US20090260585A1 - Oxyfuel Combusting Boiler System and a Method of Generating Power By Using the Boiler System - Google Patents

Oxyfuel Combusting Boiler System and a Method of Generating Power By Using the Boiler System Download PDF

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Publication number
US20090260585A1
US20090260585A1 US12/107,198 US10719808A US2009260585A1 US 20090260585 A1 US20090260585 A1 US 20090260585A1 US 10719808 A US10719808 A US 10719808A US 2009260585 A1 US2009260585 A1 US 2009260585A1
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United States
Prior art keywords
exhaust gas
steam
furnace
operating conditions
feedwater
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Abandoned
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US12/107,198
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English (en)
Inventor
Horst Hack
Andrew Seltzer
Zhen Fan
Archibald Robertson
Timo Eriksson
Ossi Sippu
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Foster Wheeler Energy Corp
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Foster Wheeler Energy Corp
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Priority to US12/107,198 priority Critical patent/US20090260585A1/en
Assigned to FOSTER WHEELER ENERGY CORPORATION reassignment FOSTER WHEELER ENERGY CORPORATION ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: SIPPU, OSSI, ERIKSSON, TIMO, FAN, ZHEN, HACK, HORST, ROBERTSON, ARCHIBALD, SELTZER, ANDREW
Priority to PCT/IB2009/051624 priority patent/WO2009130660A2/en
Priority to AT09735086T priority patent/ATE533924T1/de
Priority to EP09735086A priority patent/EP2300692B1/de
Priority to RU2010147356/06A priority patent/RU2010147356A/ru
Priority to JP2011505630A priority patent/JP2011523449A/ja
Priority to KR1020107025949A priority patent/KR20110010731A/ko
Priority to CN2009801142844A priority patent/CN102016241A/zh
Priority to PL09735086T priority patent/PL2300692T3/pl
Priority to AU2009239601A priority patent/AU2009239601B2/en
Priority to ES09735086T priority patent/ES2377909T3/es
Publication of US20090260585A1 publication Critical patent/US20090260585A1/en
Assigned to BNP PARIBAS, AS ADMINISTRATIVE AGENT reassignment BNP PARIBAS, AS ADMINISTRATIVE AGENT SECURITY AGREEMENT Assignors: FOSTER WHEELER AG, FOSTER WHEELER BIOKINETICS, INC., FOSTER WHEELER DEVELOPMENT CORPORATION, FOSTER WHEELER ENERGY CORPORATION, FOSTER WHEELER HOLDINGS LTD., FOSTER WHEELER INC., FOSTER WHEELER INTERNATIONAL CORPORATION, FOSTER WHEELER LLC, FOSTER WHEELER LTD., FOSTER WHEELER NORTH AMERICA CORP., FOSTER WHEELER USA CORPORATION
Priority to ZA2010/07795A priority patent/ZA201007795B/en
Assigned to FOSTER WHEELER ENERGY CORPORATION reassignment FOSTER WHEELER ENERGY CORPORATION RELEASE OF PATENT SECURITY INTEREST RECORDED AT R/F 024892/0836 Assignors: BNP PARIBAS, AS ADMINISTRATIVE AGENT
Abandoned legal-status Critical Current

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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
    • F22B1/00—Methods of steam generation characterised by form of heating method
    • F22B1/02—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K13/00—General layout or general methods of operation of complete plants
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K7/00—Steam engine plants characterised by the use of specific types of engine; Plants or engines characterised by their use of special steam systems, cycles or processes; Control means specially adapted for such systems, cycles or processes; Use of withdrawn or exhaust steam for feed-water heating
    • F01K7/16—Steam engine plants characterised by the use of specific types of engine; Plants or engines characterised by their use of special steam systems, cycles or processes; Control means specially adapted for such systems, cycles or processes; Use of withdrawn or exhaust steam for feed-water heating the engines being only of turbine type
    • F01K7/22—Steam engine plants characterised by the use of specific types of engine; Plants or engines characterised by their use of special steam systems, cycles or processes; Control means specially adapted for such systems, cycles or processes; Use of withdrawn or exhaust steam for feed-water heating the engines being only of turbine type the turbines having inter-stage steam heating
    • F01K7/24—Control or safety means specially adapted therefor
