EP3913283B1 - Boiler - Google Patents

Boiler Download PDF

Info

Publication number
EP3913283B1
EP3913283B1 EP20760113.9A EP20760113A EP3913283B1 EP 3913283 B1 EP3913283 B1 EP 3913283B1 EP 20760113 A EP20760113 A EP 20760113A EP 3913283 B1 EP3913283 B1 EP 3913283B1
Authority
EP
European Patent Office
Prior art keywords
burner
secondary burner
steam
air
primary
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.)
Active
Application number
EP20760113.9A
Other languages
German (de)
English (en)
French (fr)
Other versions
EP3913283A4 (en
EP3913283A1 (en
Inventor
Takazumi TERAHARA
Masafumi Mori
Ryuta NAKAMURA
Hideki Amano
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.)
Mitsubishi Heavy Industries Marine Machinery and Equipment Co Ltd
Original Assignee
Mitsubishi Heavy Industries Marine Machinery and Equipment Co 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 Mitsubishi Heavy Industries Marine Machinery and Equipment Co Ltd filed Critical Mitsubishi Heavy Industries Marine Machinery and Equipment Co Ltd
Publication of EP3913283A1 publication Critical patent/EP3913283A1/en
Publication of EP3913283A4 publication Critical patent/EP3913283A4/en
Application granted granted Critical
Publication of EP3913283B1 publication Critical patent/EP3913283B1/en
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
    • F22B35/00—Control systems for steam boilers
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
    • F22B31/00—Modifications of boiler construction, or of tube systems, dependent on installation of combustion apparatus; Arrangements of dispositions of combustion apparatus
    • F22B31/04—Heat supply by installation of two or more combustion apparatus, e.g. of separate combustion apparatus for the boiler and the superheater respectively
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
    • F22B13/00—Steam boilers of fire-box type, i.e. the combustion of fuel being performed in a chamber or fire-box with subsequent flue(s) or fire tube(s), both chamber or fire-box and flues or fire tubes being built-in in the boiler body
    • F22B13/06—Locomobile, traction-engine, steam-roller, or locomotive boilers
    • 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 
    • F23C1/00—Combustion apparatus specially adapted for combustion of two or more kinds of fuel simultaneously or alternately, at least one kind of fuel being either a fluid fuel or a solid fuel suspended in a carrier gas or air
    • F23C1/08—Combustion apparatus specially adapted for combustion of two or more kinds of fuel simultaneously or alternately, at least one kind of fuel being either a fluid fuel or a solid fuel suspended in a carrier gas or air liquid and gaseous fuel
    • 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 
    • F23C6/00—Combustion apparatus characterised by the combination of two or more combustion chambers or combustion zones, e.g. for staged combustion
    • F23C6/04—Combustion apparatus characterised by the combination of two or more combustion chambers or combustion zones, e.g. for staged combustion in series connection
    • F23C6/045—Combustion apparatus characterised by the combination of two or more combustion chambers or combustion zones, e.g. for staged combustion in series connection with staged combustion in a single enclosure
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23D—BURNERS
    • F23D14/00—Burners for combustion of a gas, e.g. of a gas stored under pressure as a liquid
    • F23D14/46—Details, e.g. noise reduction means
    • F23D14/72—Safety devices, e.g. operative in case of failure of gas supply
    • F23D14/78—Cooling burner parts
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
    • F22B21/00—Water-tube boilers of vertical or steeply-inclined type, i.e. the water-tube sets being arranged vertically or substantially vertically
    • F22B21/02—Water-tube boilers of vertical or steeply-inclined type, i.e. the water-tube sets being arranged vertically or substantially vertically built-up from substantially straight water tubes
    • F22B21/04—Water-tube boilers of vertical or steeply-inclined type, i.e. the water-tube sets being arranged vertically or substantially vertically built-up from substantially straight water tubes involving a single upper drum and a single lower drum, e.g. the drums being arranged transversely
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
    • F22B21/00—Water-tube boilers of vertical or steeply-inclined type, i.e. the water-tube sets being arranged vertically or substantially vertically
    • F22B21/02—Water-tube boilers of vertical or steeply-inclined type, i.e. the water-tube sets being arranged vertically or substantially vertically built-up from substantially straight water tubes
    • F22B21/04—Water-tube boilers of vertical or steeply-inclined type, i.e. the water-tube sets being arranged vertically or substantially vertically built-up from substantially straight water tubes involving a single upper drum and a single lower drum, e.g. the drums being arranged transversely
    • F22B21/08—Water-tube boilers of vertical or steeply-inclined type, i.e. the water-tube sets being arranged vertically or substantially vertically built-up from substantially straight water tubes involving a single upper drum and a single lower drum, e.g. the drums being arranged transversely the water tubes being arranged sectionally in groups or in banks, e.g. bent over at their ends
    • F22B21/081—Water-tube boilers of vertical or steeply-inclined type, i.e. the water-tube sets being arranged vertically or substantially vertically built-up from substantially straight water tubes involving a single upper drum and a single lower drum, e.g. the drums being arranged transversely the water tubes being arranged sectionally in groups or in banks, e.g. bent over at their ends involving a combustion chamber, placed at the side and built-up from water tubes

