US20090320369A1 - Method of generating an energy source from a wet gas flow - Google Patents

Method of generating an energy source from a wet gas flow Download PDF

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Publication number
US20090320369A1
US20090320369A1 US12/441,230 US44123007A US2009320369A1 US 20090320369 A1 US20090320369 A1 US 20090320369A1 US 44123007 A US44123007 A US 44123007A US 2009320369 A1 US2009320369 A1 US 2009320369A1
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steam
gas flow
hydrogen
combustion
temperature
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Raymond Guyomarc'h
Bernard Weil
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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
    • 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
    • C10J3/02—Fixed-bed gasification of lump fuel
    • C10J3/06—Continuous processes
    • C10J3/10—Continuous processes using external 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
    • C10J3/00—Production of combustible gases containing carbon monoxide from solid carbonaceous fuels
    • C10J3/72—Other features
    • C10J3/80—Other features with arrangements for preheating the blast or the water vapour
    • 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
    • C10J2300/0903—Feed preparation
    • 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
    • C10J2300/0903—Feed preparation
    • C10J2300/0909—Drying
    • 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
    • C10J2300/0953—Gasifying agents
    • C10J2300/0956—Air or oxygen enriched air
    • 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
    • C10J2300/0959—Oxygen
    • 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
    • C10J2300/1253—Heating the gasifier by injecting hot gas
    • 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
    • C10J2300/1603—Integration of gasification processes with another plant or parts within the plant with gas treatment
    • C10J2300/1606—Combustion processes
    • 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
    • C10J2300/16—Integration of gasification processes with another plant or parts within the plant
    • C10J2300/1671—Integration of gasification processes with another plant or parts within the plant with the production of electricity
    • C10J2300/1675—Integration of gasification processes with another plant or parts within the plant with the production of electricity making use of a steam turbine
    • 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
    • C10J2300/1861—Heat exchange between at least two process streams
    • C10J2300/1884—Heat exchange between at least two process streams with one stream being synthesis gas
    • 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
    • C10J2300/1861—Heat exchange between at least two process streams
    • C10J2300/1892—Heat exchange between at least two process streams with one stream being water/steam
    • 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
    • Y02E60/36—Hydrogen production from non-carbon containing sources, e.g. by water electrolysis
    • 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
    • Y02P20/133—Renewable energy sources, e.g. sunlight
    • 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
    • Y02P20/141—Feedstock
    • Y02P20/145—Feedstock the feedstock being materials of biological origin

Definitions

  • the present invention relates to a method of generating a renewable energy source from a gas flow and the use of this energy source to produce electricity with a high yield. It also relates to a system implementing the method according to the invention.
  • the field of the invention is the field of generation of an energy source.
  • the invention applies more particularly to generation of an energy source from a gas flow, comprising steam and having served in any treatment, or produced by any method or system.
  • thermodynamic gas flow which is generally steam, producing mechanical work or electricity.
  • a purpose of the invention is to propose a method and a system allowing an energy source to be generated from a gas flow comprising steam with a better yield than the current methods and systems.
  • Another purpose of the invention is to propose a method and a system which make it possible to more easily generate an energy source from a gas flow.
  • the invention proposes to deal with the abovementioned problems by a method of generating energy from a so-called initial gas flow, comprising steam, the method comprising deoxidation of at least some of the steam by passing the initial gas flow through a layer of high-temperature oxidation-reduction material, called the thermal base, essentially comprising high-temperature carbon elements, the deoxidation making it possible to obtain a first gas flow comprising hydrogen obtained by the reaction of the steam with the high-temperature carbon elements.
  • the method according to the invention makes it possible to generate hydrogen from the steam present in the initial gas flow, using high-temperature carbon elements.
  • the hydrogen generated is the energy source, which represents a very substantial energy value.
  • the method according to the invention makes it possible to recover not only a large part of the thermal energy from the steam present in the initial flow, but also a large part of the deoxidation energy of the H 2 O molecule by the generation of hydrogen from this steam.