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K7/00—Steam engine plants characterised by the use of specific types of engine; Plants or engines characterised by their use of special steam systems, cycles or processes; Control means specially adapted for such systems, cycles or processes; Use of withdrawn or exhaust steam for feed-water heating
    • F01K7/34—Steam engine plants characterised by the use of specific types of engine; Plants or engines characterised by their use of special steam systems, cycles or processes; Control means specially adapted for such systems, cycles or processes; Use of withdrawn or exhaust steam for feed-water heating the engines being of extraction or non-condensing type; Use of steam for feed-water heating
    • F01K7/38—Steam engine plants characterised by the use of specific types of engine; Plants or engines characterised by their use of special steam systems, cycles or processes; Control means specially adapted for such systems, cycles or processes; Use of withdrawn or exhaust steam for feed-water heating the engines being of extraction or non-condensing type; Use of steam for feed-water heating the engines being of turbine type
    • 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
    • Y02E20/12—Heat utilisation in combustion or incineration of waste
    • 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
    • Y02E20/34—Indirect CO2mitigation, i.e. by acting on non CO2directly related matters of the process, e.g. pre-heating or heat recovery

Definitions

  • the present invention relates to an oxyfuel combusting boiler system and a method of generating power by using the boiler system.
  • the invention relates especially to a dual-firing boiler system, i.e., a boiler system which can be operated by using either air or a mixture of substantially pure oxygen and recycled exhaust gas as the oxidant gas, i.e., as the oxygen carrier gas.
  • Oxyfuel combustion is one of the methods suggested for removing CO 2 from the exhaust gases of a power generating boiler, such as a pulverized coal (PC) boiler or a circulating fluidized bed (CFB) boiler.
  • Oxyfuel combustion is based on combusting carbonaceous fuel with substantially pure oxygen, typically, of about 95% purity, so as to have carbon dioxide and water as the main components of the exhaust gas discharged from the boiler. Thereby, the carbon dioxide can be captured relatively easily from the exhaust gas, without having to separate it from a gas stream having nitrogen as its main component, as when combusting the fuel with air.
  • Generating power by oxyfuel combustion is more complicated than conventional combustion by air, because of the need of an oxygen supply, for example, a cryogenic or membrane based air separation unit (ASU), where oxygen is separated from other components of air, mainly, nitrogen.
  • ASU cryogenic or membrane based air separation unit
  • the produced exhaust gas is then ready for sequestration of CO 2 when water is removed therefrom and, possibly, the exhaust gas is purified in order to reduce inert gases originating from the oxidant, fuel or air-leakage.
  • This purification is typically done by CO 2 condensation at a low temperature and/or a high pressure.
  • CO 2 can be separated from the exhaust gas, for example, by cooling to a relatively low temperature, while compressing it to a pressure greater than 110 bar.
  • Both the production of oxygen and the compression and purification of carbon dioxide increase the total production costs of the power generation process, for example, by decreasing the net power produced in the process.
  • Combustion using oxygen differs from combustion using air, mainly by having a higher combustion temperature and a smaller combustion volume. Because oxyfuel combustion is still a developing technology, it is considered to be advantageous to design so-called first generation oxyfuel combustion boilers, where the combustion conditions are arranged to be close to those of air-firing combustion. This can be done by recycling exhaust gas back to the furnace, so as to provide an average O 2 content of the oxidant of, for example, 20-28%. Such first-generation oxyfuel combustion boilers can advantageously be built by modifying existing air-firing boilers.
  • dual-firing boilers i.e., boilers which can be changed from air-firing to oxyfuel combustion and back, as easily as possible, and preferably, without any changes in the actual construction.
  • dual-firing boiler it is also possible to have a maximum power output, by using air-firing combustion, during high load demand, such as in the summer or during the daytime, and to apply oxyfuel combustion with CO 2 removal in other conditions.
