see FIG. 6).
  • An overall reduction for energy required in the gasification chamber can also allow more yield of hydrogen.
  • FIG. 5 shows that the maximum hydrogen production occurs at COR values of about 0.4 and 0.5. This occurs because at COR values greater than about 0.4, additional carbon dioxide begins to hinder the WGS reaction as water production dramatically increases and hydrogen production decreases.
  • IGCC Integrated Gasification Combined Cycle
  • a steam to carbon ratio of 0.7 is the least favorable from an energy requirement and hydrogen production standpoint. Effectively, enough steam may not exist to generate significant amounts of hydrogen and the major gasification reaction occurring is the Boudouard reaction. It is, however, very energy efficient. Hence, if the goal is to gasify carbon for energy generation, then low S/C values with high R values are generally desired.
  • S/C ratio of greater than 1.0 a slipstream of product carbon monoxide can be shifted to carbon dioxide + hydrogen via the WGS reaction in a downstream shift reactor with the excess water (above the 1-1 water/carbon molar ratio). The hydrogen can be diffused away leaving a carbon dioxide stream, which can be combined with the upstream for sequestration.
  • Systems and methods according to the disclosed subject matter include indirectly heating the reactor to provide the necessary heat in an entrained flow configuration, e.g., coal, biosolids, and/or steam and/or carbon dioxide, using heat from a form of catalytic combustion.
  • Patent catalytic partial oxidation of the coal or biosolids is accomplished using reaction path, whereby a recycled product gas, e.g., carbon monoxide, is catalytically oxidized to produce the necessary heat to produce the product gases.
  • the geometry of at least one system according to the disclosed subject matter which produces a high surface/volume ratio, maximizes the heat transfer between the combustor and the gasification reactor, and lends itself to not only large scale power generation, but also to mass produced small scale gasification systems including even micro reactor gasifiers.
  • Systems according to the disclosed subject matter are suited for modular configurations and can be part of a biorefinery when biomass is used as the feedstock. Systems according to the disclosed subject matter allow for easier adjustment of the operating parameters for differing feedstock's than in a conventional oxygen or air blown gasifier, which cannot be utilized effectively for certain biomass feedstock.
  • Systems and methods according to the disclosed subject matter can produce a sequestration ready stream of carbon dioxide, separate from the product gases. In a conventional oxygen blow gasifier, there is typically a portion of carbon dioxide mixed with the product gases.
  • Systems and methods according to the disclosed subject matter provide a gasification process that generates hydrogen and carbon monoxide, which can be used to produce consumable energy such as, but not limited to, electricity.
  • carbon monoxide generated during the gasification of coal can be partitioned so that a portion of the carbon monoxide is utilized to drive the gasification reaction.
  • systems and methods according to the disclosed subject matter can provide a unique reactor design that can operate at sufficiently low and uniform temperatures due to catalytic oxidation of product gases and allow the use of conventional materials and technologies in various processes of the present application, such as, but not limited to, hydrogen separation.
  • systems and methods of the disclosed subject matter require less oxygen to obtain specific hydrogen/carbon monoxide ratios in the product gases than in conventional single stage oxygen blown gasifier due to the catalytic combustion of the product gases.
  • Systems and methods of the disclosed subject matter allow improved plant efficiencies over standard gasification techniques. For example, economic gasification of low rank high moisture coals that have maximum dry solids contents of around 50% is likely possible.
  • the ability of the catalyst to operate outside the flammability regime normally needed by homogeneous systems allows for thermal efficiency gains. For example, to maintain a stable homogenous flame, temperatures near 2000 degrees Celsius are typically needed. However, combustion and heat transfer materials generally cannot withstand temperatures greater than 1250 degrees Celsius and usually are required to be kept below 1000 degrees Celsius. This necessitates the use of secondary (dilution) air to cool the combustion products to temperatures that the heat exchanger materials can withstand which results in one direct loss of efficiency.
  • the ability of the catalyst generate heat on its surface during the carbon monoxide to carbon dioxide conversion allows for efficient heat transfer to the gasification reaction.
  • the heterogeneous reaction requires one or both of the reactants to be adsorbed on the surface of the catalyst.
