US20090277363A1 - Oxyfuel Boiler System and Method of Retrofit of Air Fired Boiler to Oxyfuel Boiler - Google Patents

Oxyfuel Boiler System and Method of Retrofit of Air Fired Boiler to Oxyfuel Boiler Download PDF

Info

Publication number
US20090277363A1
US20090277363A1 US12/435,858 US43585809A US2009277363A1 US 20090277363 A1 US20090277363 A1 US 20090277363A1 US 43585809 A US43585809 A US 43585809A US 2009277363 A1 US2009277363 A1 US 2009277363A1
Authority
US
United States
Prior art keywords
exhaust gas
boiler
oxygen
coal
burner
Prior art date
Legal status (The legal status 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 status listed.)
Abandoned
Application number
US12/435,858
Other languages
English (en)
Inventor
Tsuyoshi Shibata
Masayuki Taniguchi
Hisayuki Orita
Osamu Ito
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Hitachi Ltd
Original Assignee
Hitachi Ltd
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 Hitachi Ltd filed Critical Hitachi Ltd
Assigned to HITACHI, LTD. reassignment HITACHI, LTD. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: ITO, OSAMU, ORITA, HISAYUKI, SHIBATA, TSUYOSHI, TANIGUCHI, MASAYUKI
Publication of US20090277363A1 publication Critical patent/US20090277363A1/en
Abandoned legal-status Critical Current