Definitions

  • the present invention relates to a boiler.
  • JP S57-81999 listed below discloses a ship boiler installed in a ship.
  • the boiler disclosed in JP S57-81999 is provided with a small capacity burner in addition to a large capacity burner and thereby can cover a need for a large capacity burner to a small capacity burner.
  • JP 2018-141585 A discloses a boiler which represents the closest prior art.
  • a main engine boiler used for a power source for driving a propulsion propeller.
  • an auxiliary boiler used for an auxiliary power source that activates various devices installed in the ship or drives a detonator.
  • An auxiliary boiler used for generating high pressure steam for a high load device and an auxiliary boiler used for generating low pressure steam for a low load device may be required, respectively. This will result in an increase in the number of units in the ship. Further, since the auxiliary boiler requires time for increasing the pressure, it is also necessary to continue a warm-up operation in order to promptly supply steam to a device. Thus, there is a problem of increased fuel consumption due to a warm-up operation of an auxiliary boiler that generates high pressure steam in particular.
  • the small capacity burner is stopped during the operation of a large capacity burner, and there is a risk of damage to the small capacity secondary burner due to radiation heat of flame of the large capacity primary burner.
  • the present disclosure has been made in view of such circumstances and intends to provide a boiler that can cool a small capacity burner while a large capacity primary burner is in operation.
  • the secondary burner is provided downstream of flame formed by the primary burner.
  • the primary burner when the primary burner is in operation and the secondary burner is not in operation, there is a risk of damage to the secondary burner caused by radiation heat of the flame of the primary burner if no combustion air is supplied to the secondary burner.
  • air is supplied from the secondary burner air fan to cool the secondary burner.
  • the secondary burner and the secondary burner wind box can be sealed from the pressurized combustion chamber.
  • the control unit may control the air supply unit such that a pressure of the secondary burner wind box is higher than a pressure of the combustion vessel when the primary burner is in operation and the secondary burner is not in operation.
  • the boiler according to the present invention includes a cooling steam supply unit configured to supply cooling steam that cools the secondary burner.
  • the secondary burner includes an oil ejection nozzle configured to eject oil fuel to the combustion chamber as combustion fuel, and the oil ejection nozzle is a part of the cooling steam supply unit.
  • the oil ejection nozzle of the secondary burner is not supplied with any oil when the secondary burner is not in operation, the oil ejection nozzle is provided as a part of the cooling steam supply unit and supplies cooling steam from the oil ejection nozzle. Since the oil ejection nozzle ejects cooling steam from the tip of the secondary burner into the combustion chamber, the secondary burner can be effectively protected from radiation heat.
  • a steam supply nozzle is provided as a part of the cooling steam supply unit in the secondary burner wind box.
  • the steam supply nozzle is provided as a part of the cooling steam supply unit in the secondary burner wind box. This enables cooling of the secondary burner accommodated in the secondary burner wind box. Further, since a path used for supplying cooling steam can be provided separately from the fuel nozzle of the secondary burner, cooling steam can be supplied regardless of the operation of the secondary burner.
  • the steam supply nozzle may be, for example, a steam ring nozzle that is a ring-shaped nozzle surrounding the secondary burner.
  • the secondary burner includes a gas ejection nozzle configured to eject gas fuel to the combustion chamber as combustion fuel, and the gas ejection nozzle is a part of the cooling steam supply unit.
  • the secondary burner has a gas ejection nozzle so that gas fuel can be used in addition to oil fuel.
  • the gas ejection nozzle is provided as a part of the cooling steam supply unit to supply cooling steam from the gas ejection nozzle. Since the gas ejection nozzle ejects cooling steam from the tip of the secondary burner into the combustion chamber, the secondary burner can be effectively protected from radiation heat.
  • the cooling steam supply unit supplies cooling steam to downstream of flame formed by the primary burner.
  • the boiler includes: a primary burner wind box accommodating the primary burner and attached to the combustion vessel; a primary burner air fan configured to supply air to the primary burner wind box; and an air supply tube configured to supply air from the primary burner air fan to the secondary burner wind box.
  • Air is supplied from the primary burner air fan to the secondary burner wind box. Accordingly, even if the secondary burner air fan should fail, cooling air can be supplied to the secondary burner wind box.
  • the air supply from the primary burner air fan to the secondary burner wind box is controlled by the control unit. That is, when the secondary burner air fan has not failed, the control unit controls an on-off valve or the like so as to stop the air flow. If the secondary burner air fan fails, the control unit controls the on-off valve or the like so that air flows. Note that, without limited to a failure of the secondary burner air fan, when the amount of air supplied from the secondary burner air fan is insufficient, air may be supplied from the primary burner fan to the secondary burner wind box.
  • a damper configured to open and close a channel is provided to an outlet of the air supply unit.