  • air-firing boiler in an air-firing mode, for example, when the air separation unit or CO 2 sequestration unit is out of order.
  • U.S. Pat. No. 6,418,865 discloses a boiler for combusting fuel with oxygen-enriched air, which boiler can be made by retrofitting an air-firing boiler, wherein flue gas is re-circulated to the furnace so as to have a flame temperature and total mass flow approximately the same as that for combustion with air.
  • Patent publication number WO 2006/131283 discloses a retrofitted dual firing boiler, where fresh air exiting an air heater is either conveyed directly, in the air-firing mode, to the combustion chamber, or it is, in the oxyfuel combustion mode, cooled by feedwater of the boiler, compressed by utilizing steam extracted from a high pressure steam turbine and conveyed to an air separator unit for producing oxygen.
  • the net power generated in the CO 2 capturing oxyfuel combustion mode of the process disclosed in WO 2006/131283 is considerably reduced from that of the air-firing mode.
  • An object of the present invention is to provide an oxyfuel combusting boiler system and a method of using the boiler system, so as to minimize the loss of produced power.
  • the present invention provides a method of generating power by combusting carbonaceous fuel with an oxidant gas in a furnace of a boiler system, the method comprising the steps of feeding carbonaceous fuel into the furnace at a fuel feeding rate, feeding oxidant gas into the furnace for combusting the fuel to produce exhaust gas, discharging the exhaust gas from the furnace via an exhaust gas channel, conveying a stream of feedwater at a feedwater conveying rate from a final economizer arranged in the exhaust gas channel to evaporating and superheating heat exchange surfaces arranged in the furnace and in the exhaust gas channel, for converting the feedwater to superheated steam, expanding the superheated steam in a high-pressure steam turbine for generating power, extracting a first portion of steam from the high-pressure steam turbine for preheating the feedwater, conveying a second portion of steam from the high-pressure steam turbine to reheating heat exchange surfaces arranged in the exhaust gas channel for generating reheated steam, and expanding the reheated steam in an intermediate
  • the present invention provides a boiler system for generating power by combusting carbonaceous fuel in a furnace of the boiler system, the boiler system comprising means for feeding carbonaceous fuel into the furnace, means for feeding substantially pure oxygen and recycled exhaust gas as an oxidant gas into the furnace for combusting the fuel to produce exhaust gas, an exhaust gas channel for discharging the exhaust gas from the furnace, means for conveying a stream of feedwater from a final economizer arranged in the exhaust gas channel to evaporating and superheating heat exchange surfaces arranged in the furnace and in the exhaust gas channel, for converting the feedwater to superheated steam, a high-pressure steam turbine for expanding the superheated steam for generating power, means for extracting a first portion of steam from the high-pressure steam turbine for preheating the feedwater, means for conveying a second portion of steam from the high-pressure steam turbine to reheating heat exchange surfaces arranged in the exhaust gas channel for generating reheated steam, an intermediate-pressure steam turbine for expanding the reheated steam
  • the decreasing amount of steam extracted from the high-pressure steam turbine for preheating the feedwater naturally lowers the temperature of the feedwater entering a final economizer in the exhaust gas channel.
  • the decreasing of this steam extraction increases the temperature difference between the feedwater and the exhaust gas in the final economizer.
  • the decreasing of the steam extraction indirectly increases the rate of heat exchange taking place in the final economizer.
  • the increasing of the amount of steam conveyed from the high-pressure steam turbine to the reheating heat exchange surfaces increases the heat exchange rate taking place at the reheating surfaces.
  • the fuel feeding rate and the feedwater conveying rate are advantageously adjusted so as to obtain a desired furnace temperature.
  • This together with the above-discussed method for controlling the temperature of the exhaust gas, provides an efficient method of adjusting the temperature profile of an oxyfuel combustion boiler retrofitted from an air-firing boiler, to be nearly the same as that of the air-firing combustion, and to avoid, e.g., corrosion or material strength problems of the boiler walls.
  • the fuel feeding rate at full load is when modifying an air-firing boiler for oxyfuel combustion, increased by 20% and, correspondingly, the feedwater conveying rate is at the same time increased by 10%.