  • the method according to the invention makes it possible to generate more energy than the current methods and systems.
  • the hydrogen, vector of this energy can be used in numerous known industrial systems.
  • the initial gas flow can comprise steam from an industrial method at the installation site, from the recycling of the steam after combustion of the hydrogen, or thermomechanical means vaporizing a volume of water during the start-up of the system.
  • the thermal base essentially comprises high-temperature carbon elements and makes it possible to provide, in a single system, the thermal energy and the carbon elements for carrying out the deoxidation of the steam and producing H 2 .
  • the carbon elements can be those of the chemical composition of the known raw materials such as coal, lignin, peat, vegetable or animal biomass.
  • the method according to the invention makes it possible to achieve an exploitable energy yield greater than that of the current methods and systems.
  • the thermal base comprising high-temperature carbon makes it possible on the one hand to raise the temperature of the steam contained in the initial flow in order to create the temperature necessary for the deoxidation of this steam, and on the other hand to provide the carbon elements which are involved in this deoxidation.
  • the temperature at the thermal base is such that the steam passing through this thermal base reacts with the high-temperature carbon elements so as to produce hydrogen by the following deoxidation reactions:
  • This reaction therefore requires a heat supply of 91 kJ in order for the disproportionation, formulated above, to be achieved.
  • This energy is provided by the combustion of at least some of the thermal base.
  • the method according to the invention can also comprise a step separating the hydrogen from the other elements contained in the gas flow after deoxidation of the steam. This separation can be carried out by easily used devices available in the trade.
  • the method according to the invention can comprise storage of the hydrogen obtained during the separation stage.
  • the method according to the invention can comprise generation of electricity in a fuel cell from at least some of the hydrogen, this generation also producing a reaction gas.
  • the reaction gas essentially comprises steam which can be recycled and deoxidized through the thermal base in order to produce hydrogen which will again serve to generate electricity in the fuel cell, in a continuous cycle.
  • the method according to the invention can also advantageously comprise combustion of at least some of the hydrogen in a gas-fired boiler, said combustion producing thermal energy and a combustion gas comprising high-temperature, low-pressure steam.
  • the combustion of the hydrogen can also be carried out in a gas turbine, a gas engine, or a conventional boiler producing steam.
  • the combustion of the hydrogen in the steam boiler can be carried out under O 2 .
  • the combustion gas flow comprises virtually only very high-temperature, low-pressure steam.
  • the combustion of the hydrogen can be carried out under air.
  • thermodynamic fluid in a second gas flow essentially comprising high-temperature, high-pressure steam.
  • At least some of the high-temperature, high-pressure steam can also be used in a system for the production of mechanical and/or electrical energy.
  • At least some of the steam contained in the second gas flow is used to produce electricity in a steam turbine, or a turbo-alternator, this production of electricity also comprising generation of a third gas flow comprising low-pressure, low-temperature steam.
  • the temperature/pressure pairing that can be obtained in the system and method according to the invention can reach very substantial levels which make it possible to carry out electricity production at the highest yield of existing and future systems and to increase the electricity production yield relative to the thermal potential used at the start.
  • the method according to the invention can also comprise compression of at least some of the low-temperature, low-pressure steam contained in the third gas flow bringing said steam to a condensation pressure.
  • This compression can be carried out in compression means arranged at the outlet from a steam turbine.
  • the method according to the invention can comprise recovery of at least some of the condensation energy of the steam obtained after compression.
  • the method can also comprise an increase in temperature of at least some of the steam contained in the third flow.
  • the method according to the invention can comprise recycling of at least some of the combustion gas comprising steam, by passing at least some of this gas through the oxidation-reduction thermal base, for a fresh deoxidation of said steam in this gas, this deoxidation again producing hydrogen.
  • the permanent recycling of the gas flows logically restores all of the energy potential that they contain less the losses inherent in the systems and equipment used for the invention. Therefore, all of the residual heat capacity of the steam can thus be recovered at the thermal base and is deducted from the energy to be provided to condition the oxidation-reduction carbon elements and allow the disproportionation or the deoxidation of the steam.