  • a damper is provided to the outlet of the air supply unit. Accordingly, the damper is closed when the air supply unit is stopped, air guided from the primary burner air fan via the air supply tube can be prevented from flowing back to the air supply unit side.
  • the secondary burner can be cooled.
  • the boiler of the present embodiment will be described as being a ship boiler installed in a ship. Specifically, the boiler will be described as being used for an auxiliary boiler that generates general service steam used for driving a steam turbine or the like for a cargo oil pump, for example. Note that, without being limited to the above auxiliary boiler, the boiler can also be used as a main engine boiler that serves as a power source during navigation or an auxiliary boiler that activates a machine installed in a ship, in a case of a ship, for example. The boiler can be used for boilers of various uses without being limited to the ship use.
  • a boiler 10 has a combustion vessel 11, a primary burner 12, a secondary burner 13, an evaporator 14, and a control unit 15.
  • the combustion vessel 11 has a box-like shape, and a combustion chamber 24 is formed inside.
  • the combustion chamber 24 is pressurized when the primary burner 12 or the secondary burner 13 is in operation. Note that the burner 12 or 13 being in operation means a state where flame is formed, and the burner 12 or 13 being not in operation means a state where no flame is formed.
  • the combustion vessel 11 has a top 11a, a bottom 11b, a front wall 11c (see Fig. 2 ), a rear wall 11d (see Fig. 2 ), and a pair of side walls 11e and 11f.
  • a gas outlet 22 is formed in the top 11a.
  • the bottom 11b is provided facing the top 11a.
  • the front wall 11c, the rear wall 11d, and the pair of side walls 11e and 11f extend so as to connect the top 11a and the bottom 11b to each other.
  • the top 11a, the bottom 11b, the front wall 11c, the rear wall 11d, and the side wall 11e form the combustion chamber 24.
  • the combustion chamber 24 is defined by the top 11a, the bottom 11b, the front wall 11c, the rear wall 11d, the side wall 11e, and a front bank tube 28 described later.
  • the primary burner 12 and the secondary burner 13 are situated facing the combustion chamber 24.
  • an exhaust chamber 33 defined by the top 11a, the bottom 11b, the front wall 11c, rear wall 11d, the side wall 11f, and an evaporator tube 25 described later is provided.
  • the gas outlet 22 is in communication with the exhaust chamber 33.
  • the combustion vessel 11 is provided with a partition plate 29 near the center in the height direction (the vertical direction in Fig. 1 ) of the evaporator 14 and the front bank tube 28.
  • the partition plate 29 forms a gas outlet-side passage 23 between the bottom 11b and the partition plate 29 in a region in which the evaporator 14 and the front bank tube 28 are arranged.
  • the gas outlet-side passage 23 is a passage of a combustion gas G mainly flowing from the combustion chamber 24 to the exhaust chamber 33.
  • a single primary burner 12 is provided at a position of the top 11a in which the position is on the side wall 11e side and is spaced apart from the gas outlet 22. Note that, although the single primary burner 12 is provided in the present embodiment, a plurality of primary burners 12 may be provided.
  • the primary burner 12 is connected to a fuel supply line and an air supply line.
  • the primary burner 12 has an igniter (not illustrated). The primary burner 12 combusts a fuel gas in the combustion chamber 24 surrounded by the top 11a, the bottom 11b, and the side wall 11e and forms flame F1 toward the bottom 11b side.
  • a single secondary burner 13 is provided to the front wall 11c.
  • the secondary burner 13 is connected to a fuel supply line and an air supply line that are different from those for the primary burner 12.
  • the secondary burner 13 has an igniter (not illustrated) that is different from that of the primary burner 12.
  • the secondary burner 13 combusts a fuel oil and/or a fuel gas in the combustion chamber 24 and forms flame F2 from the front wall 11c to the rear wall 11d, as illustrated in Fig. 2 .
  • the secondary burner 13 has a smaller capacity than the primary burner 12. In the present embodiment, the capacity of the secondary burner 13 is one-fifth to one-third of the capacity of the primary burner 12, for example.
  • the secondary burner 13 is accommodated in the secondary burner wind box 40.
  • the secondary burner wind box 40 is provided so as to protrude outward from the front wall 11c.
  • Secondary burner air AR1 is supplied into the secondary burner wind box 40.
  • the secondary burner air AR1 is used as combustion air of the secondary burner 13 and also used as seal air or cooling air as described later.
  • the secondary burner 13 has an oil ejection nozzle 13a that ejects oil fuel and gas ejection nozzles 13b that eject gas fuel.
  • the oil ejection nozzle 13a is located at the center on a transverse plane of the secondary burner 13.
  • the plurality of gas ejection nozzles 13b are provided at predetermined angle intervals around the oil ejection nozzle 13a as the center.
  • the periphery of the oil ejection nozzle 13a and the gas ejection nozzles 13b serves as a channel through which the secondary burner air AR1 (see Fig. 2 ) flows.
  • the number of oil ejection nozzles 13a and the number of the gas ejection nozzles 13b are not limited to those in Fig. 3 , a plurality of the oil ejection nozzles 13a may be provided, or more gas ejection nozzles 13b may be provided.
  • the secondary burner 13 is provided to the front wall 11c on the side closer to the bottom 11b of the combustion vessel 11 than to the primary burner 12.
  • the secondary burner 13 is provided at a position near the lower end that is downstream of the flame F1 formed by the primary burner 12, and air can be supplied to the lower end of the flame F1.