  • the oxyfuel combustion boiler is a dual-firing boiler, i.e., an oxyfuel combusting boiler, which can, in special operating conditions, for example, when the oxygen supply is not operational, be used for combustion with air.
  • the fuel feeding rate in the first operating conditions is advantageously higher than that in the second operating conditions.
  • the fuel feeding rate in oxyfuel combustion is preferably at least 10% higher, even more preferably, at least 15% higher, than that in the air-firing combustion. Due to the higher fuel feeding rate, the total firing rate of the boiler is increased, and the loss of produced power is minimized.
  • the use of an increased fuel feeing rate in the oxyfuel combustion, while still maintaining the furnace temperature, is advantageously partly based on the increased heat exchange in the evaporation surfaces, due to decreased temperature, and possibly, also increased flow rate, of the feedwater.
  • the feedwater temperature can advantageously be lowered, especially before the final economizer, but to some extent, also after the final economizer, in oxyfuel combustion, by decreasing the extraction of steam for preheating the feedwater from that in air-firing combustion.
  • the furnace temperature is naturally, also to a large extent, determined by the exhaust gas cycling rate, which affects both the rate of feeding relatively cold inlet gas to the furnace and the rate of convective heat flow, by the exhaust gas, from the furnace.
  • the exhaust gas recycling rate may, in the oxyfuel combustion mode, advantageously be determined such that the average oxygen content, by volume, of the oxidant gas is at a desired level, typically, from about 18% to about 28%.
  • the exhaust gas recycling rate in the oxyfuel combustion mode may alternatively be determined so as to maintain a desired gas flow velocity, usually, the same as that in air-firing combustion, in the furnace.
  • the increased convective heat flow from the furnace is partially based on the fact that the mass and heat capacity of the exhaust gas of oxyfuel combustion, having carbon dioxide as its main component, are larger than those of the exhaust gas of air-firing combustion, having nitrogen as its main component.
  • the high heat flow brings about that the exhaust gas carries an increased amount of heat to the exhaust gas channel, where the heat is advantageously recovered by an increased heat exchange rate in the reheating surfaces and the final economizer, as discussed above.
  • the system comprises a gas-gas heat exchanger, where heat is transferred from the exhaust gas in the exhaust gas channel to at least a portion of the oxidant gas.
  • the same gas-gas heat exchanger is advantageously used in air-firing combustion to transfer heat from the exhaust gas to the combustion air, and in oxyfuel combustion to transfer heat from the exhaust gas to at least a portion of the oxidant gas.
  • the substantially pure oxygen is advantageously produced in an air separation unit (ASU), for example, a cryogenic or membrane based air separation unit.
  • ASU air separation unit
  • a portion of the exhaust gas is advantageously cooled and pressurized in multiple exhaust gas compressors, so as to sequestrate liquid or supercritical carbon dioxide. Due to this auxiliary equipment, the net power produced by an oxyfuel combusting boiler tends to be considerably less than that of a corresponding air-firing boiler.
  • at least a portion of the exhaust compressors is directly driven by mechanical energy of auxiliary steam turbines using steam extracted from the steam turbine system. This steam is advantageously generated by firing more and saved from reducing the extraction of steam used for feedwater heating.
  • the need for auxiliary power for the compression of carbon dioxide is minimized.
  • the oxygen supply comprises a cryogenic air separation unit having compressors for pressurizing air
  • one or more of these compressors can also be driven directly by the auxiliary steam turbines, so as to further decrease the need for auxiliary power.
  • the substantially pure oxygen and recycled exhaust gas can be fed to the boiler as separate streams, or as a mixture of the two streams. It is also possible to feed to the boiler multiple streams, which can be identical mixture streams, or streams having different temperatures or compositions.
  • the multiple streams can naturally have different purposes in the furnace, such as primary, secondary and overfire gas streams of a PC boiler, or streams of fluidizing gas and secondary gas of a CFB boiler.
  • the feeding rate of oxygen is always, in practice, determined on the basis of the fuel feeding rate, so as to provide sufficiently complete combustion of the fuel.