  • the hydrogen obtained is again transferred to the energy cogeneration system, in a continuous cycle.
  • the thermal base In this recycling mode, the thermal base must be capable of deoxidizing steam continuously, the quantity of high-temperature carbon must therefore be sufficient. The supply of high-temperature carbon must be continuous.
  • At least some of the steam contained in the combustion gas can be mixed with at least some of the steam obtained in any peripheral system, such as a system for the dehydration of vegetable biomass or system for supplying water in liquid phase and evaporation in an exchanger using the surplus heat of the system according to the invention.
  • the mixture can then be deoxidized through the thermal base and a fresh cycle started in the method according to the invention, in a continuous cycle.
  • At least some of the steam of the third flow, compressed to a condensation pressure then raised in temperature, can be recycled and used to produce electricity in a steam turbine, after a raising of its temperature and its pressure.
  • the temperature of the steam can be raised using the thermal energy present at the thermal base or the thermal energy obtained by combustion of the hydrogen in a gas-fired boiler, or both.
  • the method according to the invention can comprise generation of the thermal base by combustion of vegetable biomass or of coal.
  • the combustion of biomass can be carried out under O 2 or under air.
  • the biomass the combustion of which makes it possible to generate the thermal base can comprise vegetable biomass, the moisture content of which has been reduced beforehand, such as biomass dried in air, biomass dried in a treatment unit, roasted biomass, etc.
  • the initial gas flow can comprise at least some of a gas flow treating a biomass feedstock, such as the gas flow dehumidifying, drying or roasting a biomass feedstock.
  • a gas flow treating a biomass feedstock such as the gas flow dehumidifying, drying or roasting a biomass feedstock.
  • the steam present in the initial gas flow comes from the dried, dehumidified or roasted biomass.
  • the initial gas flow can comprise CO 2 or any other neutral gas that served as a heat-transfer vector for dehydration and treatment.
  • the thermal base comprises high-temperature carbon elements
  • the initial gas flow comprises CO 2 .
  • At least some of the CO 2 can also pass through at least one heat exchanger in order to reach there a temperature necessary for a predetermined treatment and be directly used in the treatment in question.
  • the treatment in question can be the roasting, drying, dehumidifying, etc. of a wood feedstock for example.
  • At least some of the CO 2 can be condensed and recovered, for example in liquid phase.
  • the thermal base used in the method according to the invention can be burning at a temperature which is controlled by injecting oxygen into the core of said base. This injection of oxygen can serve to control the temperature at the core of the base, upstream of the base or downstream of the thermal base.
  • a system is proposed of generating energy from a so-called initial gas flow, comprising steam, the system comprising:
  • the generation means comprise a heat generator provided to generate at least some of the thermal base, the generator also being provided to deoxidize at least some of the steam which passes through the thermal base.
  • the thermal base can be located within the heat generator.
  • the heat generator can comprise a thermal reactor or solid-fuel furnace or also a hybrid device allowing the combustion of a solid fuel, in particular vegetable biomass, the moisture content of which has been reduced by prior treatment. This combustion produces high-temperature carbon elements at least some of which can be used to produce the thermal base, and used as high-temperature oxidation-reduction carbon.
  • the heat generator can be equipped with a system controlling the temperature of the walls, by circulation of a heat-transfer fluid.
  • the generator can comprise double walls between which the heat-transfer liquid, for example pressurized water, can circulate.
  • the heat-transfer liquid can also be projected onto the walls of the heat generator.
  • the heat generator can comprise a grated furnace provided to receive the thermal base and set up to transfer the combustion gases of a biomass feedstock producing at least in part the thermal base and the initial gas flow.
  • the grated furnace can advantageously be equipped with a system of cooling by circulation of a heat-transfer fluid in the grids of the furnace.
  • the heat generator can also comprise oxygen-injection means.
  • the injection of oxygen can, on the one hand, serve to achieve the combustion of a solid fuel intended for the generation of the thermal base and on the other hand, to control the temperature at the thermal base.