  • carbon monoxide oxidation carbon monoxide molecule is strongly adsorbed to the catalyst surface, which then reacts with oxygen to generate carbon dioxide.
  • FIG. 9 shows a conceptual depiction of the systems and methods of the disclosed subject matter where the heat release can occur on the catalyst. Referring now to FIG. 10, this is contrasted with conventional indirectly heated homogeneous gasification systems that are known in the prior art, where the heat release can occur in the bulk.
  • the heat transfer across the catalyst support and the metal substrate can be nearly 1000 times faster than the heat transfer that occurs across the momentum boundary layer. Calculations indicate that the primary mechanism of heat transfer from the metal surface to the gasification reaction likely occurs via radiation.
  • the coal particles which can be considered a black body, can be maintained at a temperature close to that of the gasification reaction conditions, i.e., approximately 600K, while the surface of the metal substrate can be nearly 1200K. Hence, there can be a considerable driving force for radiative heat transfer.
  • Systems and methods according to the disclosed subject differ from fixed bed, fluidized bed, and multi-stage gasifiers.
  • simulation of a conventional single stage entrained flow gasifier with the same feed conditions produces slightly less than 0.7kg/hr and requires twice as much oxygen as compared to Simulation 1 above.
  • catalytic combustion likely has the ability to interrupt NOx formation pathways and not allow carbon based emissions, such as, but not limited to, carbon monoxide and unburned hydrocarbons (UHC) to be released. Therefore, for embodiments according to the disclosed subject matter where oxygen is used to combust the carbon monoxide to carbon dioxide, it is likely that there will be no gas phase emissions. This is in contrast to a homogeneous system where NOx, especially thermal and fuel bound NOx, are routinely formed.
  • carbon based emissions such as, but not limited to, carbon monoxide and unburned hydrocarbons (UHC)
  • Systems and methods according to the disclosed subject matter can be up or down due to their catalytic nature.
  • Systems and methods according to the disclosed subject matter can scale with gas velocity because the heat transfer aspects (i.e. radiation) can be very insensitive to geometric scaling parameters.
  • Scalability can be done in at least two ways. First, systems according to the disclosed subject matter can be replicated many times over, effecting economies of mass production. Second, systems according to the disclosed subject matter can also be scaled up in the traditional sense. This is likely easier than scaling up other types of systems where heat loss must be considered.
  • Systems and methods according to the disclosed subject matter offer a modular design. Modular designs allow for rapid development cycles and the ability to swap modules in and out upon technological advances. Incremental construction of energy conversion facilities, and therefore incremental investment, can open the door for groups like developing nations who are excluded in the case of single large-scale investments.
  • Modular scaling can allow for a flexible response to shortages.
  • the development of automated controls and maintenance systems can provide efficient responses in these areas, as well as in standard operation.
  • Central housing in large plants can be effective in applying the modular approach. Less materials, controls, and operation and maintenance can be required than an equivalent energy output from a number of dispersed modules and the central plant can have an enhanced flexibility to respond to changes.
  • Individual units can include fuel-conditioning models, which, for example, can convert coal, coal slurries, biomass, or orimulsion into a syngas. Upstream units can prepare the input fuel; downstream energy conversion units can combust or electrochemically generate electric power. Other units can be designed to create specialty fuels like methanol, ultra clean Fischer Trospch diesel, or hydrogen.
  • Catalyst science has not evolved to the point where an a-priori prediction about performance of a given formulation can be given. Therefore, it is a benefit of the systems and methods of the disclosed subject matter that they can be easily and cheaply modified to accept new formulations as they are being developed.
  • a modular approach can afford this in two significant ways. First, as the reactor train is being moved from an exhausted part of the tar sand field to a more fertile one, new catalysts can be quickly and easily installed, thus adding little, if any, downtime to the transfer. Second, as new formulations are being developed, they can be tested in-situ and compared directly against the ones already in operation. If the new catalysts yield different product compositions, in the overall system operation, this will not amount to a significant change in ultimate product quality.