Links

Images

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J15/00—Arrangements of devices for treating smoke or fumes
    • F23J15/006—Layout of treatment plant
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23C—METHODS OR APPARATUS FOR COMBUSTION USING FLUID FUEL OR SOLID FUEL SUSPENDED IN  A CARRIER GAS OR AIR 
    • F23C9/00—Combustion apparatus characterised by arrangements for returning combustion products or flue gases to the combustion chamber
    • F23C9/003—Combustion apparatus characterised by arrangements for returning combustion products or flue gases to the combustion chamber for pulverulent fuel
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J15/00—Arrangements of devices for treating smoke or fumes
    • F23J15/02—Arrangements of devices for treating smoke or fumes of purifiers, e.g. for removing noxious material
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23L—SUPPLYING AIR OR NON-COMBUSTIBLE LIQUIDS OR GASES TO COMBUSTION APPARATUS IN GENERAL ; VALVES OR DAMPERS SPECIALLY ADAPTED FOR CONTROLLING AIR SUPPLY OR DRAUGHT IN COMBUSTION APPARATUS; INDUCING DRAUGHT IN COMBUSTION APPARATUS; TOPS FOR CHIMNEYS OR VENTILATING SHAFTS; TERMINALS FOR FLUES
    • F23L7/00—Supplying non-combustible liquids or gases, other than air, to the fire, e.g. oxygen, steam
    • F23L7/007—Supplying oxygen or oxygen-enriched air
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J2215/00—Preventing emissions
    • F23J2215/20—Sulfur; Compounds thereof
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J2215/00—Preventing emissions
    • F23J2215/50—Carbon dioxide
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23J—REMOVAL OR TREATMENT OF COMBUSTION PRODUCTS OR COMBUSTION RESIDUES; FLUES 
    • F23J2900/00—Special arrangements for conducting or purifying combustion fumes; Treatment of fumes or ashes
    • F23J2900/15061—Deep cooling or freezing of flue gas rich of CO2 to deliver CO2-free emissions, or to deliver liquid CO2
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23L—SUPPLYING AIR OR NON-COMBUSTIBLE LIQUIDS OR GASES TO COMBUSTION APPARATUS IN GENERAL ; VALVES OR DAMPERS SPECIALLY ADAPTED FOR CONTROLLING AIR SUPPLY OR DRAUGHT IN COMBUSTION APPARATUS; INDUCING DRAUGHT IN COMBUSTION APPARATUS; TOPS FOR CHIMNEYS OR VENTILATING SHAFTS; TERMINALS FOR FLUES
    • F23L2900/00—Special arrangements for supplying or treating air or oxidant for combustion; Injecting inert gas, water or steam into the combustion chamber
    • F23L2900/07001—Injecting synthetic air, i.e. a combustion supporting mixture made of pure oxygen and an inert gas, e.g. nitrogen or recycled fumes
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
    • Y02C20/00—Capture or disposal of greenhouse gases
    • Y02C20/40—Capture or disposal of greenhouse gases of CO2
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E20/00—Combustion technologies with mitigation potential
    • Y02E20/32—Direct CO2 mitigation
    • 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 boiler system, a method for retrofitting a pulverized coal firing boiler, a control apparatus of an oxyfuel boiler system and a method for controlling an oxyfuel boiler system.
  • Coal firing power generation system configured with a pulverized coal firing boiler and a steam turbine electric generator is considered to play a significant role in future energy supply, given the recent years' energy price increases resulting from oil supply shortages and an increasing reliance on natural gas.
  • coal firing system has their own serious problem with a high CO 2 production rate compared to oil or natural gas firing system.
  • a problem as high CO 2 production must be definitely solved in view of the suppression of the advancement of global warming.
  • Typical coal firing boiler uses air as the oxidizer.
  • a large part of the exhaust gas is extracted from the exhaust gas discharge line, then mixed with high purity oxygen produced at the oxygen generator to provide a desired oxygen concentration, and supplied to the boiler as the oxidizer.
  • the off-gas to be discharged into the environment from oxyfuel boiler plant can be reduced to about 1 ⁇ 4th of those of conventional plants.
  • the CO 2 concentration in the exhaust gas is greatly increased, and therefore CO 2 can be readily separated and collected from the exhaust gas.
  • the patent document 1 discloses an oxyfuel boiler system in which the exhaust gas is extracted from the boiler, mixed with oxygen produced at an oxygen separator, and supplied the mixture gas to the boiler as the oxidizer.
  • Patent Document 1 Japanese Application Patent Hei 5 (1993)-231609
  • the exhaust gas extracted from the boiler is cooled and liquefied in a cooler, thereby separating the liquefied CO 2 from the exhaust gas. Then, the liquefied CO 2 is revaporized, mixed with oxygen and recirculated to the boiler.
  • a problem here is that such liquefaction and revaporization imposes an undesired energy loss penalty.
  • Another problem is that, when the exhaust gas extracted from the boiler is recirculated without any treatments, sulfuric acid dew point corrosion occurs in the recirculation pipes.
  • An object of the present invention is to provide a simple system that can suppress sulfuric acid dew point corrosion in the piping of oxyfuel boiler system.
  • the present invention provides an oxyfuel boiler system, comprising: an oxygen generator to separate oxygen from air; a coal supply unit to dry and pulverize coal; a burner having a fuel feed path for feeding pulverized coal supplied from the coal supply unit and an oxidizer feed path for feeding oxidizer; a boiler provided with the burner; an exhaust gas discharge line to discharge exhaust gas generated in the boiler into environment; an exhaust gas treatment apparatus provided in the exhaust gas discharge line, a CO 2 separator provided in the exhaust gas discharge line downstream of the exhaust gas treatment apparatus to separate CO 2 from the exhaust gas; an exhaust gas recirculation line including an exhaust gas tapping port provided in the exhaust gas discharge line to extract a part of the exhaust gas; and an oxygen supply line to supply the oxygen generated at the oxygen generator to the exhaust gas flowing through the exhaust gas recirculation line,
  • the exhaust gas treatment apparatus is provided with at least an SO 3 removing unit and a moisture removing unit; and the exhaust gas tapping port of the exhaust gas recirculation line is disposed downstream of the exhaust gas treatment apparatus and upstream of the CO 2 separator for recirculating a part of the gas extracted from the port to the coal supply unit and/or the boiler.
  • FIG. 1 illustrates an oxyfuel boiler system according to one of the embodiment of the present invention.
  • FIG. 2 illustrates an oxyfuel boiler system according to one of the embodiment of the present invention.
  • FIG. 3 illustrates an oxyfuel boiler system according to one of the embodiment of the present invention.
  • FIG. 4 illustrates an oxyfuel boiler system according to one of the embodiment of the present invention.
  • FIG. 5 is a graph illustrating the relationship between the recirculated exhaust gas composition and sulfuric acid dew point.
  • FIG. 6 illustrates a control apparatus for use in an oxyfuel boiler system according to the present invention.
  • the present invention is particularly intended to solve the problem (4).
  • the amount of the exhaust gas generated in the boiler is less than 1 ⁇ 4th of those in air fired boilers, and therefore the velocity of the exhaust gas flowing through the heat transfer tube of the boiler is slower. This poses yet another problem because such slow velocity of exhaust gas degrades the thermal transfer efficiency and therefore the thermal recovery efficiency.
  • conventional oxyfuel boiler system employ a configuration in which a large amount of the exhaust gas is recirculated, mixed with oxygen, and then supplied to the boiler.
  • such conventional oxyfuel boiler system is designed so that the flow rate of the mixture gas (of the oxidizer supplied to the burner and the exhaust gas supplied to the boiler) is more than 70% of the flow rate of air in conventional air fired boiler. In this manner, high efficiency thermal recovery and electric power generation can be stably achieved without greatly modifying a conventional air fired boiler system.
  • the first problem concerns sulfuric acid dew point corrosion.
  • the conventional air fired boiler system is designed so that the internal temperatures of the system components located upstream of the desulfurization device never fall below the sulfuric acid dew point of the exhaust gas.
  • an exhaust gas containing SO 3 passes through the system components such as the recirculation pipes, recirculation fan, heat exchanger, coal supply unit and burner. Therefore, apparently, the oxyfuel boiler system also requires measures to prevent sulfuric acid dew point corrosion occurring at the system components and piping which are exposed to SO 3 .