  • the generator can also comprise means of collecting and separating the hydrogen obtained by deoxidation of the steam.
  • the heat generator can in particular comprise an expansion chamber for the gas flow that has passed through the high-temperature thermal base.
  • This expansion chamber is used in particular to complete the disproportionation of the residual steam molecules to H 2 on contact with the carbon monoxide elements from the incomplete combustion of the high-temperature carbon.
  • the heat generator can comprise at least one heat exchanger, this heat exchanger being provided to carry out heat exchanges between the first gas flow, essentially composed of high-temperature CO 2 and H 2 and a heat-transfer fluid, which can be that of a cooling circuit for part of the heat generating system.
  • This fluid is loaded with the thermal energy of said gas mixture in order to transfer it to an electricity cogeneration system, for example a turbo-alternator.
  • the system according to the invention can also comprise a device producing steam, valorizing the thermal energy from any element of the system.
  • the system can also comprise storage and/or distribution means for O 2 and/or CO 2 .
  • FIG. 1 is a diagrammatic representation of a first embodiment of the method according to the invention using a steam boiler
  • FIG. 2 is a diagrammatic representation of a second embodiment of the method according to the invention using a steam boiler
  • FIG. 3 is a diagrammatic representation of a third embodiment of the method according to the invention using a fuel cell.
  • FIG. 4 is a diagrammatic representation of a fourth embodiment of the method according to the invention using a fuel cell.
  • FIG. 1 diagrammatically represents a first embodiment of the method according to the invention.
  • the system represented in FIG. 1 comprises a unit 1 storing a solid fuel comprising carbon, and more particularly combustible carbon.
  • the combustible carbon can be coal or vegetable biomass the moisture content of which has been reduced by a prior treatment, such as dehumidification.
  • the unit 1 is a unit storing a feedstock of combustible raw material with a high carbon content B 1 .
  • the feedstock of high-carbon combustible raw material B 2 is introduced, by a regulating system B, into the reactor R where it is burned under O 2 .
  • This combustible raw material is intended on the one hand to form the thermal base and on the other hand to bring this thermal base to, and maintain it at, the process temperature.
  • the complete combustion of this raw material under O 2 produces CO 2 .
  • the reactor R also receives an initial gas flow F 1 comprising high-temperature, low-pressure steam from an exchanger E 2 and a mixing box Cm.
  • the steam from E 2 undergoes the oxidation-reduction reaction while passing through the thermal base.
  • This disproportionation produces the first high-temperature, low-pressure gas flow Fg 1 .
  • This first gas flow Fg 1 is composed essentially of H 2 and CO 2 .
  • H 2 and CO 2 are then separated in an industrial gas separation system S-G.
  • the CO 2 obtained by separation is a neutral gas flow Fn, too hot to be utilized as such, which is cooled in a cooling unit E 3 .
  • a part Fnr of the cooled CO 2 is discharged and the remainder Fns compressed in compression means C 1 and stored in storage means S 1 .
  • a part Fns 1 of the stored CO 2 can be used as a flow to cool the system according to the invention or for the safety of the system.
  • the hydrogen obtained is burned under O 2 in a gas-fired boiler Ch.
  • the combustion of the hydrogen under O 2 makes it possible on the one hand to generate a very high-temperature combustion gas flow Gc 1 essentially comprising low-pressure steam H 2 O and on the other hand to generate a second gas flow Fg 2 essentially comprising steam obtained by heating a thermodynamic fluid Fth essentially comprising water.
  • this second gas flow Fg 2 essentially comprises high-temperature, very high-pressure steam.
  • the combustion gas Gc 1 which has transferred the majority of its thermal potential to the second gas flow Fg 2 , still retains a substantial thermal load at the outlet from the boiler Ch: approximately 10 to 20% of the calorific power of the combustion of H 2 under O 2 in the system.
  • This combustion gas comprising steam is recycled into the reactor R after passing through an exchanger/mixing box E 2 and Cm where it can be mixed with a supply F 1 - 1 of liquid H 2 O which serves as a top-up.