  • the secondary burner 13 is provided in the center part of a wall tube (not illustrated) provided to the side wall 11e and the front bank tube 28 in a width direction (the lateral direction of Fig. 1 ) of the combustion chamber 24.
  • the secondary burner 13 is provided in the center part of the gas outlet-side passage 23 in the height direction (the vertical direction of Fig. 1 ) of the combustion chamber 24, as an example.
  • the secondary burner 13 may be provided near the center part of the wall tube (not illustrated) provided to the side wall 11e and the front bank tube 28 or may be provided near the center part of the gas outlet-side passage 23.
  • the evaporator 14 is formed of a group of evaporators that are a plurality of bundled evaporator tubes 25.
  • the plurality of evaporator tubes 25 are arranged along a fuel gas ejection direction of the primary burner 12 inside the combustion vessel 11.
  • the lower ends of the plurality of evaporator tubes 25 are connected to a water drum 26 supported by the bottom 11b, and the upper ends of the plurality of evaporator tubes 25 are connected to a steam drum 27 supported by the top 11a.
  • Some of the evaporator tubes 25 are arranged bent to the front wall 11c side, and thereby, the evaporator 14 is arranged as the front bank tube 28.
  • the combustion chamber 24, the front bank tube 28, the evaporator 14, and the exhaust chamber 33 are arranged in this order from the primary burner 12 and the secondary burner 13 to the gas outlet 22.
  • a plurality of wall tubes (furnace wall tubes) (not illustrated) as a heat exchanger are provided on each wall face of the combustion vessel 11.
  • a superheater used for superheating steam in the steam drum 27 to generate superheated steam may be provided between the evaporator 14 and the front bank tube 28.
  • the primary burner 12 or the secondary burner 13 ejects fuel to the combustion chamber 24 and combusts the fuel, thereby the flame F1 or flame F2 is formed, and the combustion gas G is generated.
  • the generated combustion gas G flows from the side wall 11e side to the side wall 11f side of the combustion vessel 11.
  • the combustion gas G sequentially passes, from the combustion chamber 24, through a region in which the front bank tube 28 is arranged and a region in which the evaporator 14 is arranged and then reaches the exhaust chamber 33.
  • the combustion gas G passes through the front bank tube 28 and the evaporator 14 via the lower region in Fig. 1 mainly partitioned by the partition plate 29, that is, via the gas outlet-side passage 23.
  • the combustion gas G is mainly redirected to and flows in the upper region in Fig. 1 partitioned by the partition plate 29 in the exhaust chamber 33, again passes through the evaporator 14, and reaches the gas outlet 22.
  • the front bank tube 28 and the evaporator 14 are heat exchangers, respectively, exchange heat with the combustion gas G when the combustion gas G passes therethrough, and collect heat of the combustion gas G to increase the temperature of water or steam (heating medium) passing inside.
  • the front bank tube 28 is arranged on the side of the primary burner 12 and the secondary burner 13 in the combustion vessel 11, that is, arranged in a region with a high temperature inside the combustion vessel 11.
  • the front bank tube 28 is connected to the water drum 26 and the steam drum 27, and water or steam flows inside the front bank tube 28.
  • the front bank tube 28 collects heat of the combustion gas G by heat exchange between the combustion gas G and water or steam, thereby increases the temperature of the water or steam, and reduces the temperature of the combustion gas G.
  • the evaporator 14 has the plurality of evaporator tubes 25 and is arranged on the gas outlet 22 side with respect to the front bank tube 28 in the combustion vessel 11.
  • the combustion gas G that has passed through the region in which the front bank tube 28 is arranged passes through the evaporator 14.
  • the water drum 26 and the steam drum 27 are connected to respective ends of the plurality of evaporator tubes 25, respectively, and water or steam flows in each evaporator tube 25.
  • the evaporator 14 collects heat of the combustion gas G by heat exchange between the combustion gas G and water or steam, thereby increases the temperature of the water or steam, and reduces the temperature of the combustion gas G. That is, the water or steam in each evaporator tube 25 is heated by the combustion gas G, and thereby, only the steam rises and reaches the steam drum 27.
  • combustion gas G The heat of the combustion gas G that has passed through the evaporator 14 is collected, the temperature thereof decreases, and the combustion gas G then reaches the exhaust chamber 33 and is discharged to the outside from the gas outlet 22 as an exhaust gas (combustion gas G).
  • the combustion vessel 11 and the wind box 40 are each provided with a pressure sensor (not illustrated). The output of each pressure sensor is transmitted to the control unit 15.
  • the control unit 15 controls the operation of the boiler such as the primary burner 12 or the secondary burner 13 described above.
  • the control unit is formed of a central processing unit (CPU), a random access memory (RAM), a read only memory (ROM), a computer readable storage medium, and the like, for example. Further, as an example, a series of processes to implement various functions is stored in a storage medium or the like in a form of a program.
  • the CPU reads such a program into the RAM or the like and executes a process of edition and operation of information, and thereby various functions are implemented.
  • a form in which a program is installed in advance in a ROM or other storage mediums a form in which a program is provided in a state of being stored in a computer readable storage medium, a form in which a program is delivered via a wired or wireless communication unit, or the like may be applied.