  • the oxygen feeding rate is controlled by monitoring the content of residual oxygen in the exhaust gas, which should stay at a suitable level, typically, about 3%.
  • an advantage of an oxycombustion power generation process in accordance with the present invention is that it can be taken to use relatively easily, by retrofitting an conventional air-firing boiler, such as a PC boiler or a CFB boiler.
  • the modification mainly comprises the implementation of an oxygen supply, such as a cryogenic air separation unit, equipment for carbon dioxide sequestration, means for extensive exhaust gas recycling and means for controlling the ratio of the steam flows from the high-pressure steam turbine to the feedwater preheaters and reheater surfaces.
  • the modification may also require the use of updated steam turbines and a steam condenser, as well as increased heat exchange surfaces in the upstream portion of the exhaust gas channel.
  • the same combustion system can be used in oxyfuel combustion and in air-firing combustion, thus enabling the use of the system as a dual-firing steam generator.
  • FIG. 1 is a schematic diagram of an oxy-fuel combusting power plant in accordance with the present invention.
  • FIG. 1 shows a schematic diagram of an oxycombustion boiler system 10 in accordance with a preferred embodiment of the present invention.
  • the boiler system 10 comprises a boiler 12 , which may be, for example, a pulverized coal (PC) boiler or a circulating fluidized bed (CFB) boiler.
  • the boiler 12 comprises conventional fuel feeding means 16 , such as a fuel supply pipe means for introducing oxidant gas into the furnace 14 of the boiler, such as a gas supply line 18 , and an exhaust gas channel 20 for discharging exhaust gas produced by combusting the fuel with the oxygen of the oxidant gas.
  • the details and types of some elements of the boiler 12 such as the fuel feeding means 16 and oxidant gas feeding means 18 , depend, naturally, on the type of the boiler. Such details, for example, burners, coal mills, means for separately feeding primary and secondary oxidant gas, are, however, not important for the present invention, and they are thus not shown in FIG. 1 .
  • the oxycombustion boiler system 10 is advantageously retrofitted from an existing air-firing boiler, mainly by adding equipment 24 for purifying and sequestering carbon dioxide from the exhaust gas, and an oxygen supply 26 , such as a cryogenic or membrane-based air separation unit (ASU), for producing substantially pure oxygen from an air stream 28 .
  • an oxygen supply 26 such as a cryogenic or membrane-based air separation unit (ASU)
  • the boiler system 10 is preferably designed so as to maintain the temperature profiles in the furnace and the exhaust gas channel to be close to those of an original air firing boiler.
  • the boiler system 10 is designed as a dual-firing boiler, i.e., a boiler which can be easily switched between oxyfuel combustions and air-firing combustion.
  • the system is designed so as to have the loss of produced net power in the oxycombustion mode be as low as possible.
  • the oxidant gas, introduced from gas supply line 18 into the furnace 14 is in normal operating conditions, so-called first operating conditions, and includes a mixture of substantially pure oxygen and a portion of cooled exhaust gas, which is recycled via an exhaust gas recycling channel 30 .
  • the exhaust gas recycling channel 30 advantageously comprises means, such as a fan (not shown in FIG. 1 ), for controlling the exhaust gas recycling rate.
  • the recycling rate of the exhaust gas is advantageously adjusted such that the average oxygen content of the oxidant gas is close to that of air, preferably, from 18% to 28%.
  • the walls of the furnace 14 are preferably formed as a tube-wall construction, which forms an evaporating heat transfer surface 32 , for converting preheated feedwater to steam.
  • the high temperature portions of the boiler 12 especially, the upstream end of the exhaust gas channel 20 , comprise superheating heat transfer surfaces 34 for recovering heat from the exhaust gas to produce superheated steam to be conveyed to the inlet of a high-pressure steam turbine 36 for generating power in a generator 38 .
  • Expanded steam in line 42 is conveyed from the outlet side of the high-pressure steam turbine 36 to reheating heat transfer surfaces 40 for recovering further heat from the exhaust gas.