  • the liquid H 2 O is evaporated in the exchanger/mixing box E 2 and Cm, a system Pch coupled to a heating system for the start-up phase vaporizes the supplied water.
  • the gaseous mixture thus formed at the outlet from box Cm, becomes the initial gas flow F 1 , it is at a high temperature and low pressure and participates in the useful heat exchange within the thermal base. All the thermal energy contained in this gaseous mixture is thus recycled, as is the steam which is deoxidized again on passing through the thermal base, in a continuous cycle.
  • the second gas flow Fg 2 comprising very high-pressure superheated steam obtained at the outlet from the gas-fired boiler Ch drives a steam turbine TAV which generates electricity by an alternator A coupled to the system.
  • the turbine makes it possible to utilize most of the mechanical energy of the steam.
  • a third gas flow Fg 3 is obtained, comprising very low-pressure, low-temperature steam. This steam is compressed by a steam compressor C 2 , at a pressure sufficient for its physical change to the liquid state in the processor/exchanger VAP.
  • thermodynamic flow Fth The water obtained by condensation in this processor at the pressure relative to the enthalpy of the residual steam is superheated in the exchanger E 1 , it is thus recycled in thermodynamic flow Fth before being reintroduced into the secondary circuit of the gas-fired boiler Ch. A large part of the residual energy at the outlet from the steam turbine is thus recycled.
  • the electricity necessary for the compression generates thermal energy, by the “Joule” effect, which is utilized by the system, thus neutralizing some of the effect of the electricity consumption of the compressor on the operating balance.
  • FIG. 2 is a diagrammatic representation of a second embodiment of the method according to the invention.
  • the system according to the invention is used to recycle a gas flow Ft treating a biomass feedstock B 1 and to efficientlyze the energy from the gas flow that served to treat the biomass feedstock.
  • the biomass B 1 is dehydrated or roasted in the treatment unit 1 .
  • the extracted gaseous mixture comprises:
  • This gaseous mixture then becomes the initial gas flow F 1 which is recycled in the system and method according to the invention.
  • a part B 3 of the biomass B 1 that has been treated, for example by roasting or drying, is stored.
  • Another part B 2 of the biomass B 1 is introduced, by a regulating system B, into the reactor R where it is thermally reacted under O 2 in order to form the thermal base some of which serves to bring this thermal base to, and maintain it at, the process temperature.
  • the complete combustion of the biomass under O 2 produces CO 2 which can be used as heat-transfer flow Ft for the treatment of the original biomass B 1 .
  • the initial gas flow F 1 comprising heat-transfer CO 2 used in the treatment of the biomass B 1 and the steam extracted from the original biomass, is recycled into the reactor R after a heat exchange in a heat exchanger E 2 and passage through a mixing box Cm, explained below.
  • the initial gas flow is thus at a high temperature when it is introduced into the reactor R.
  • the CO 2 is neutral for the water-steam deoxidation reaction, but the steam undergoes the oxidation-reduction reaction of the thermal base.
  • This disproportionation produces a first gas flow Fg 1 essentially comprising H 2 and CO 2 .
  • H 2 is separated from the other components of the first gas flow, and in particular from the CO 2 , in an industrial gas separation system S-G, known to a person skilled in the art.
  • the CO 2 can be reused as heat-transfer gas Ft which will transmit its heat capacity to the biomass to be dehydrated or roasted.
  • the CO 2 has transferred some of its thermal load into the exchanger E 1 .
  • the hydrogen is burned under O 2 in a gas-fired boiler Ch producing superheated steam with a very high yield.
  • the combustion of the hydrogen under O 2 makes it possible on the one hand to generate a combustion gas Gc 1 essentially comprising high temperature/low-pressure steam H 2 O, and on the other hand to generate a second gas flow Fg 2 essentially comprising steam by heating a thermodynamic fluid Fth essentially comprising water.
  • this second gas flow Fg 2 essentially comprises high-temperature, very high-pressure steam.