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Abstract

L'invention concerne des procédés et des systèmes pour la gazéification de flux à traiter. Selon certains modes de réalisation de l'invention, un procédé pour la gazéification d'un flux à traiter consiste à gazéifier le flux à traiter dans une première chambre afin de générer un ou plusieurs produits gazeux, à transporter au moins une partie de ces produits gazeux dans une deuxième chambre, à faire brûler au moins une partie de ces produits gazeux en présence d'un ou de plusieurs catalyseurs dans la deuxième chambre afin de générer de l'énergie thermique et à amener indirectement l'énergie thermique de la deuxième chambre à la première chambre en tant que source de chaleur primaire pour alimenter la gazéification du flux à traiter.
PCT/US2007/008033 2006-03-31 2007-03-30 Procédés et systèmes pour la gazéification d'un flux à traiter WO2007123776A2 (fr)

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US12/295,099 US20090320368A1 (en) 2006-03-31 2007-03-30 Methods and Systems for Gasifying a Process Stream
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See also references of EP2007674A2 *

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* Cited by examiner, † Cited by third party
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US9091213B2 (en) 2006-12-16 2015-07-28 Keld Energy Limited Processing biomass
GB2444856B (en) * 2006-12-16 2011-04-06 Keld Energy Ltd Processing biomass
EP2291492A1 (fr) * 2008-06-12 2011-03-09 Cortus AB Procédé et équipement de production d'hydrogène gazeux utilisant la biomasse
EP2291492A4 (fr) * 2008-06-12 2013-02-27 Cortus Ab Procédé et équipement de production d'hydrogène gazeux utilisant la biomasse
US9487715B2 (en) 2008-10-22 2016-11-08 Mitsubishi Hitachi Power Systems, Ltd. Coal gasifier
EP2338956A1 (fr) * 2008-10-22 2011-06-29 Mitsubishi Heavy Industries, Ltd. Four de gazéification de charbon
EP2338956A4 (fr) * 2008-10-22 2013-03-13 Mitsubishi Heavy Ind Ltd Four de gazéification de charbon
WO2010062879A3 (fr) * 2008-11-26 2010-10-28 Good Earth Power Corporation Gazéification améliorée pour la production de gaz et d’énergie à partir de matières carbonées
WO2010062879A2 (fr) * 2008-11-26 2010-06-03 Good Earth Power Corporation Gazéification améliorée pour la production de gaz et d’énergie à partir de matières carbonées
JP2010221160A (ja) * 2009-03-24 2010-10-07 Showa Shell Sekiyu Kk 改質触媒及びこれを用いた合成ガスの製造方法
EP2584023A1 (fr) * 2011-10-21 2013-04-24 Neste Oil Oyj Procédé de production de composition de gaz de synthèse
CN104583377A (zh) * 2012-07-09 2015-04-29 南方公司 高灰分、高灰熔点烟煤的气化
EP2706103A1 (fr) 2012-09-05 2014-03-12 Commissariat A L'energie Atomique Et Aux Energies Alternatives Procédé de gazéification de charge de matière carbonée à rendement amélioré
FR2994980A1 (fr) * 2012-09-05 2014-03-07 Commissariat Energie Atomique Procede de gazeification de charge de matiere carbonee, a rendement ameliore.
EP3568452A4 (fr) * 2017-01-15 2021-01-27 Wormser Energy Solutions, Inc. Gazéification tout-vapeur pour système à cycle de puissance co2 supercritique
US11193073B2 (en) 2017-01-15 2021-12-07 Wormser Energy Solutions, Inc. All-steam gasification for supercritical CO2 cycle system
US11572518B2 (en) 2019-11-25 2023-02-07 Wormser Energy Solutions, Inc. Char preparation system and gasifier for all-steam gasification with carbon capture
CN114045181A (zh) * 2021-10-28 2022-02-15 西安热工研究院有限公司 一种旋风式生物质半气化实验装置

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AU2007240969B2 (en) 2013-02-21
AU2007240969A1 (en) 2007-11-01
EP2007674A2 (fr) 2008-12-31
WO2007123776A3 (fr) 2008-06-26
US20090320368A1 (en) 2009-12-31
EP2007674A4 (fr) 2014-03-19

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