  • the oxyfuel boiler system has their own specific problem.
  • the SO 3 and H 2 O concentrations in the recirculated exhaust gas of the oxyfuel boiler system are about four times as high as those in the exhaust gas of air fired boiler system, and as a result the sulfuric acid dew point of the recirculated exhaust gas of oxyfuel boiler system is about 40° C. higher than that of the exhaust gas of air fired boiler system.
  • This seriously increases the risk of sulfuric acid dew point corrosion in the oxyfuel boiler system; therefore some novel countermeasures need to be taken to address this problem.
  • Particularly important is anti-corrosion protection for the coal supply unit of a system and the piping extending downstream therefrom to the burner, because the temperature of the recirculated exhaust gas is most likely dropping during passage through those system components.
  • the second problem relates to degradation in the coal drying capability.
  • heated high temperature air is supplied to pulverized coal in the coal supply unit, thereby drying, before burning, a large amount of water adsorbed to the pulverized coal. If the drying is insufficient, the adhered water removes a large quantity of latent heat during vaporization when the coal is ignited by the burner, thereby degrading the ignition performance and resulting in firing instability.
  • This problem is worse for the oxyfuel boiler system because the H 2 O concentration in the recirculated exhaust gas in the air fired boiler system is as high as about 30%.
  • the third problem relates to increased NO x production. It is generally known that, in the oxyfuel boiler system, the N 2 concentration in the exhaust gas is very low; therefore the thermal NO x generation (and therefore the NO x generation per unit heat generation) is very low compared to those in the conventional boiler. So, in order to further reduce the NO x conversion ratio in the oxyfuel boiler system, some method is needed that can suppress the amount of fuel NO x formed by the oxidization of nitrogen in the fuel. However, the following fact has been found: As pointed out in the descriptions of the first and second problems, the H 2 O concentration in the recirculated exhaust gas in the oxyfuel boiler system is as high as about 30%. As a result, the oxidization of nitrogen in the firing flame is accelerated, thus increasing the fuel NO x formation ratio.
  • FIG. 1 illustrates an oxyfuel boiler system according to an embodiment of the present invention.
  • Fuel coal is transported, via a coal transfer device (not shown), to a coal mill 11 (serving as a coal supply unit) and is pulverized to a particle size suitable for pulverized coal firing.
  • the pulverized coal is carried by recirculated gas that is also supplied to the coal mill 11 , and is sent to a fuel feed path for a burner 12 through a coal supply pipe 19 .
  • the burner 12 is provided with the fuel feed path for feeding fuel to a boiler furnace and an oxidizer feed path for feeding an oxidizer.
  • An oxygen supply pipe 16 is connected to a location along the coal supply pipe 19 , where oxygen is mixed as needed.
  • One end of the oxygen supply pipe 16 is connected to an oxygen generator 10 , and the other end branches out to be connected to an exhaust gas recirculation pipe 14 and the coal supply pipe 19 .
  • Oxygen is separated from air at the oxygen generator 10 , and is then supplied to the oxygen supply pipe 16 .
  • Gas containing a large proportion of nitrogen generated in the oxygen generator 10 is exhausted through a nitrogen gas exhaust pipe 15 and a discharge stack 9 .
  • the oxyfuel boiler system in FIG. 1 has an exhaust gas recirculation line including: an exhaust gas tapping port 22 provided in the exhaust gas discharge line; and the exhaust gas recirculation pipe 14 extracting a part of the exhaust gas.
  • the recirculation pipe 14 splits into two branches, one of which is connected to the coal mill 11 .
  • the other branch of the recirculation pipe 14 is connected to the oxidizer feed path of the burner 12 , from which a mixture gas of the recirculated exhaust gas and the oxygen supplied through the oxygen supply pipe 16 is fed into the burner.
  • the mixture gas and the coal supplied through the coal supply pipe 19 are fed into the burner 12 and then into a boiler 1 where a flame is formed.
  • the recirculation pipe 14 is connected to an after-gas port 13 which is located in the boiler downstream of the burner 12 , and the mixture gas is also fed into the boiler 1 independently of the oxidizer feed path of the burner 12 .
  • the after-gas port 13 has a function similar to that of the after-air port of air fired boiler. That is, by properly regulating the amounts of the mixture gases supplied to the burner 12 and the after-gas port 13 , a reductive atmosphere region is formed in the boiler 1 , thus preventing nitrogen in the fuel coal from being converted into NO x . Also, the mixture gas jet exiting from the after-gas port 13 can promote gas mixing in the boiler 1 and reduce unburned coal.
  • the flow rates of the recirculated exhaust gases supplied to the coal mill 11 , burner 12 and after-gas port 13 are each regulated by a flow rate regulator (not shown).
  • the oxygen flow rate through each branch of the oxygen supply pipe 16 is also regulated by a flow rate regulator (not shown).
  • the oxygen concentration of the mixture gas supplied from each of the burner 12 and after-gas port 13 to the boiler 1 may be independently controlled. That is, the oxygen supply pipe 16 is further split into two branches respectively to the burner 12 and the after-gas port 13 , and the flow rate through each branch is independently regulated. And, the two branches of the oxygen supply pipe 16 are respectively connected to the two branches of the recirculation pipe 14 (one for the burner 12 and the other for the after-gas port 13 ).
  • Such independent regulation of the flow rate and oxygen concentration of the mixture gas supplied to each of the burner 12 and the after-gas port 13 is advantageous because the formation of the reductive atmosphere region in the boiler 1 and the amount of unburned coal can be more accurately controlled.
  • Heat generated in the boiler 1 is used to produce high-temperature, high-pressure steam, which is then supplied to a steam turbine electric generator (not shown) to generate electricity.
  • Exhaust gas generated in the boiler 1 is discharged through an exhaust gas discharge line 20 and enters a NO x removing unit 2 in order to reduce the NO x content in the exhaust gas.
  • the NO x removing unit 2 may be omitted when NO x generation in the boiler 1 can be sufficiently reduced by an improved combustion method or other methods.
  • Exhaust gas exiting the NO x removing unit 2 then enters a heat exchanger 3 and the temperature of the exhaust gas is reduced. Heat extracted from the exhaust gas in the heat exchanger 3 is returned to the recirculated exhaust gas also passing through the heat exchanger 3 , then heated recirculated exhaust gas is supplied to the boiler 1 , thus suppressing the thermal efficiency degradation of the plant.
  • the exhaust gas exiting the NO x removing unit 2 then enters a dry dust removing unit 4 where more than 95% of the dust is removed, and then enters a wet desulfurization unit 5 where more than 95% of the SO 3 is removed.
  • the exhaust gas then enters a wet dust removing unit 6 (serving as an SO 3 removing apparatus) where more than 98% of the SO 3 is removed, and then enters a moisture removing cooler 7 (serving as a moisture removing apparatus) where the water content in the exhaust gas is reduced.
  • an exhaust gas tapping port is provided downstream of the SO 3 removing apparatus and the moisture removing apparatus, thereby removing SO 3 and moisture from the exhaust gas and recirculating them.
  • the recirculated exhaust gas contains only as low as less than 1 ppm of SO 3 and as low as less than 1% of moisture; therefore the sulfuric acid dew point can be substantially reduced compared to system without such SO 3 removing apparatus and moisture removing apparatus to the recirculated exhaust gas. Therefore, there is no need for costly anti-corrosion measures, such as the use of expensive corrosion resistant materials for the system components and piping, tight thermal insulation and the use of heaters.
  • the oxyfuel boiler system of the embodiment can be readily configured by reusing wet dust removing unit and moisture removing cooler normally employed in the existing coal firing boiler system in stead of providing new SO 3 removing apparatus and moisture removing apparatus.