  • the combustion gas Gc 1 which has transferred the greater part of its thermal potential to the second gas flow Fg 2 still retains a substantial thermal load: 10 to 20% of the calorific power of the combustion of H 2 under O 2 .
  • the steam contained in the combustion gas is recycled into the reactor R after passing through the mixing box Cm where it will be mixed with the initial gas flow F 1 , i.e. with the gaseous mixture treating the original biomass: CO 2 +H 2 O from the dehydration of the biomass B 1 .
  • the gaseous mixture thus formed becomes the new initial flow F 1 which will be recycled into the reactor R, it is at a high temperature and participates in the useful heat exchange within the thermal base. All the thermal energy contained in this gaseous mixture is thus recycled.
  • the steam is again deoxidized on passing through the thermal base, in a continuous cycle.
  • the second gas flow Fg 2 comprising very high-pressure superheated steam, obtained at the outlet from the gas-fired boiler Ch, drives a steam turbine TAV which generates electricity using the alternator A coupled to the system.
  • the turbine makes it possible to convert most of the “temperature/pressure” pairing of the steam into mechanical energy which will drive the alternator A.
  • a third gas flow Fg 3 is obtained, essentially comprising very low-pressure, low-temperature steam.
  • This steam is then compressed by a steam compressor C 2 , to a pressure sufficient for its physical change to the liquid state in the processor VAP: the water obtained in this processor (at the pressure relative to the enthalpy of the residual steam) is superheated in the exchanger E 1 before being reintroduced into the secondary circuit of the gas-fired boiler Ch. A large part of the residual energy at the outlet from the steam turbine is thus recycled.
  • the electricity necessary for the compression generates thermal energy by the “Joule” effect which is utilized by the system, thus neutralizing some of the effect of the electricity consumption of the compressor on the operating balance.
  • the continuous recycling of the steam in the disproportionation cycle and CO 2 generates surpluses.
  • the surplus water is discharged into the ecosystem.
  • the surplus CO 2 Fn is cooled in a cooling unit E 3 .
  • a part Fnr of this CO 2 is discharged into the ecosystem, the remainder Fns is compressed by compression means C 1 and stored in storage means S 1 .
  • FIG. 3 is a representation of a third embodiment of the method according to the invention using a fuel cell PAC.
  • the unit 1 is a unit storing a feedstock of high-carbon combustible raw material B 1 .
  • This raw material is a fuel for generating at the same time the physical and chemical conditions for the disproportionation of the steam contained in the initial gas flow.
  • the fuel will preferably be solid, in order to create the best homogenization conditions for the H 2 O disproportionation reaction.
  • the choice of fuel will be a combustible raw material which will preferably be renewable, i.e. dehydrated or roasted vegetable biomass, or peat or any other high-carbon fuel.
  • the feedstock of high-carbon combustible raw material B 2 is introduced, by a regulating system B, into the reactor R where it is burned under O 2 .
  • the combustible raw material thus forms the thermal base, some of which serves to bring this thermal base to, and maintain it at, the process temperature.
  • the complete combustion of this raw material under O 2 produces CO 2 .
  • the reactor R also receives the initial gas flow F 1 comprising high-temperature, low-pressure steam.
  • the steam from the exchanger E 1 undergoes the oxidation-reduction reaction while passing through the thermal base.
  • This disproportionation produces a first gas flow Fg 1 essentially composed of H 2 and CO 2 from the thermal reaction and the disproportionation.
  • the first gas flow Fg 1 is at a high temperature and low pressure.
  • H 2 and CO 2 are separated in an industrial “gas separator” system S-G.
  • the separator S-G can form an integral part of the fuel cell, of which it is then one of the constituents.
  • the CO 2 obtained Fn is cooled in a cooling unit E 3 .
  • a part Fnr of the cooled CO 2 is discharged and the remainder Fns is compressed by compression means C 1 and stored in storage means S 1 .
  • a part Fns 1 of the stored CO 2 can be used to cool the system according to the invention or for the security of the system.
  • the hydrogen obtained is introduced into the fuel cell PAC where it will be chemically reacted by the physical means of the system and an injection of industrial O 2 .