  • primary superheating and reheating surfaces may be located in the exhaust gas channel 20 and additional finishing superheating and reheating surfaces, for example in the furnace 14 .
  • Another portion of steam from the high-pressure turbine 36 may be converted through line 42 to a feedwater heater 44 .
  • Reheated steam is conveyed from the reheating heat exchange surfaces 40 the feedwater heater 44 to the inlet of an intermediate-pressure steam turbine 46 for generating power.
  • the intermediate-pressure steam turbine 46 may comprise a line 48 for extracting steam from the steam turbine 46 for other purposes, advantageously, for generating mechanical power in an auxiliary steam turbine for driving compressors in the air separation unit 26 or carbon dioxide purification and sequestration unit 24 .
  • the steam turbine system also usually comprises at least a low-pressure steam turbine, which is, however, not shown in FIG. 1 .
  • the steam cycle of the boiler 12 comprises, in a conventional manner, a condenser 50 downstream of the intermediate-pressure steam turbine 46 .
  • the condensed steam i.e., feedwater of the next steam cycle, is conducted from the condenser 50 for preheating in an economizer system typically comprising at least a first economizer 52 and a final economizer 54 , to be again converted to steam in the evaporation surfaces 32 .
  • Additional feedwater heating may be performed in the feedwater heater 40 by steam extracted from the high-pressure steam turbine 36 .
  • the exhaust gas temperature is controlled in oxyfuel combustion by adjusting the rate of extracting intermediate-pressure steam from the high-pressure steam turbine 36 to the feedwater preheater 44 , by means 56 , such as a regulation valve, arranged in the steam line 42 .
  • the rate of extracting intermediate-pressure steam from the high-pressure steam turbine 36 to the feedwater preheater 44 by means 56 , such as a regulation valve, arranged in the steam line 42 .
  • the controlling of the exhaust gas temperature may advantageously be based on measuring the temperature of the exhaust gas downstream of the final economizer 54 by a thermometer 58 .
  • the loss of produced net power is minimized by arranging the conditions such that more fuel can be fired while still maintaining the temperatures in the furnace 14 and in the exhaust gas channel 20 .
  • the temperature in the furnace 14 can be maintained by adjusting the exhaust gas recycling rate to a suitable level and by controlling the temperature and flow rate of the feedwater.
  • the temperature in the furnace 14 can typically still be adjusted to its desired level by the measures discussed above. Due to the increased mass flow and high heat capacity of the exhaust gas, consisting mainly of carbon dioxide, the convective heat, carried by the exhaust gas, is increased, even if the temperature in the furnace 14 is unchanged. This additional heat can then be recovered by decreasing the extraction of steam for feedwater preheating, by the means 56 , and increasing the reheating rate, as discussed above, as well as by increasing feedwater flow due to increased main steam generation.
  • a recuperative or regenerative gas-gas heat exchanger 60 is advantageously arranged in the exhaust gas channel, downstream of the final economizer 54 .
  • a gas-gas heat exchanger 60 can be of a recuperative or regenerative type, for transferring heat from the exhaust gas to the oxidant gas of the boiler 12 .
  • the exhaust gas channel 20 also usually comprises different units for cleaning the exhaust gas from particles and gaseous pollutants, but because they are not important for the present invention, such units are not shown in FIG. 1 .
  • the end portion of the exhaust gas channel 20 is equipped with means 24 , such as a separator, to produce liquid or supercritical carbon dioxide, typically, at a pressure of about 110 bar, so that it can be transported for further use or to be stored in a suitable place.
  • the carbon dioxide purification and sequestration system also usually comprises means for completely drying all water from the exhaust gas, and means for separating oxygen, and other possible impurities, from the carbon dioxide, which are, however, not shown in FIG. 1 . Such means for drying and means for separating are individually known in the art.