  • possible corrosion at various system units (such as the recirculation pipe 14 , recirculation fan 21 , heat exchanger 3 , coal mill 11 and coal supply pipe 19 ) can be remarkably prevented with a simple system configuration employing existing apparatuses.
  • the SO 3 removing apparatus used in the embodiment is preferably a wet dust removing apparatus. This is because it is difficult for wet desulfurization apparatuses to remove SO 3 mist particles bonding to water molecules, while wet dust removing apparatuses are suitable for removal of such SO 3 mist.
  • FIG. 5 is a well known graph illustrating the change in sulfuric acid dew point as a function of SO 3 and water concentrations in exhaust gas.
  • the point labeled “A” in the figure represents the sulfuric acid dew point of an exhaust gas composition of a conventional air fired boiler.
  • the point labeled “B” represents the sulfuric acid dew point of a recirculated exhaust gas composition of an oxyfuel boiler system without treatments by SO 3 and moisture removing apparatuses.
  • the exhaust gas amount is about 30% less than those of air fired boiler systems.
  • recirculation of the exhaust gas causes the SO 3 and water concentrations to increase by a factor of 3 to 4 times.
  • the sulfuric acid dew point is about 40° C. higher those of exhaust gases in conventional air fired boiler system, thus seriously increasing the risk of sulfuric acid dew point corrosion.
  • the point labeled “C” represents the sulfuric acid dew point of the recirculated exhaust gas composition according to the present embodiment.
  • the sulfuric acid dew point of the point “C” is about 90° C. lower than that of the point “B”, and in addition, the SO 3 concentration can be suppressed to as low as about 1 ppm. Therefore, sulfuric acid dew point corrosion can be effectively prevented.
  • the exhaust gas is extracted, for recirculation, from the exhaust gas tapping port provided downstream of the moisture removing apparatus, and the thus extracted exhaust gas is also supplied to the coal supply unit.
  • the moisture concentration in the recirculation exhaust gas supplied to the coal supply unit can be reduced to levels comparable to the concentration levels of moisture in air supplied to the coal mill of conventional air fired boiler. Therefore, degradation in coal drying capability, which is a problem with conventional oxyfuel boiler system, can be suppressed without the need for additional devices or any special design.
  • the reduction in moisture concentration in the recirculated exhaust gas made according to the present embodiment has the effect of limiting formation of fuel NO x in the burning flame, which is advantageous in view of reducing harmful products in the off-gas to be discharged into the environment.
  • the unrecirculated part of the exhaust gas exiting the moisture removing cooler 7 enters a CO 2 liquefaction unit 8 (serving as a CO 2 separating apparatus), where CO 2 is liquefied and separated from the exhaust gas.
  • the separated CO 2 may be returned to consumers in the form of a high pressure gas without liquefying through a pipeline or the like.
  • the exhaust gas which remains unliquefied in the CO 2 liquefaction unit 8 is discharged as off-gas.
  • the off-gas contains nitrogen and oxygen as major components, and minor amounts of other components such as NO x and CO 2 .
  • the off-gas and a large amount of nitrogen generated at the oxygen generator 10 are mixed and discharged into the environment through the discharge stack 9 .
  • the exhaust gas tapping port is provided upstream of the CO 2 separating apparatus, the exhaust gas can be directly recirculated without any treatment. That is, liquefied CO 2 need not be revaporized for recirculation to the boiler, thus eliminating energy loss accompanying such revaporization.
  • the exhaust gas extracted from the exhaust gas tapping port is also supplied to the oxidizer feed path of the burner 12 and to the after-gas port 13 .
  • moisture is substantially removed from the exhaust gas supplied to the oxidizer feed path of the burner 12 and the after-gas port 13 , and hence NO x generation can be reduced to a greater extent.
  • the oxyfuel boiler system of the present embodiment can also be effectively achieved by retrofitting an existing pulverized coal firing boiler.
  • existing pulverized coal firing boiler includes: a coal supply unit that dries and pulverizes coal; a burner having a fuel feed path for feeding the coal supplied from the coal supply unit and an oxidizer feed path for feeding oxidizer; a boiler having the burner; an exhaust gas discharge line for discharging exhaust gas generated in the boiler into the environment; and an exhaust gas treatment apparatus provided in the exhaust gas discharge line.
  • the present embodiment is also effectively adaptable to such existing pulverized coal firing boiler by adding the exhaust gas recirculation line of the present embodiment, an oxygen generator, and a CO 2 separator.
  • the exhaust gas extracted from the exhaust gas tapping port 22 is directly recirculated to the boiler in a gaseous state rather than being once liquefied and then revaporized. Then, the exhaust gas flowing through the recirculation pipe 14 is heated in the heat exchanger 3 .
  • a heat exchanger normally employed in existing air fired boiler can be diverted to a heat exchanger necessary for the oxyfuel boiler, and therefore reductions in cost can be made.
  • an exhaust gas tapping port is provided downstream of the SO 3 removing apparatus and the moisture removing apparatus, thereby removing SO 3 and moisture from the exhaust gas and recirculating them.
  • the recirculated exhaust gas contains only as low as less than 1 ppm of SO 3 and as low as less than 1% of moisture; therefore the sulfuric acid dew point can be substantially reduced compared to system without such SO 3 removing apparatus and moisture removing apparatus to the recirculated exhaust gas.
  • the recirculated exhaust gas having a greatly lowered sulfuric acid dew point is heated by passing through the heat exchanger. Therefore, along the piping between the coal supply unit and the burner, the difference between the exhaust gas temperature and the sulfuric acid dew point of the exhaust gas is increased, thereby suppressing corrosion.
  • FIG. 2 illustrates an oxyfuel coal-firing boiler system according to an another embodiment of the present invention.
  • the present embodiment differs from the first embodiment in that two exhaust gas tapping ports are provided in the exhaust gas discharge line 20 , and the exhaust gas extracted from each port is recirculated to a different part of the system through a different exhaust gas recirculation pipe.
  • the present embodiment has a second exhaust gas tapping port 22 a in addition to a first exhaust gas tapping port 22 similar to the tapping port 22 of the first embodiment.
  • the second exhaust gas tapping port 22 a is provided upstream of the heat exchanger 3 , the dry dust removing unit 4 , the wet desulfurization unit 5 , the wet dust removing unit 6 and the moisture removing cooler 7 and downstream of the NO x removing unit 2 .
  • the recirculation pipe 14 a is connected to an exhaust gas recirculation pipe 14 a , through which a part of the exhaust gas is recirculated to the after-gas port 13 by a recirculation fan (not shown).
  • the recirculation pipe 14 a is provided with a flow rate regulator (not shown), thereby regulating the flow rate of the recirculated exhaust gas.
  • To the recirculation pipe 14 a is connected a branch of the oxygen supply pipe 16 , through which oxygen is supplied to and mixed with the recirculated exhaust gas.
  • the flow rate of the oxygen is also regulated by a flow rate regulator (not shown).
  • the flow rate and oxygen concentration of the mixture gas supplied to the after-gas port 13 can be regulated independently.
  • the exhaust gas recirculation pipe 14 through which part of the exhaust gas is recirculated to the coal mill 11 and the oxidizer feed path of the burner 12 , is connected to the first tapping port 22 provided downstream of the moisture removing cooler 7 as similarly to the first embodiment, and exhaust gas that has been subjected to all the exhaust gas treatments is recirculated.
  • the first exhaust gas recirculation pipe 14 extending from the first tapping port 22 is not connected to the after-gas port 13 .
  • the exhaust gas tapping port 22 a may be provided between the boiler 1 and the NO x removing unit 2 in the exhaust gas discharge line 20 .
  • the exhaust gas tapping port for the second exhaust gas recirculation line is provided between the NO x removing unit and the heat exchanger, and thereby the rate of the exhaust gas flowing through each unit from the heat exchanger 3 to the moisture removing cooler 7 can be reduced by about 15%.
  • This is advantageous because the boiler system can be downsized.