  • This reaction makes it possible on the one hand to generate electricity with a very high yield relative to the energy potential used at the start and on the other hand to generate a reaction gas flow Fgr essentially comprising high-temperature, low-pressure steam.
  • the electricity can be used directly by any conventional means.
  • the reaction gas flow Fgr is therefore essentially composed of high-temperature, low-pressure steam which retains a substantial thermal load.
  • This reaction gas flow Fgr comprising steam is recycled into the reactor R after passing into an exchanger/mixing box E 2 and Cm where it is mixed with a supply of liquid H 2 O which serves as a top-up F 1 - 1 .
  • the liquid H 2 O is evaporated in the exchanger/mixing box E 2 and Cm, a system Pch, coupled to a heating system for the start-up phase, vaporizes the supplied water.
  • the gaseous mixture thus formed at the outlet from the mixing box Cm, constitutes at least in part the initial gas flow F 1 .
  • This gaseous mixture is at a high temperature and low pressure and participates in the useful heat exchange within the thermal base. All the thermal energy contained in this gaseous mixture is thus recycled.
  • the steam is recycled into the reactor R, and is thus again deoxidized on passing through the thermal base, in a continuous cycle.
  • FIG. 4 is a representation of a fourth embodiment of the method according to the invention using a fuel cell PAC.
  • the system according to the invention is used to recycle a gas flow Ft treating a biomass feedstock B 1 and the recycling (for the valorization of the energy and elements) of the gas flow that served to treat the biomass feedstock.
  • the biomass B 1 is dehydrated or roasted in the treatment unit 1 .
  • the gaseous mixture extracted comprises:
  • This gaseous mixture then becomes the initial gas flow F 1 which will be recycled in the system and method according to the invention.
  • a part B 3 of the biomass B 1 that has been treated, for example by roasting or drying, is stored.
  • Another part of the biomass B 2 is introduced, by a regulating system B, into the reactor R where it is thermally reacted under O 2 in order to form the thermal base.
  • Some of this biomass B 2 serves to bring this thermal base to, and maintain it at, the process temperature.
  • the complete combustion of the biomass under O 2 produces CO 2 which can be used as heat-transfer flow Ft to treat the original biomass B 1 .
  • the initial gas flow F 1 comprising heat-transfer CO 2 used in the treatment of the biomass B 1 and the steam extracted from the original biomass, is recycled into the reactor R after a heat exchange in a heat exchanger E 1 and a passage through a mixing box Cm, explained below.
  • the initial gas flow F 1 is thus at a high temperature when it is introduced into the reactor R.
  • the CO 2 is neutral for the thermal reaction, but the steam undergoes the oxidation-reduction reaction of the thermal base.
  • This disproportionation produces a first gas flow Fg 1 essentially comprising H 2 and CO 2 .
  • H 2 is then separated from the other gaseous elements composing the first flow, and in particular the CO 2 , in an industrial gas separation system S-G, known to a person skilled in the art.
  • the CO 2 can be reused as heat-transfer treatment gas flow Ft which will transmit its heat capacity to the biomass to be dehydrated or roasted.
  • the CO 2 has transferred some of its thermal load in the exchanger E 1 , it may however still be too hot to be usable in treatment gas Ft, an injection of cold CO 2 Fns 1 will then regulate it.
  • the hydrogen obtained is introduced into the fuel cell PAC where it is chemically reacted by the physical means of the system and an injection of industrial O 2 .
  • This reaction makes it possible on the one hand to generate electricity in a very high yield relative to the energy potential utilized at the base and on the other hand to generate a reaction gas flow Fgr essentially comprising steam at a high temperature and low pressure.
  • the electricity can be used directly by any conventional means.
  • the reaction gas flow Fgr essentially comprises high-temperature, low-pressure steam which retains a substantial thermal load.
  • This gas flow comprising steam is introduced into a mixing box Cm where it is mixed with the gas flow extracted from the unit 1 treating the biomass, and which has passed through the heat exchanger E 1 where it has acquired a substantial heat capacity.