  • the computer readable storage medium is a magnetic disk, a magneto-optical disk, a CD-ROM, a DVD-ROM, a semiconductor memory, or the like.
  • a secondary burner air fan 44 is connected to the secondary burner wind box 40 via a secondary burner air duct 42.
  • the secondary burner air AR1 (see Fig. 2 ) is supplied into the secondary burner wind box 40 by the secondary burner air fan 44.
  • Start and stop of the secondary burner air fan 44 is controlled by the control unit 15 (see Fig. 1 ). Further, the rotating speed of the secondary burner air fan 44 may be controlled by the control unit 15 to adjust the air flow rate.
  • a damper 46 that opens and closes a channel is provided to the outlet of the secondary burner air fan 44.
  • the opening and closing of the damper 46 is controlled by an instruction from the control unit 15.
  • One end of an air supply tube 48 is connected to a position that is downstream of the damper 46 and in the middle of the secondary burner air duct 42.
  • the other end of the air supply tube 48 is connected to a position in the middle of a primary burner air duct 50.
  • An on-off valve 49 is provided to the air supply tube 48.
  • the on-off valve 49 is controlled by the control unit 15.
  • a primary burner air fan 52 is connected to the upstream end of the primary burner air duct 50. Start and stop of the primary burner air fan 52 is controlled by the control unit 15 (see Fig. 1 ). Further, the rotating speed of the primary burner air fan 52 may be controlled by the control unit 15 to adjust the air flow rate.
  • a primary burner wind box 54 is connected to the downstream end of the primary burner air duct 50.
  • the primary burner 12 (see Fig. 1 ) is accommodated in the primary burner wind box 54. Air supplied to the primary burner wind box 54 is used as combustion air of the primary burner 12.
  • the control unit 15 adjusts combustion performed by the primary burner 12 and the secondary burner 13 to adjust the operation load of the boiler 10 in accordance with a load in which the steam generated by the boiler 10 is used.
  • the control unit 15 does not operate the primary burner 12 to be not in operation when a low load less than a predetermined value is demanded such as when a steam turbine for a cargo oil pump is not driven, for example. That is, no combustion by the primary burner 12 is performed. At this time, the boiler 10 is warmed up by the secondary burner 13.
  • the control unit 15 operates only the secondary burner 13 to combust a fuel oil and/or a fuel gas. Accordingly, it is possible to operate the primary burner 12 and promptly supply steam from the boiler 10 when a steam turbine needs to be driven or the like, for example, while warming up the boiler 10 by using the small capacity secondary burner 13 without using the large capacity primary burner 12 to suppress fuel consumption.
  • the control unit 15 When a high load above a predetermined value is demanded such as when a steam turbine for a cargo oil pump is required to be driven, for example, the control unit 15 gradually increases the supply amount of the fuel oil and/or the fuel gas to the primary burner 12 in accordance with an increase in the load of the steam turbine (increase in the operation load demanded for the boiler 10). In such a way, when only the primary burner 12 is used for combustion, the control unit 15 supplies air from the secondary burner air fan 44 to cool the secondary burner 13. At this time, the fuel oil and the fuel gas are not supplied to the secondary burner 13. The control unit 15 controls the secondary burner air fan 44 so that the pressure in the secondary burner wind box 40 is higher than the pressure in the combustion vessel 11.
  • the air supplied to the secondary burner wind box 40 cools the secondary burner 13 and is then supplied near the lower end of the flame F1 formed by the primary burner 12. As a result, the flame is cooled near the lower end of the flame F1, and thereby, the NOx production amount due to the combustion by the primary burner 12 is reduced.
  • control unit 15 detects the failure of the secondary burner air fan 44
  • the control unit 15 operates the on-off valve 49 provided to the air supply tube 48 from fully closed to fully open. This causes a part of the air supplied from the primary burner air fan 52 to be supplied to the secondary burner wind box 40 via the air supply tube 48 and the secondary burner air duct 42.
  • the control unit 15 operates the damper 46 from fully open to fully closed. This prevents the air from flowing back to the secondary burner air fan 44. Note that it is possible to detect a failure of the secondary burner air fan 44 by monitoring the fan rotating speed or the like.
  • the secondary burner 13 is provided downstream of the flame F1 formed by the primary burner 12.
  • the secondary burner 13 is provided downstream of the flame F1 formed by the primary burner 12.
  • the primary burner 12 when the primary burner 12 is in operation and the secondary burner 13 is not in operation, there is a risk of damage to the secondary burner 13 due to radiation heat of the flame F1 from the primary burner 12 if no combustion air is supplied to the secondary burner 13.
  • air is supplied from the secondary burner air fan 44 to cool the secondary burner 13.
  • the secondary burner 13 and the secondary burner wind box 40 can be sealed from the pressurized combustion chamber 24. This can avoid a risk of entry (flowing back) of the combustion gas of the primary burner 12 to the secondary burner 13 when the pressure in the secondary burner wind box 40 is lower than the pressure in the combustion vessel 11.
  • the air supply tube 48 is used to supply air from the primary burner air fan 52 to the secondary burner wind box 40. Accordingly, if the secondary burner air fan 44 should fail, a cooling air can be supplied to the secondary burner wind box 40.
  • air may be supplied from the primary burner air fan 52 to the secondary burner wind box 40 when the air amount supplied from the secondary burner air fan 44 is insufficient.
  • the damper 46 is provided to the outlet of the secondary burner air fan 44. Accordingly, by closing the damper 46 when the secondary burner air fan 44 is stopped, the air guided from the primary burner air fan 52 via the air supply tube 48 can be prevented from flowing back to the secondary burner air fan 44 side.
  • the present embodiment differs from the first embodiment in that the present embodiment has a feature to cool the secondary burner 13 by using steam in addition to the features of the first embodiment. Therefore, features different from the first embodiment will be described below.
  • Fig. 5 illustrates a system that supplies a fuel oil to the oil ejection nozzle 13a (see Fig. 3 ) provided to the secondary burner 13.
  • a fuel oil supply path 60 and a steam supply path (cooling steam supply unit) 62 are connected to the oil ejection nozzle 13a.
  • An oil tank and an oil supply pump (not illustrated) are connected to the upstream of the fuel oil supply path 60.
  • the fuel oil supply path 60 is provided with a control valve 64.
  • the control valve 64 is controlled by the control unit 15.
  • a steam source (not illustrated) is connected to the upstream of the steam supply path 62.
  • the steam supply path 62 is branched into an atomize steam supply path 62a and a purge steam supply path 62b.
  • the atomize steam supply path 62a is connected to the oil ejection nozzle 13a.
  • the atomize steam supply path 62a is provided with a control valve 66 and a check valve 67 controlled by the control unit 15.
  • the steam supplied from the atomize steam supply path 62a is originally used for atomizing a fuel oil. In the present embodiment, however, such steam can be used as cooling steam.
  • the downstream end of the purge steam supply path 62b is connected to the fuel oil supply path 60.
  • the purge steam supply path 62b is provided with a control valve 68 and a check valve 69 controlled by the control unit 15.
  • the steam supplied from the purge steam supply path 62b is originally used for purging, with steam, a path in which a fuel oil flows. In the present embodiment, however, such steam can be used as cooling steam.
  • the steam cooling of the secondary burner 13 according to the present embodiment is performed as follows.
  • the control unit 15 causes the oil ejection nozzle 13a to eject steam by using the steam supply path 62. Specifically, the control valve 66 of the atomize steam supply path 62a is opened and the control valve 68 of the purge steam supply path 62b is opened to guide steam to the oil ejection nozzle 13a. The steam is atomized from the oil ejection nozzle 13a, and thereby, the secondary burner 13 is protected from radiation heat radiated from the flame F1 formed in the combustion chamber 24.
  • the oil ejection nozzle 13a of the secondary burner 13 is not supplied with any oil when the secondary burner 13 is not in operation, the oil ejection nozzle 13a is provided as a part of the cooling steam supply unit to supply cooling steam from the oil ejection nozzle 13a. Since the oil ejection nozzle 13a ejects cooling steam from the tip of the secondary burner 13 into the combustion chamber 24, the secondary burner 13 can be effectively protected from radiation heat.
  • steam may be supplied from the gas ejection nozzle 13b (see Fig. 3 ) of the secondary burner 13.
  • the gas ejection nozzle 13b can be a part of the cooling steam supply unit and supply cooling steam from the gas ejection nozzle 13b. Since the gas ejection nozzle 13b ejects cooling steam from the tip of the secondary burner 13 into the combustion chamber 24, the secondary burner 13 can be effectively protected from radiation heat. Further, the gas ejection nozzle 13b projecting in the combustion chamber 24 can be effectively cooled.
  • the present embodiment differs from the first embodiment in that the present embodiment has a feature to cool the secondary burner 13 by using steam in addition to the features of the first embodiment. Therefore, features different from the first embodiment will be described below.
  • a steam ring nozzle (steam supply nozzle) 72 is provided in the secondary burner wind box 40.
  • the steam ring nozzle 72 is connected to a steam source (not illustrated) and ejects steam from the secondary burner wind box 40 into the combustion chamber 24.
  • the steam ring nozzle 72 has a ring-shaped pipe, and a plurality of ejection holes 72a are formed to the pipe at predetermined intervals.
  • the steam ring nozzle 72 is arranged so as to surround the base part of the secondary burner 13.
  • the steam ring nozzle 72 is provided as a part of the cooling steam supply unit in the secondary burner wind box 40. This enables cooling of the secondary burner 13 accommodated in the secondary burner wind box 40.
  • cooling steam can be supplied to the whole secondary burner 13 by the steam ring nozzle 72, a portion that is likely to be damaged by radiation heat of the flame of the primary burner 12, such as a swirler or the gas ejection nozzle 13b, can be effectively cooled. Further, a flame cooling effect due to steam blowing also extends to a wide area, and this enables a reduction of NOx.
  • a path used for supplying cooling steam can be provided separately from the oil ejection nozzle 13a or the gas ejection nozzle 13b of the secondary burner 13, the cooling steam can be supplied regardless of the operation of the secondary burner 13. By blowing steam when the secondary burner 13 is in operation, this enables the secondary burner 13 itself to reduce NOx.