  • the water content of the recycled exhaust gas is advantageously lowered before the exhaust gas is recycled to the furnace 14 . Therefore, the exhaust gas recycling line 30 is advantageously branched off from the exhaust gas channel 20 downstream of the first economizer 52 , which functions as a condensing cooler of the exhaust gas. Thereby, the water content of the recycled gas is reduced, also causing a reduction of the water content in the furnace 14 and in the exhaust gas discharged from the furnace 14 . Because the O 2 content of the exhaust gas has to be maintained at a suitable level, at about 3% by volume, in order to guarantee sufficiently complete combustion of the fuel, the reducing of the water content reduces the O 2 /CO 2 ratio in the exhaust gas. Alternatively, the condensing cooler can be downstream of the branch point of the recycled exhaust gas.
  • the oxyfuel combustion system shown in FIG. 1 can be constructed relatively easily by retrofitting an existing air-firing boiler.
  • the boiler system can also be used as a dual firing boiler, which can be switched between oxyfuel combustion and air-firing combustion, without any physical modification of the system. This is achieved by arranging means 62 , such as an air inlet supply line, for introducing fresh air as the oxidant gas, to replace the mixture of oxygen and recycled exhaust gas, and a stack 64 for releasing the exhaust gas to the environment.
  • air inlet 62 is arranged in the recycling gas channel 30 , in such a way that the gas-gas heater 60 can be used alternatively as an air heater.
  • the temperature profiles in the furnace 14 and in the exhaust channel 20 can be adjusted to their desired values by adjusting the fuel feeding rate and steam reheating rate to suitable values, by using the principles discussed above.
US12/107,198 2008-04-22 2008-04-22 Oxyfuel Combusting Boiler System and a Method of Generating Power By Using the Boiler System Abandoned US20090260585A1 (en)

Priority Applications (12)

Application Number Priority Date Filing Date Title
US12/107,198 US20090260585A1 (en) 2008-04-22 2008-04-22 Oxyfuel Combusting Boiler System and a Method of Generating Power By Using the Boiler System
ES09735086T ES2377909T3 (es) 2008-04-22 2009-04-21 Sistema de caldera de combustión oxi-gas y procedimiento de generación de energía con el uso de dicho sistema
KR1020107025949A KR20110010731A (ko) 2008-04-22 2009-04-21 순산소 연소 보일러 시스템과 상기 보일러 시스템을 사용하여 전력을 생산하는 방법
PL09735086T PL2300692T3 (pl) 2008-04-22 2009-04-21 System kotła spalania tlenowo-paliwowego oraz metoda wytwarzania mocy przy użyciu systemu kotła
EP09735086A EP2300692B1 (de) 2008-04-22 2009-04-21 Oxyfuel-verbrennungskesselsystem und verfahren zur erzeugung von energie durch verwendung des kesselsystems
RU2010147356/06A RU2010147356A (ru) 2008-04-22 2009-04-21 Котельная система с кислородно-топливным сжиганием и способ генерирования энергии посредством использования котельной системы
JP2011505630A JP2011523449A (ja) 2008-04-22 2009-04-21 酸素燃焼ボイラ・システム及びこのボイラ・システムを使用して発電する方法
PCT/IB2009/051624 WO2009130660A2 (en) 2008-04-22 2009-04-21 Oxyfuel combusting boiler system and a method of generating power by using the boiler system
CN2009801142844A CN102016241A (zh) 2008-04-22 2009-04-21 氧燃料燃烧锅炉系统和使用所述锅炉系统产生动力的方法
AT09735086T ATE533924T1 (de) 2008-04-22 2009-04-21 Oxyfuel-verbrennungskesselsystem und verfahren zur erzeugung von energie durch verwendung des kesselsystems
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ES2377909T3 (es) 2012-04-03
EP2300692A2 (de) 2011-03-30
ATE533924T1 (de) 2011-12-15
CN102016241A (zh) 2011-04-13
AU2009239601B2 (en) 2011-11-17
AU2009239601A1 (en) 2009-10-29
JP2011523449A (ja) 2011-08-11
PL2300692T3 (pl) 2012-07-31
WO2009130660A3 (en) 2010-12-23
EP2300692B1 (de) 2011-11-16
ZA201007795B (en) 2011-07-27
KR20110010731A (ko) 2011-02-07
WO2009130660A2 (en) 2009-10-29

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