  • a part of the high temperature exhaust gas is almost directly recirculated to the boiler without thermal loss by equipment, thus improving the thermal efficiency of the plant.
  • the sulfuric acid dew point of the exhaust gas in the recirculation pipe 14 a is higher than that of the recirculated exhaust gas in the first embodiment, however, the high temperature exhaust gas higher than 350° C. can be recirculation to the after-gas port 13 without suffering from any serious temperature drop, thus minimizing the risk of sulfuric acid dew point corrosion.
  • FIG. 3 illustrates an oxyfuel coal-firing boiler system according to an other embodiment of the present invention.
  • the present embodiment differs from the first and second embodiments in that one of the two exhaust gas tapping ports is provided between the dry dust removing unit 4 and the heat exchanger 3 , and a part of the exhaust gas extracted from the tapping port 22 b is recirculated to the oxidizer feed path of the burner 12 and the after-gas port 13 .
  • the present embodiment provides a second exhaust gas tapping port 22 b in the exhaust gas discharge line 20 upstream of the heat exchanger 3 , the wet desulfurization unit 5 , the wet dust removing unit 6 and the moisture removing cooler 7 and downstream of the dry dust removing unit 4 .
  • the dry dust removing unit 4 in the present embodiment is provided upstream of the heat exchanger 3 , so the dry dust removing unit needs to be able to treat higher temperature exhaust gas.
  • the dry dust removing unit can treat exhaust gas higher than 350° C.
  • an exhaust gas recirculation pipe 14 b To the tapping port 22 b is connected an exhaust gas recirculation pipe 14 b , through which a part of the exhaust gas is recirculated to the after-gas port 13 and the oxidizer feed path of the burner 12 by a recirculation fan (not shown).
  • the recirculation pipe 14 b is provided with a flow rate regulator (not shown), thereby independently regulating the flow rate of the exhaust gas recirculated to the after-gas port 13 and the burner 12 .
  • a branch of the oxygen supply pipe 16 To the recirculation pipe 14 b is connected a branch of the oxygen supply pipe 16 , through which oxygen is supplied to and mixed with the recirculated exhaust gas.
  • the flow rate of the oxygen is also regulated by a flow rate regulator (not shown).
  • a regulation device that can independently regulate the flow rate and oxygen concentration of the mixture gas supplied to each of the after-gas port 13 and the oxidizer feed path of the burner 12 .
  • a regulation device that can independently regulate the flow rate and oxygen concentration of the mixture gas supplied to each of the after-gas port 13 and the oxidizer feed path of the burner 12 .
  • To provide the such regulation device is advantageous because the formation of the reductive atmosphere region in the boiler 1 and the amount of unburned coal can be more accurately controlled.
  • the exhaust gas recirculation pipe 14 is connected to the first tapping port 22 provided downstream of the moisture removing cooler 7 , and a part of the exhaust gas that has been subjected to all the exhaust gas treatments is recirculated to the coal mill 11 .
  • the exhaust gas recirculation pipe is not connected to the after-gas port 13 or the oxidizer feed path of the burner 12 .
  • the exhaust gas tapping port for the second exhaust gas recirculation line is provided between the dry dust removing unit and the heat exchanger, and thereby the rate of the exhaust gas flowing through each of the heat exchanger 3 , the wet desulfurization unit 5 , the wet dust removing unit 6 and the moisture removing cooler 7 can be reduced by about 50% compared to the first embodiment.
  • This is advantageous because the boiler system can be downsized to a greater extent than that of the second embodiment.
  • an even larger part of the high temperature exhaust gas is almost directly recirculated to the boiler without thermal loss by equipment than that of the second embodiment, thus more greatly improving the thermal efficiency of the boiler system.
  • the sulfuric acid dew point of the exhaust gas in the recirculation pipe 14 b is higher than that of the second embodiment, however, the high temperature gas higher than 350° C. can be recirculated to the after-gas port 13 and the burner 12 without suffering from any serious temperature drop, thus minimizing the risk of sulfuric acid dew point corrosion.
  • the second exhaust gas tapping port for the second exhaust gas recirculation line is provided downstream of the dry dust removing unit, and thus exhaust gas that has been subjected to a dust removing treatment can be supplied to the after-gas port and the oxidizer feed path of the burner. This can prevent dust contained in the exhaust gas from clogging the exhaust gas recirculation line, the after-gas port and the oxidizer feed path of the burner as exhaust-gas jet outlets to the boiler.
  • FIG. 4 illustrates an oxyfuel coal firing boiler system according to an other embodiment of the present invention.
  • the present embodiment differs from the first embodiment in that the nitrogen gas exhaust pipe 15 through which gas mainly containing nitrogen is discharged from the oxygen generator 10 for separating oxygen from air has a nitrogen gas bypass pipe 18 . Also, the nitrogen gas bypass pipe 18 is connected with a heat transfer pipe provided in the moisture removing cooler 7 so that
  • the nitrogen gas in the nitrogen gas bypass pipe and the exhaust gas in the exhaust gas discharge line 20 can be heat exchanged with each other in the moisture removing cooler 7 .
  • the nitrogen gas thus heat exchanged is returned to the nitrogen gas exhaust pipe 15 , mixed with the off-gas from the CO 2 liquefaction unit 8 and discharged into the environment through the discharge stack 9 .
  • each of the nitrogen gas bypass pipe 18 and the nitrogen gas exhaust pipe is provided with a flow rate regulating valve and an on-off valve so that the flow rate of nitrogen gas flowing through the nitrogen gas bypass pipe can be regulated.
  • the oxygen generator 10 is preferably of a cryogenic separation type.
  • a heat exchanger may be placed separately downstream of the moisture removing cooler 7 , instead of providing in the cooler 7 .
  • a heat exchanger may be constructed a moisture removing unit, instead of providing the moisture removing cooler.
  • the configuration of the present embodiment can make more efficient use of the cold temperature of the exhausted nitrogen gas and can remove moisture from the recirculated exhaust gas more reliably.
  • the thermal efficiency of the entire system can be enhanced, and also the effects of the invention provided by the removal of moisture from the exhaust gas can be achieved more stably.
  • FIG. 6 illustrates a control apparatus for controlling the recirculated exhaust gas in the oxyfuel boiler system in the first embodiment.
  • the control apparatus for controlling the recirculated exhaust gas is described below.
  • a recirculation exhaust gas control apparatus 100 outputs: signals 112 and 113 that each control the flow rate of a corresponding recirculation gas stream based on a demand signal 101 ; signals 110 and 111 that each control the flow rate of a corresponding O 2 gas supply stream; and a signal 114 that controls the flow rate of coal.
  • the demand signal 101 essentially includes a load demand and an output demand.
  • the load demand is a demand signal that determines the load of the boiler furnace.
  • the recirculation exhaust gas control apparatus 100 determines the supply rate of coal based on the load demand, and then determines, based on the thus determined coal supply rate, the rate of each O 2 supply (i.e., the ratio of each O 2 supply rate/the coal supply rate) as well as the flow rate of each recirculation gas stream (i.e., the O 2 concentration in each recirculation gas stream).
  • Each flow rate is controlled by using a flow rate detector (not shown).
  • the supply rate of coal is controlled by sending the signal 114 to the flow rate regulating valve provided in the coal supply pipe for supplying coal to the coal mill 11 .
  • the supply rates of O 2 are controlled by sending the signals 110 and 111 to the respective flow rate regulating valves provided in the oxygen supply pipe 16
  • the flow rates of the recirculated gas are controlled by sending the signals 112 and 113 to the respective flow rate regulating valves provided in the exhaust gas recirculation pipe 14 .
  • the output demand is a demand signal that is issued when the load demand signal remains unchanged, yet the heat generation of the furnace deviates from the target value demanded by the load demand signal.
  • the heat generation of the furnace is fine-adjusted by changing the flow rate of each recirculation gas stream (i.e., by changing the O 2 concentration in each recirculation gas stream) rather than by changing the rate of each O 2 supply.