  • the gaseous mixture thus formed at the outlet from the mixing box Cm constitutes at least in part the initial gas flow F 1 and is at a high temperature and low pressure and participates in the useful heat exchange within the thermal base. All the thermal energy contained in this gaseous mixture is thus recycled.
  • the steam is recycled and again deoxidized on passing through the thermal base, in a continuous cycle.
  • a part Fn of the CO 2 obtained is cooled in a cooling unit E 3 .
  • a part Fnr of the cooled CO 2 is discharged and the remainder Fns is compressed by compression means C 1 and stored in storage means S 1 .
  • a part Fns 1 of the stored CO 2 can be used to cool the system according to the invention or for the security of the system.
  • the surplus water is also discharged into the ecosystem at the outlet from the fuel cell PAC.
  • the CO 2 which will be used as heat-transfer treatment flow Ft, is at a very high temperature at the outlet from the separator. It exchanges the greater part of its thermal load, with the gas flow extracted from the biomass treatment unit, in the exchanger E 1 . This heat-transfer flow will then be controlled, at the temperature necessary for its utilization, by a supply of cold CO 2 Fns 1 .
  • the invention is of course not limited to the examples which have just been described and can be used to generate energy from any gas flow comprising steam.
US12/441,230 2006-09-13 2007-09-13 Method of generating an energy source from a wet gas flow Abandoned US20090320369A1 (en)

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FR0607983A FR2905691B1 (fr) 2006-09-13 2006-09-13 Procede de generation d'une source d'energie a partir d'un flux gazeux humide.
FR0607983 2006-09-13
PCT/FR2007/001486 WO2008031950A2 (fr) 2006-09-13 2007-09-13 Procédé de génération d'une source d'énergie à partir d'un flux gazeux humide

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EP (1) EP2071928A2 (fr)
JP (1) JP2010503746A (fr)
CA (1) CA2663583A1 (fr)
FR (1) FR2905691B1 (fr)
RU (1) RU2009113605A (fr)
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US20110107670A1 (en) * 2008-04-09 2011-05-12 Saint-Gobain Glass France Gasification of combustible organic materials
FR3043689A1 (fr) * 2015-11-13 2017-05-19 Air Liquide Procede et installation de production d'energie electrique et d'energie thermique a partir de biomasse lignocellulosique

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Publication number Priority date Publication date Assignee Title
FR3007829A1 (fr) * 2013-06-26 2015-01-02 Air Liquide Procede de chauffe avec generation et combustion de syngaz et installation pour sa mise en œuvre

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US2084749A (en) * 1932-08-06 1937-06-22 Earl L Tornquist Method of manufacturing water gas
US5306481A (en) * 1989-02-14 1994-04-26 Manufacturing And Technology Conversion International, Inc. Indirectly heated thermochemical reactor apparatus and processes
US20010027642A1 (en) * 1998-03-24 2001-10-11 Tadashi Tsuji Intake-air cooling type gas turbine power equipment and combined power plant using same
US20010016274A1 (en) * 2000-01-25 2001-08-23 Emi Kawasumi Fuel cell system and method
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US20060029893A1 (en) * 2004-08-09 2006-02-09 Kuai-Teng Hsu Process and system of power generation
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US20110107670A1 (en) * 2008-04-09 2011-05-12 Saint-Gobain Glass France Gasification of combustible organic materials
US9163187B2 (en) 2008-04-09 2015-10-20 Saint-Gobain Glass France Gasification of combustible organic materials
FR3043689A1 (fr) * 2015-11-13 2017-05-19 Air Liquide Procede et installation de production d'energie electrique et d'energie thermique a partir de biomasse lignocellulosique

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WO2008031950A2 (fr) 2008-03-20
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RU2009113605A (ru) 2010-10-20
EP2071928A2 (fr) 2009-06-24
JP2010503746A (ja) 2010-02-04
FR2905691A1 (fr) 2008-03-14
FR2905691B1 (fr) 2009-07-03

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