Landscapes

  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Thermal Sciences (AREA)
  • Gas Burners (AREA)
  • Combustion Of Fluid Fuel (AREA)
EP20760113.9A 2019-02-22 2020-01-08 Boiler Active EP3913283B1 (en)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
JP2019030836A JP7292898B2 (ja) 2019-02-22 2019-02-22 ボイラ
PCT/JP2020/000220 WO2020170622A1 (ja) 2019-02-22 2020-01-08 ボイラ

Publications (3)

Publication Number Publication Date
EP3913283A1 EP3913283A1 (en) 2021-11-24
EP3913283A4 EP3913283A4 (en) 2022-03-09
EP3913283B1 true EP3913283B1 (en) 2022-12-28

Family

ID=72144409

Family Applications (1)

Application Number Title Priority Date Filing Date
EP20760113.9A Active EP3913283B1 (en) 2019-02-22 2020-01-08 Boiler

Country Status (6)

Country Link
EP (1) EP3913283B1 (ja)
JP (1) JP7292898B2 (ja)
KR (1) KR102551979B1 (ja)
CN (1) CN113439180B (ja)
DK (1) DK3913283T3 (ja)
WO (1) WO2020170622A1 (ja)

Family Cites Families (20)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JPS5523870A (en) * 1978-08-10 1980-02-20 Babcock Hitachi Kk Burner unit
JPS5747107A (en) * 1980-09-01 1982-03-17 Babcock Hitachi Kk Boiler generating low nox exhaust gas
JPS5781999U (ja) 1980-11-07 1982-05-20
JPS58122804U (ja) * 1982-02-09 1983-08-20 日立造船株式会社 ボイラの燃焼装置
JPS59170601A (ja) * 1983-03-18 1984-09-26 三菱重工業株式会社 ボイラ
JPH0330647Y2 (ja) * 1986-04-16 1991-06-28
JPH01121612A (ja) * 1987-11-05 1989-05-15 Mitsubishi Heavy Ind Ltd ボイラ用バーナ装置
US5308239A (en) * 1992-02-04 1994-05-03 Air Products And Chemicals, Inc. Method for reducing NOx production during air-fuel combustion processes
JPH09210325A (ja) * 1996-02-07 1997-08-12 Asahi Chem Ind Co Ltd バーナ装置とバーナ運転方法
JPH09264516A (ja) * 1996-03-28 1997-10-07 Hitachi Zosen Corp 燃料二段供給式低ＮＯｘバーナー
JP2005233483A (ja) * 2004-02-18 2005-09-02 Volcano Co Ltd バーナの燃焼制御方法
US20070224556A1 (en) * 2006-03-10 2007-09-27 Springstead Michael L Diffuser plate for boiler burner feed assembly
JP2008014574A (ja) * 2006-07-06 2008-01-24 Kashima Oil Co Ltd 燃焼方法、加熱方法、及び水蒸気改質炉
CN201193825Y (zh) * 2007-11-26 2009-02-11 单忠民 油气双燃型低NOx燃烧器
JP5022204B2 (ja) * 2007-12-17 2012-09-12 三菱重工業株式会社 舶用ボイラ構造
KR101383859B1 (ko) * 2011-06-27 2014-04-10 강림중공업 주식회사 2-드럼 타입의 선박용 보일러
JP6010489B2 (ja) * 2013-03-12 2016-10-19 三菱日立パワーシステムズ株式会社 熱電可変型コジェネレーションシステム
CN105841183A (zh) * 2016-05-25 2016-08-10 上海华之邦科技股份有限公司 一种降低NOx排放的雾/汽喷射系统
JP6243485B2 (ja) * 2016-07-11 2017-12-06 ボルカノ株式会社 混焼用バーナ装置及びボイラ
JP6879778B2 (ja) * 2017-02-28 2021-06-02 三菱重工マリンマシナリ株式会社 ボイラ及びボイラを備えた船舶並びにイナートガスの生成方法

Also Published As

Publication number Publication date
CN113439180A (zh) 2021-09-24
WO2020170622A1 (ja) 2020-08-27
CN113439180B (zh) 2023-12-01
KR102551979B1 (ko) 2023-07-05
DK3913283T3 (da) 2023-01-16
EP3913283A4 (en) 2022-03-09
JP2020134069A (ja) 2020-08-31
EP3913283A1 (en) 2021-11-24
KR20210114501A (ko) 2021-09-23
JP7292898B2 (ja) 2023-06-19

Similar Documents

Publication Publication Date Title
ES2340465T3 (es) Metodo para controlar la produccion de amoniaco a partir de urea para eliminar nox.
US20110053102A1 (en) Solid fuel burner, combustion apparatus using solid fuel burner, and method of operating the combustion apparatus
NO162887B (no) Stoetstraalekjoelt overgangskanal.
EP3913283B1 (en) Boiler
GB1292236A (en) Improvements in or relating to vapour generators
JP4489307B2 (ja) 化石燃料貫流ボイラ
JP5812844B2 (ja) 舶用ボイラ
JP4058681B2 (ja) 過熱低減器
EP3591291B1 (en) Boiler, ship comprising boiler, and inert gas generation method
KR101982955B1 (ko) 보일러, 이것을 구비한 선박용 증기 터빈 추진 시스템 및 이것을 구비한 선박 그리고 보일러 제어 방법
JP6995609B2 (ja) ボイラ
EP3929419B1 (en) System and method for controlling temperature in an air intake
JP2005273952A (ja) 減温装置
JP7319769B2 (ja) 排熱回収システム及び船舶並びに排熱回収装置の運転方法
EP3504479B1 (en) Overfire air system for low nitrogen oxide tangentially fired boiler
JPH1114007A (ja) ボイラの再熱蒸気温度制御装置
JP3694910B2 (ja) 加圧流動層ボイラの炉底部構造
JPH0989223A (ja) 高温空気バーナ
JP2004077096A (ja) 助燃バーナ付き排熱回収ボイラ
JPS6339811B2 (ja)
JP2008076020A (ja) 貫流式排熱回収ボイラ

Legal Events

Date Code Title Description
STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE INTERNATIONAL PUBLICATION HAS BEEN MADE

PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: REQUEST FOR EXAMINATION WAS MADE

17P Request for examination filed

Effective date: 20210819

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

A4 Supplementary search report drawn up and despatched

Effective date: 20220203

RIC1 Information provided on ipc code assigned before grant

Ipc: F22B 13/06 20060101ALI20220128BHEP

Ipc: F23D 14/78 20060101ALI20220128BHEP

Ipc: F22B 31/00 20060101AFI20220128BHEP

DAV Request for validation of the european patent (deleted)
DAX Request for extension of the european patent (deleted)
GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

RIC1 Information provided on ipc code assigned before grant

Ipc: F22B 13/06 20060101ALI20220728BHEP

Ipc: F23D 14/78 20060101ALI20220728BHEP

Ipc: F22B 31/00 20060101AFI20220728BHEP

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: GRANT OF PATENT IS INTENDED

INTG Intention to grant announced

Effective date: 20220901

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE PATENT HAS BEEN GRANTED

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

REG Reference to a national code

Ref country code: GB

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: CH

Ref legal event code: EP

REG Reference to a national code

Ref country code: DE

Ref legal event code: R096

Ref document number: 602020007244

Country of ref document: DE

REG Reference to a national code

Ref country code: AT

Ref legal event code: REF

Ref document number: 1540733

Country of ref document: AT

Kind code of ref document: T

Effective date: 20230115

REG Reference to a national code

Ref country code: DK

Ref legal event code: T3

Effective date: 20230110

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: LT

Ref legal event code: MG9D

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

Ref country code: NO

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20230328

Ref country code: LT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

Ref country code: FI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: DK

Payment date: 20230113

Year of fee payment: 4

REG Reference to a national code

Ref country code: NL

Ref legal event code: MP

Effective date: 20221228

REG Reference to a national code

Ref country code: AT

Ref legal event code: MK05

Ref document number: 1540733

Country of ref document: AT

Kind code of ref document: T

Effective date: 20221228

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: RS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

Ref country code: LV

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

Ref country code: HR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

Ref country code: GR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20230329

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SM

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

Ref country code: RO

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

Ref country code: PT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20230428

Ref country code: ES

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

Ref country code: EE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

Ref country code: CZ

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

Ref country code: AT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

REG Reference to a national code

Ref country code: DE

Ref legal event code: R119

Ref document number: 602020007244

Country of ref document: DE

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

Ref country code: PL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

Ref country code: IS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20230428

Ref country code: AL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

REG Reference to a national code

Ref country code: CH

Ref legal event code: PL

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MC

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

Ref country code: LU

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20230108

REG Reference to a national code

Ref country code: BE

Ref legal event code: MM

Effective date: 20230131

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LI

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20230131

Ref country code: DE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20230801

Ref country code: CH

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20230131

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: BE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20230131

26N No opposition filed

Effective date: 20230929

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20221228

Ref country code: IE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20230108

Ref country code: FR

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20230228