Landscapes

  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Combustion Of Fluid Fuel (AREA)
  • Treating Waste Gases (AREA)
  • Air Supply (AREA)
  • Chimneys And Flues (AREA)
US12/435,858 2008-05-07 2009-05-05 Oxyfuel Boiler System and Method of Retrofit of Air Fired Boiler to Oxyfuel Boiler Abandoned US20090277363A1 (en)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
JP2008120865A JP4644725B2 (ja) 2008-05-07 2008-05-07 酸素燃焼ボイラシステム，微粉炭燃焼ボイラの改造方法，酸素燃焼ボイラシステムの制御装置及びその制御方法
JP2008-120865 2008-05-07

Publications (1)

Publication Number Publication Date
US20090277363A1 true US20090277363A1 (en) 2009-11-12

Family

ID=40886901

Family Applications (1)

Application Number Title Priority Date Filing Date
US12/435,858 Abandoned US20090277363A1 (en) 2008-05-07 2009-05-05 Oxyfuel Boiler System and Method of Retrofit of Air Fired Boiler to Oxyfuel Boiler

Country Status (3)

Country Link
US (1) US20090277363A1 (de)
EP (1) EP2116765A3 (de)
JP (1) JP4644725B2 (de)

Cited By (16)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20100212555A1 (en) * 2009-02-25 2010-08-26 Hitachi, Ltd. Oxyfuel Combustion Boiler Plant and Operating Method for the Same
US20110045421A1 (en) * 2008-03-06 2011-02-24 Ihi Corporation Method and apparatus of controlling oxygen supply for boiler
US20110076216A1 (en) * 2009-09-30 2011-03-31 Hitachi, Ltd. Carbon Dioxide Capture Power Generation System
US20110094105A1 (en) * 2009-10-22 2011-04-28 Hitachi, Ltd. Retrofit Method for Pulverized Coal Boiler
US20110139046A1 (en) * 2009-12-16 2011-06-16 Foster Wheeler Energy Corporation Emissionless Oxyfuel Combustion Process and a Combustion System Using Such a Process
US20120085339A1 (en) * 2009-03-26 2012-04-12 Fadi Eldabbagh System to Lower Emissions and Improve Energy Efficiency on Fossil Fuels and Bio-Fuels Combustion Systems
US20120090326A1 (en) * 2010-10-19 2012-04-19 Alstom Technology Ltd Power plant
US20120090328A1 (en) * 2010-10-19 2012-04-19 Alstom Technology Ltd Power plant
US20120145052A1 (en) * 2010-11-16 2012-06-14 Alstom Technology Ltd. Apparatus and method of controlling the thermal performance of an oxygen-fired boiler
CN102519053A (zh) * 2011-12-15 2012-06-27 东南大学 一种降低空气含湿量来提高锅炉燃烧效率的系统
US20130092062A1 (en) * 2010-06-16 2013-04-18 Masahiko Matsuda Combustion system
US8814561B2 (en) 2011-01-17 2014-08-26 Ihi Corporation Method and apparatus for controlling operation of oxyfuel combustion boiler
US9181888B2 (en) 2013-10-28 2015-11-10 Cummins Inc. Selectively trapping and storing SO3 in an exhaust gas effluent
US9486736B2 (en) 2009-12-04 2016-11-08 General Electric Technology Gmbh Method and a device for cleaning a carbon dioxide rich flue gas
CN107023823A (zh) * 2016-02-02 2017-08-08 通用电气公司 空气污染控制方法和系统
US10750676B2 (en) * 2018-05-30 2020-08-25 Therma-Stor, Llc Greenhouse desiccant dehumidifier and carbon dioxide generator

Families Citing this family (31)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8807991B2 (en) * 2007-07-10 2014-08-19 Babcock & Wilcox Power Generation Group, Inc. Oxy-fuel combustion oxidant heater internal arrangement
US20090320725A1 (en) * 2008-06-25 2009-12-31 Alstom Technology Ltd. Furnace system with internal flue gas recirculation
JP5183372B2 (ja) * 2008-08-29 2013-04-17 株式会社日立製作所 酸素燃焼ボイラシステム及び燃焼方法
JP5174618B2 (ja) * 2008-10-31 2013-04-03 株式会社日立製作所 酸素燃焼ボイラシステム及び酸素燃焼ボイラシステムの制御方法
JP4896194B2 (ja) * 2009-09-30 2012-03-14 株式会社日立製作所 酸素燃焼ボイラプラント
JP5284251B2 (ja) * 2009-12-09 2013-09-11 バブコック日立株式会社 酸素燃焼方式の排ガス処理装置と該排ガス処理装置の運用方法
JP5600439B2 (ja) * 2010-01-27 2014-10-01 バブコック日立株式会社 ボイラプラント
JP5377371B2 (ja) * 2010-03-12 2013-12-25 株式会社日立製作所 酸素燃焼型石炭火力発電システム
JP5437151B2 (ja) * 2010-04-27 2014-03-12 バブコック日立株式会社 排煙脱硫装置及びこれを備えた酸素燃焼装置と方法
JP5717382B2 (ja) * 2010-09-01 2015-05-13 三菱日立パワーシステムズ株式会社 排煙処理装置及び排煙処理方法
JP5432098B2 (ja) * 2010-09-14 2014-03-05 株式会社日立製作所 酸素燃焼ボイラ
WO2012042693A1 (ja) * 2010-09-30 2012-04-05 バブコック日立株式会社 酸素燃焼システム及びその運転方法
JP5740898B2 (ja) * 2010-10-06 2015-07-01 株式会社Ihi 酸素燃焼システムにおける排煙脱硫装置
JP5487509B2 (ja) 2010-10-15 2014-05-07 バブコック日立株式会社 ボイラ燃焼システムとその運転方法
EP2457637B8 (de) 2010-11-24 2016-09-21 General Electric Technology GmbH Verfahren und Boilersystem zum Reinigen eines kohlendioxidreichen Abgases
JP2013002684A (ja) * 2011-06-14 2013-01-07 Mitsubishi Heavy Ind Ltd 流動層処理システム及び方法
CN102500282B (zh) * 2011-11-04 2014-04-09 神华集团有限责任公司 煤净化设备变换管道线路防裂方法及煤净化设备变换管道线路
JP2013185783A (ja) * 2012-03-09 2013-09-19 Ihi Corp 酸素燃焼ボイラシステム
WO2014128959A1 (ja) 2013-02-25 2014-08-28 三菱重工コンプレッサ株式会社 二酸化炭素液化装置
JP6229508B2 (ja) * 2014-01-21 2017-11-15 株式会社Ihi 酸素燃焼ボイラシステム
CN103969072B (zh) * 2014-05-13 2017-02-22 国家电网公司 一种四角切圆燃烧锅炉细粉分离器效率试验方法
CN106247368B (zh) * 2016-07-29 2018-07-17 上海交通大学 一种工业煤粉锅炉烟气再循环低氮燃烧方法和系统
CN106439796A (zh) * 2016-11-09 2017-02-22 中国环境科学研究院 一种低负荷燃煤锅炉烟气量/氮氧化物减排系统
CN106642180B (zh) * 2016-12-06 2019-01-04 丹东同合高新科技有限公司 一种燃煤锅炉烟气二次回收控氧阻燃系统
KR101928540B1 (ko) * 2018-04-20 2018-12-12 주식회사 비엔에스 보일러의 이상 진동 감지 알람 시스템
CN108800151B (zh) * 2018-04-29 2019-09-13 无锡方菱环保科技有限公司 一种绿色环保的工业垃圾焚烧炉
CN109268862B (zh) * 2018-09-20 2020-04-07 北京建筑大学 混合气体加湿的低氮高效烟气潜热利用系统
CN109520287A (zh) * 2018-12-28 2019-03-26 广州薪光合环保技术有限公司 循环式固体废弃物烘干处理系统
KR102319856B1 (ko) * 2020-02-03 2021-11-02 한국에너지기술연구원 순산소 연소시스템의 폐열을 이용하는 유동층 건조장치 및 이를 이용한 건조방법
CN112443855B (zh) * 2020-11-16 2023-03-31 中国神华能源股份有限公司国华电力分公司 变负载过程中的氮氧化物控制方法、装置及煤燃烧系统
KR102659356B1 (ko) * 2022-11-28 2024-04-19 대림로얄이앤피(주) 진동센서를 이용한 산업용 보일러 송풍기의 이상진단시스템

Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4411204A (en) * 1981-12-07 1983-10-25 Combustion Engineering, Inc. Method of firing a pulverized fuel-fired steam generator
US6505567B1 (en) * 2001-11-26 2003-01-14 Alstom (Switzerland) Ltd Oxygen fired circulating fluidized bed steam generator
US7320288B2 (en) * 2002-02-15 2008-01-22 American Air Liquide, Inc. Steam-generating combustion system and method for emission control using oxygen enhancement
US20080184880A1 (en) * 2006-10-26 2008-08-07 Foster Wheeler Energy Corporation Method of and apparatus for CO2 capture in oxy-combustion
US20080302107A1 (en) * 2007-06-08 2008-12-11 Foster Wheeler Energy Corporation Method of and power plant for generating power by oxyfuel combustion
US20090249988A1 (en) * 2008-04-07 2009-10-08 L'air Liquide Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Apparatus and Process for Oxycombustion with CO2 Capture
US20090255450A1 (en) * 2008-04-14 2009-10-15 Stone Bryan B Oxy-combustion coal fired boiler and method of transitioning between air and oxygen firing
US7832342B2 (en) * 2005-03-04 2010-11-16 Martin GmbH für Umwelt-und Energietechnik Process for combusting fuels, in particular waste

Family Cites Families (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JP3068888B2 (ja) * 1991-05-28 2000-07-24 株式会社日立製作所 燃焼装置及びその運転方法
JP3053914B2 (ja) * 1991-07-16 2000-06-19 バブコック日立株式会社 Ｃｏ２回収型ボイラ
JPH0694212A (ja) * 1992-09-10 1994-04-05 Mitsubishi Heavy Ind Ltd 化石燃料燃焼ボイラ
JPH06101809A (ja) * 1992-09-21 1994-04-12 Ishikawajima Harima Heavy Ind Co Ltd ボイラ設備
JP3338555B2 (ja) * 1994-05-24 2002-10-28 電源開発株式会社 二酸化炭素回収型排ガス再循環ボイラ設備の燃焼バーナ
RU2005116273A (ru) * 2002-10-30 2005-11-10 Кребс Энд Сислер Лп (Us) Котел со сжиганием топлива при использовании окислителя, обогащенного кислородом, для повышения кпд и снижения вредных выбросов
JP4731293B2 (ja) * 2005-11-28 2011-07-20 電源開発株式会社 酸素燃焼ボイラの燃焼制御方法及び装置
JP2007147161A (ja) * 2005-11-28 2007-06-14 Electric Power Dev Co Ltd 燃焼装置の排ガス処分方法及び装置
US9651253B2 (en) * 2007-05-15 2017-05-16 Doosan Power Systems Americas, Llc Combustion apparatus

Patent Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4411204A (en) * 1981-12-07 1983-10-25 Combustion Engineering, Inc. Method of firing a pulverized fuel-fired steam generator
US6505567B1 (en) * 2001-11-26 2003-01-14 Alstom (Switzerland) Ltd Oxygen fired circulating fluidized bed steam generator
US7320288B2 (en) * 2002-02-15 2008-01-22 American Air Liquide, Inc. Steam-generating combustion system and method for emission control using oxygen enhancement
US7832342B2 (en) * 2005-03-04 2010-11-16 Martin GmbH für Umwelt-und Energietechnik Process for combusting fuels, in particular waste
US20080184880A1 (en) * 2006-10-26 2008-08-07 Foster Wheeler Energy Corporation Method of and apparatus for CO2 capture in oxy-combustion
US20080302107A1 (en) * 2007-06-08 2008-12-11 Foster Wheeler Energy Corporation Method of and power plant for generating power by oxyfuel combustion
US20090249988A1 (en) * 2008-04-07 2009-10-08 L'air Liquide Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Apparatus and Process for Oxycombustion with CO2 Capture
US20090255450A1 (en) * 2008-04-14 2009-10-15 Stone Bryan B Oxy-combustion coal fired boiler and method of transitioning between air and oxygen firing

Cited By (25)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20110045421A1 (en) * 2008-03-06 2011-02-24 Ihi Corporation Method and apparatus of controlling oxygen supply for boiler
US8662884B2 (en) * 2008-03-06 2014-03-04 Ihi Corporation Method and apparatus of controlling oxygen supply for boiler
US20100212555A1 (en) * 2009-02-25 2010-08-26 Hitachi, Ltd. Oxyfuel Combustion Boiler Plant and Operating Method for the Same
US8561555B2 (en) * 2009-02-25 2013-10-22 Hitachi, Ltd. Oxyfuel combustion boiler plant and operating method for the same
US20120085339A1 (en) * 2009-03-26 2012-04-12 Fadi Eldabbagh System to Lower Emissions and Improve Energy Efficiency on Fossil Fuels and Bio-Fuels Combustion Systems
US20110076216A1 (en) * 2009-09-30 2011-03-31 Hitachi, Ltd. Carbon Dioxide Capture Power Generation System
US8500881B2 (en) * 2009-09-30 2013-08-06 Hitachi, Ltd. Carbon dioxide capture power generation system
US20110094105A1 (en) * 2009-10-22 2011-04-28 Hitachi, Ltd. Retrofit Method for Pulverized Coal Boiler
US8393065B2 (en) * 2009-10-22 2013-03-12 Hitachi, Ltd. Retrofit method for pulverized coal boiler
US9486736B2 (en) 2009-12-04 2016-11-08 General Electric Technology Gmbh Method and a device for cleaning a carbon dioxide rich flue gas
US20110139046A1 (en) * 2009-12-16 2011-06-16 Foster Wheeler Energy Corporation Emissionless Oxyfuel Combustion Process and a Combustion System Using Such a Process
WO2011073890A1 (en) * 2009-12-16 2011-06-23 Foster Wheeler Energy Corporation Emissionless oxyfuel combustion process and a combustion system using such a process
US20130092062A1 (en) * 2010-06-16 2013-04-18 Masahiko Matsuda Combustion system
KR101495087B1 (ko) * 2010-06-16 2015-03-03 미츠비시 히타치 파워 시스템즈 가부시키가이샤 연소 시스템
US20120090328A1 (en) * 2010-10-19 2012-04-19 Alstom Technology Ltd Power plant
US9010081B2 (en) * 2010-10-19 2015-04-21 Alstom Technology Ltd. Combined cycle plant including chilled ammonia based CO2 capture unit and utilizing system produced nitric acid
US9200540B2 (en) * 2010-10-19 2015-12-01 Alstom Technology Ltd Combined cycle with recirculation plant inlet oxygen concentration system
US20120090326A1 (en) * 2010-10-19 2012-04-19 Alstom Technology Ltd Power plant
US20120145052A1 (en) * 2010-11-16 2012-06-14 Alstom Technology Ltd. Apparatus and method of controlling the thermal performance of an oxygen-fired boiler
US9752773B2 (en) * 2010-11-16 2017-09-05 General Electric Technology Gmbh Apparatus and method of controlling the thermal performance of an oxygen-fired boiler
US8814561B2 (en) 2011-01-17 2014-08-26 Ihi Corporation Method and apparatus for controlling operation of oxyfuel combustion boiler
CN102519053A (zh) * 2011-12-15 2012-06-27 东南大学 一种降低空气含湿量来提高锅炉燃烧效率的系统
US9181888B2 (en) 2013-10-28 2015-11-10 Cummins Inc. Selectively trapping and storing SO3 in an exhaust gas effluent
CN107023823A (zh) * 2016-02-02 2017-08-08 通用电气公司 空气污染控制方法和系统
US10750676B2 (en) * 2018-05-30 2020-08-25 Therma-Stor, Llc Greenhouse desiccant dehumidifier and carbon dioxide generator

Also Published As

Publication number Publication date
EP2116765A3 (de) 2011-02-16
EP2116765A2 (de) 2009-11-11
JP4644725B2 (ja) 2011-03-02
JP2009270753A (ja) 2009-11-19

Similar Documents

Publication Publication Date Title
US20090277363A1 (en) Oxyfuel Boiler System and Method of Retrofit of Air Fired Boiler to Oxyfuel Boiler
EP2182279B1 (de) Oxyfuel-Kesselsystem und Steuerungsverfahren dafür
AU2006316951B2 (en) Combustion control method and device of oxygen combustion boiler
JP5138028B2 (ja) 酸素燃焼ボイラの酸素供給制御方法及び装置
US8561555B2 (en) Oxyfuel combustion boiler plant and operating method for the same
RU2442076C1 (ru) Способ управления процессом генерирования мощности на энергетической установке
EP2267366B1 (de) Verfahren zur steuerung von verbrennung in einem sauerstoffverbrennungskessel und vorrichtung dafür
CN102016417A (zh) 氧燃烧锅炉的排气控制方法及装置
CN102047040B (zh) 氧燃烧锅炉的一次再循环废气流量控制方法及装置
WO2012035777A1 (ja) 燃焼プラント
US9429319B2 (en) Boiler combustion system and operation method therefor
Kim et al. Impurity effects on the oxy-coal combustion power generation system
CN115298484A (zh) 包含环形护罩炉头的燃烧系统
JP5812740B2 (ja) 酸素燃焼システム及びその運転方法
RU2817237C1 (ru) Способ высушивания и система сушки бурого угля с использованием рециркуляции дымового газа
CN103480241A (zh) 烟气系统及其控制方法

Legal Events

Date Code Title Description
AS Assignment

Owner name: HITACHI, LTD., JAPAN

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:SHIBATA, TSUYOSHI;TANIGUCHI, MASAYUKI;ORITA, HISAYUKI;AND OTHERS;REEL/FRAME:022984/0524;SIGNING DATES FROM 20090605 TO 20090606

STCB Information on status: application discontinuation

Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION