WO2019049300A1 - Procédé de combustion - Google Patents

Procédé de combustion Download PDF

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Publication number
WO2019049300A1
WO2019049300A1 PCT/JP2017/032407 JP2017032407W WO2019049300A1 WO 2019049300 A1 WO2019049300 A1 WO 2019049300A1 JP 2017032407 W JP2017032407 W JP 2017032407W WO 2019049300 A1 WO2019049300 A1 WO 2019049300A1
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WO
WIPO (PCT)
Prior art keywords
ammonia
combustion
boiler
gas
pipe
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Application number
PCT/JP2017/032407
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English (en)
Japanese (ja)
Inventor
博昭 谷川
泰孝 和田
優 大内
輝夫 田中
Original Assignee
中国電力株式会社
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.)
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Priority to PCT/JP2017/032407 priority Critical patent/WO2019049300A1/fr
Priority to JP2018500951A priority patent/JP6332578B1/ja
Publication of WO2019049300A1 publication Critical patent/WO2019049300A1/fr

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    • 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
    • F23C1/12—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 gaseous and pulverulent 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 
    • F23C5/00—Disposition of burners with respect to the combustion chamber or to one another; Mounting of burners in combustion apparatus
    • F23C5/08—Disposition of burners
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23D—BURNERS
    • F23D17/00—Burners for combustion conjointly or alternatively of gaseous or liquid or pulverulent fuel
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F23—COMBUSTION APPARATUS; COMBUSTION PROCESSES
    • F23K—FEEDING FUEL TO COMBUSTION APPARATUS
    • F23K5/00—Feeding or distributing other fuel to combustion apparatus

Definitions

  • the present invention relates to a combustion method.
  • a boiler of a power generation facility such as a thermal power plant generates high-temperature high-pressure steam using heat obtained by burning a fossil fuel such as coal, natural gas, light oil, heavy oil or the like with a burner.
  • burning these fossil fuels generates carbon dioxide, which causes global warming.
  • carbon credits for this reason, in recent years there has been a move to curb carbon dioxide in the form of carbon credits (emission allowances).
  • LNG liquefied natural gas
  • LPG liquefied petroleum gas
  • LNG is used as a fuel.
  • Gas fuels, such as LNG need to be liquefied for convenience in transportation.
  • ammonia has a low burning rate, specifically, for example, where the burning rate of propane is 40 cm / s, the burning rate of ammonia is only 8 cm / s. For this reason, the flame when burning ammonia becomes long. Therefore, in the case of co-firing ammonia with other fuels, for example, if a co-axial burner such as shown in FIG. 3 and FIG. Therefore, depending on the size and shape of the combustion space, incomplete combustion may occur.
  • an object of the present invention is to provide a power generation facility and a combustion method that minimize the generation and incomplete combustion of nitrogen oxides.
  • the present invention has the following configuration.
  • the boiler includes a pulverized coal injection nozzle for injecting the pulverized coal, and an ammonia injection nozzle for injecting the ammonia, and the ammonia injection nozzle is for the pulverized coal injected from the pulverized coal injection nozzle
  • an injection port for injecting the ammonia may be provided in the tangential direction of the circle.
  • FIG. 1 is a schematic view of a thermal power plant 1 of the embodiment.
  • the thermal power generation facility 1 of the embodiment is a system capable of combusting ammonia gas, but is a mixed-fired power generation facility 1 capable of combusting other than pulverized coal, oil, natural gas or ammonia gas such as BOG (boil off gas).
  • BOG snow off gas
  • the thermal power generation facility 1 is a gas fuel supply that supplies gaseous fuel other than ammonia gas through the ammonia gas supply facility 2, the ammonia gas fuel piping facility 3, the boiler 6, the denitration facility 90, and the gas fuel piping 170. It comprises a unit 70 and a control unit 7 that controls the whole.
  • the ammonia gas supply facility 2 includes a storage tank 10, a vaporizer 20, an accumulator 30, an ammonia gas absorbing unit 80, and the like.
  • the ammonia gas absorbing unit 80 is a water storage tank for absorbing ammonia gas emitted from the blow valve 81 or the like provided in the ammonia gas supply facility 2 into water.
  • the storage tank 10 stores pressurized and liquefied liquid ammonia, and is connected to the vaporizer 20 through a pipe 110.
  • the pipe 110 is branched in two directions along the way.
  • a vaporizer start valve 11 and a vaporizer pressure control valve 12 for controlling the pressure in the vaporizer 20 are sequentially disposed from the upstream side.
  • a vaporizer bypass valve 13 is disposed in the other branched pipe 110b.
  • the vaporizer 20 heats and vaporizes the liquid ammonia supplied from the storage tank 10.
  • liquid ammonia is heated through the inside of a coiled pipe immersed in warm water and vaporized to be ammonia gas.
  • the downstream side of the vaporizer 20 is connected to the accumulator 30 via a pipe 120.
  • the pipe 120 is branched in two directions along the way.
  • An accumulator start valve 21 and an accumulator pressure control valve 22 for controlling the pressure in the accumulator 30 are sequentially disposed from the upstream side in one branched pipe 120 a.
  • An accumulator bypass valve 23 is disposed in the other branched pipe 120b.
  • the accumulator 30 is a device that accumulates ammonia gas and stabilizes the pressure.
  • a pipe 130 extends from the downstream side of the accumulator 30.
  • the pipe 130 is branched in two directions.
  • One branched pipe 132 is connected to the header 40.
  • the other branched pipe 131 is connected to the ammonia gas fuel pipe arrangement 3.
  • the pipe 140 is connected to the downstream side of the header 40, and the pipe 140 is branched into a plurality of denitration pipes 141, 142, 143, and the denitration pipes 141, 142, 143 respectively have denitration shutoff valves 41, 42, 43. It is connected to the denitrification equipment 90 through.
  • NOx removal pipes 141, 142 and 143 are connected to NOx removal units 91, 92 and 93, respectively.
  • the exhaust gas generated by combustion from the boiler 6 is fed into the denitration devices 91, 92, 93, and ammonia is introduced from the piping of the denitration piping 141, 142, 143 in which the denitration shutoff valves 41, 42, 43 are open.
  • the gas as a reducing agent nitrogen oxides in the exhaust gas are converted into harmless nitrogen gas and water.
  • Ammonia gas fuel piping system 3 As described above, the pipe 131 branched from the pipe 130 extending from the accumulator 30 is connected to the ammonia gas fuel pipe arrangement 3. A shutoff valve 31 is provided upstream of the pipe 131. On the downstream side of the shutoff valve 31, a purge pipe 133 extending from a purge gas supply unit 37 capable of flowing a purge gas such as nitrogen gas into the ammonia gas fuel piping installation 3 is connected via a purge valve 36.
  • the downstream side of the connection portion of the pipe 131 to which the purge pipe 133 is connected is branched in two directions.
  • a pressure control valve 32 is disposed in one of the branched pipes 131a.
  • a shutoff valve 33 is disposed in the other branched pipe 131b. The pipe 131 a and the pipe 131 b rejoin on the downstream side. The joined pipe 131 is connected to the flow meter 50 via the shutoff valve 34.
  • the flow meter 50 measures the flow rate of the gas flowing through the pipe 131.
  • a pipe 150 extends from the downstream side of the flow meter 50.
  • the piping 150 is branched in two directions along the way.
  • a flow control valve 51 is disposed in one of the branched pipes 150a.
  • a shutoff valve 52 is disposed in the other branched pipe 150b. The pipe 150 a and the pipe 150 b rejoin on the downstream side.
  • the downstream side of the joined pipe 150 is branched in two directions by the second connection portion 56.
  • One branched pipe is an ammonia gas outflow pipe 151 a, and is connected to the ammonia gas absorbing unit 80 of the ammonia gas supply facility 2 via an ammonia outflow blocking valve 55.
  • the ammonia gas absorbing unit 80 is a water storage tank, and dissolves ammonia gas in water.
  • a burner valve 53 is disposed in the other branched ammonia gas supply pipe 151b.
  • a cooling pipe 160 to which cooling air is introduced is connected via a cooling air valve 61.
  • the ammonia gas outflow pipe 151 a may be branched downstream of the burner valve 53.
  • the downstream side of the ammonia gas supply pipe 151 b is connected to the first connection portion 72 of the gas fuel pipe 170 extending from the gas fuel supply unit 70 to the burner 62 A of the boiler 6 via the shutoff valve 54.
  • the gas fuel supply unit 70 stores LNG (liquefied natural gas). When LNG is liquefied and stored, the LNG is vaporized by natural heat input from the outside, etc., and BOG off gas is generated.
  • the gas fuel pipe 170 is a pipe that sends the BOG as a fuel to the burner 62A.
  • the gas fuel pipe 170 is connected to the burner 62 A of the boiler 6 at the downstream side of the first connection portion 72.
  • a gas fuel pipe shutoff valve 71 is disposed upstream of the first connection portion 72 in the gas fuel pipe 170.
  • FIG. 2A is a view for explaining an arrangement example of the four-stage burners 62.
  • coal pulverized coal
  • gas fuel is further supplied to the topmost four burners 62A.
  • the gas ring 171 provided at the tip of the gas fuel pipe 170 is arranged in an arc at the outermost part of each of the burners 62A, and the five burner nozzles 172 branch from the gas ring 171.
  • An injection port 173 is provided at the tip of 172.
  • ammonia is co-fired by injecting ammonia from one of the five injection ports 173 of the burner 62A located at the rightmost side in FIG. 2A.
  • FIG. 2B is a configuration example of the burner 62A present at the rightmost side in FIG. 2A, and more specifically, shows a layout diagram of each component when the burner 62A is viewed from the opposite side to the furnace.
  • a gas ring 171 is provided at the end of the gas fuel pipe 170, and five burner nozzles 172A to 172E branch from the gas ring 171. Further, the burner nozzle 172A is connected to the injection port 173A, the burner nozzle 172B to the injection port 173B, the burner nozzle 172C to the injection port 173C, the burner nozzle 172D to the injection port 173D, and the burner nozzle 172E to the injection port 173E.
  • a pulverized coal burner nozzle 175 is provided at the center of the pentagon formed by the injection ports 173A to 173E so as to surround the heavy oil burner 174. Note that, hereinafter, the pulverized coal burner nozzle 175 may be referred to as "pulverized coal injection nozzle 175".
  • each of the burner nozzles 172A to 172E is provided with gas fuel piping shutoff valves 71A to 71E.
  • ammonia gas supply pipe 151b is connected to the burner nozzle 172B at the first connection portion 72 provided downstream of the gas fuel pipe shutoff valve 71B.
  • the burner nozzle 172B may be referred to as "ammonia injection nozzle 172B".
  • the ammonia gas supply pipe 151 b is provided with the shutoff valve 54, the return pipe 176 is branched upstream of the shutoff valve 54, and the shutoff valve 177 is provided in the return pipe 176.
  • the return pipe 176 is a pipe used when the ammonia gas is not supplied to the burner nozzle 172B from the ammonia gas supply pipe 151b.
  • the shutoff valve 54 is closed and the shutoff valve 177 is opened.
  • ammonia gas is supplied to the burner nozzle 172B, as shown in FIG. 2B, the shutoff valve 54 is opened, and the gas fuel pipe shutoff valve 71B and the shutoff valve 177 are closed.
  • the burner nozzle to which ammonia is supplied is one (172B) of the five burner nozzles 172 constituting the burner 62A
  • the embodiment of the present invention is not limited thereto.
  • Ammonia may be supplied to any number of burner nozzles 172 among the plurality of burner nozzles 172 constituting the burner 62A.
  • the plurality of burners 62A provided in the uppermost stage of the boiler 6 not only the rightmost burner 62A but also any number of burners 62A may mix and burn ammonia. More specifically, it is desirable to supply ammonia to one burner nozzle 172 not only in the rightmost burner 62A of the first stage but also in the other burners 62A.
  • all the burners 62A a total of four burners It is more desirable to supply ammonia to the five burner nozzles 172 at 62. Furthermore, it is possible to mix and burn ammonia not only in the burner 62A but also in the burners 62B to 62D.
  • FIG. 2C is an example of a cross-sectional view of the burner 62 in the long axis direction, and the right side of FIG. 2C corresponds to the furnace side of the boiler 6.
  • a burner nozzle 172B (ammonia injection nozzle 172B) connected to the gas ring 171 in the lower part has a heavy oil burner 174 at the center and a pulverized coal burner nozzle 175 (fine powder) so as to surround the heavy oil burner 174.
  • a coal injection nozzle 175) is a coal injection nozzle 175.
  • the burner nozzle 172B extends from the gas ring 171 in the direction opposite to the furnace and then bends to the furnace side, but the gas fuel pipe shut-off valve 71B is provided at the extension to the opposite side of the furnace and the first connection portion is bent 72 are provided.
  • the ammonia gas supply pipe 151b is connected to the burner nozzle 172B.
  • the burner nozzle 172B extends to the furnace side through the bent portion, and reaches the injection port 173B.
  • Ammonia gas is supplied from the ammonia gas supply pipe 151b to the injection port 173B through the first connection portion 72 and the extending portion of the burner nozzle 172B in the furnace direction, as shown by the arrow in FIG. 2C, and the injection port It is injected from 173B.
  • pulverized coal is injected from the pulverized coal burner nozzle 175.
  • FIG. 2D shows a configuration example of the burner 62A viewed from the furnace side, and corresponds to the back side of the configuration example shown in FIG. 2B. Also, in FIG. 2D, solid arrows indicate the flow of ammonia gas, and solid circles indicate the contour of a cross section perpendicular to the length direction of the pulverized coal flame.
  • the shutoff valve 54 provided in the ammonia gas supply pipe 151b is opened, and the gas fuel pipe shutoff valve 71B provided in the burner nozzle 172B and the shutoff valve 177 provided in the return pipe 176 are closed.
  • the ammonia gas is supplied to the injection port 173B via the ammonia gas supply pipe 151b, the first connection portion 72, and the burner nozzle 172B.
  • the injection port 173B is tangential to this circle. Ammonia is injected into the
  • Ammonia is injected so as to draw a spiral locus around the pulverized coal flame, and the combustion distance of the ammonia is increased, whereby the combustion time of the ammonia is secured and the ammonia can be completely burned.
  • the test period is 7 days, from 13 o'clock to 17 o'clock on the first day, from 10 o'clock to 17 o'clock on the second day to 6 o'clock, and from 10 o'clock to 13 o'clock on the seventh day
  • a maximum of 450 kg / h of ammonia (note that this is the maximum flow rate of the vaporizer 20 and corresponds to 400 kg of coal) was used. More specifically, 100 kg / h of ammonia is burned from 13 o'clock to 15 o'clock on the first day, and 200 kg / h of ammonia is burned from 15 o'clock to 16 o'clock on the first day.
  • liquid ammonia used for combustion has a purity of 99.98%, water content of 0.016%, and an oil content of less than 1.0 ppm, and coal species co-fired with ammonia is 60% for mount oren, and Bocabri premium Is 40%.
  • Boiler metal temperature The temperature of the metal portion of the piping or the like provided in the boiler 6, that is, the boiler metal temperature was measured at the time of coal-only combustion and at the time of mixed combustion of ammonia and coal. There are six measurement points: a primary superheater outlet, a reheater outlet, a secondary superheater inlet, a secondary superheater middle, and a secondary superheater outlet.
  • the boiler metal temperature at the primary superheater outlet is 400 to 450 ° C
  • the boiler metal temperature at the reheater outlet is 500 to 550 ° C
  • the boiler heat at the secondary superheater inlet The metal temperature is 400 to 450 ° C
  • the boiler metal temperature in the middle of the secondary superheater is 450 to 500 ° C
  • the boiler metal temperature at the outlet of the secondary superheater is 500 to 600 ° C.
  • the boiler metal temperature at the primary superheater outlet is 400 to 450 ° C
  • the boiler metal temperature at the reheater outlet is 500 to 600 ° C
  • the boiler metal at the secondary superheater inlet The temperature is 400 to 450 ° C
  • the boiler metal temperature in the middle of the secondary superheater is 450 to 550 ° C
  • the boiler metal temperature at the outlet of the secondary superheater is 500 to 600 ° C. And there was almost no change.
  • FIG. 4 shows the amount of used coal per hour before and after mixed combustion, and the difference between the amounts of coal used.
  • table of (b) shows the numerical value used by the graph of (a) in a tabular form
  • table of (c) shows the average value of the day shown by the leftmost column in (c).
  • the reduction in the amount of coal used after co-firing compared to before co-firing was 0.50 T / h on average for 7 days. That is, 450 kg / h of the amount of ammonia combustion became almost the same as 500 kg / h (anhydrous) of the amount of reduction of coal. Also, comparing the 1st to 7th days, the amount of reduction of coal on the 5th day became the maximum value of 1.96T / h.
  • the coal type of coal used for the combustion is 60% of Mount Oen and 40% of Boca-Bri Premium.
  • the table of (b) shows the numerical values used in the graph of (a) in tabular form
  • the table of (c) shows the power plant output, the mixed combustion rate, and the leftmost column in (c) Mean of the difference between
  • the value before mixed combustion is a value 30 minutes before the injection of ammonia
  • the value after mixed combustion is an average value of data of 4 to 5 points taken every 30 minutes after the injection of ammonia.
  • ammonia co-firing rate when ammonia is co-fired with coal, it is desirable that the ammonia co-firing rate be 0.8% or more, and it is suggested that the NOx value can be reduced as the ammonia supply amount is increased. This is, 4NO + 4NH 3 + O 2 ⁇ 4N 2 + 6H 2 O It is presumed that the noncatalytic denitrification reaction has progressed as shown in the chemical reaction formula.
  • ammonia is injected in the tangential direction of the pulverized coal flame so that the ammonia draws a spiral locus around the pulverized coal flame, and the combustion time of the ammonia is secured by taking a long combustion distance of the ammonia. It is estimated that
  • FIG. 5 shows the composition of the exhaust gas from the boiler, the amount of injected ammonia, and the amount of CO 2 in the exhaust gas from the boiler.
  • the table of (b) shows the numerical values used in the graph of (a) in the form of a table. Where the initial amount of CO 2 is 12.8%, the mixed combustion rate of ammonia is 0.6% to 0.8%, so the amount of CO 2 is only about 0.1% which is the product of those numbers. It was not expected to decrease, but in practice it decreased by 0.2 to 1.3%.
  • the annual carbon dioxide reduction amount in the case where the mixed combustion rate is about 0.6% is about 3.99 (thousand t-CO 2 / year), and the annual carbon dioxide in the case where the mixed combustion rate is about 0.8%
  • the reduction amount was about 4.12 (thousand t-CO 2 / year).
  • the carbon dioxide emission factor was calculated using the emission factor by electric power company in FY 2015 (China Electric Power: 0.0007t-CO 2 / kWh) and the facility operation rate was 70%. Since it is possible to burn all mixed ammonia in the boiler, it is considered that carbon dioxide emissions can be reduced according to the ratio of mixed combustion.
  • the combustion method of the present embodiment is a combustion method executed by the thermal power generation facility 1 that generates power by burning pulverized coal and ammonia in the boiler 6, and the fine powder of ammonia used for combustion in the boiler 6
  • the rate of co-firing with charcoal is at least 0.8%.
  • the ammonia used for the combustion simultaneously has an effect of denitrifying NOx in the exhaust gas generated by the combustion, so that the ammonia can be effectively used.
  • the boiler 6 includes a pulverized coal burner nozzle 175 for injecting pulverized coal, and an ammonia injection nozzle 172B for injecting ammonia, and the ammonia injection nozzle 172B is a pulverized coal burner nozzle
  • an injection port 173B for injecting ammonia is provided in the tangential direction of this circle.
  • ammonia is injected so as to draw a spiral trajectory around the pulverized coal flame, and the combustion distance of the ammonia is increased, whereby the combustion time of the ammonia is secured and the ammonia is completely burned.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Combustion Of Fluid Fuel (AREA)

Abstract

L'invention concerne un procédé de combustion qui réduit au minimum la combustion incomplète et la production d'oxydes d'azote. Dans ce procédé de combustion, la combustion est effectuée dans une centrale thermique (1) qui produit de l'électricité par combustion de charbon pulvérisé et d'ammoniac dans une chaudière (6). Le rapport de combustion mixte de l'ammoniac au charbon pulvérisé utilisés dans la combustion dans la chaudière (6) est supérieur ou égal à 0,8 %.
PCT/JP2017/032407 2017-09-08 2017-09-08 Procédé de combustion WO2019049300A1 (fr)

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PCT/JP2017/032407 WO2019049300A1 (fr) 2017-09-08 2017-09-08 Procédé de combustion
JP2018500951A JP6332578B1 (ja) 2017-09-08 2017-09-08 燃焼方法

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Application Number Priority Date Filing Date Title
PCT/JP2017/032407 WO2019049300A1 (fr) 2017-09-08 2017-09-08 Procédé de combustion

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WO2019049300A1 true WO2019049300A1 (fr) 2019-03-14

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JP7081407B2 (ja) * 2018-09-11 2022-06-07 株式会社Ihi ボイラ
JP7485500B2 (ja) * 2018-09-11 2024-05-16 株式会社Ihi 燃焼装置及びボイラ
CN114893767B (zh) * 2022-05-10 2023-03-10 华中科技大学 一种带有折流结构的掺氨旋流燃烧器

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JPS58187709A (ja) * 1982-04-26 1983-11-02 Hitachi Ltd 石炭中窒素利用微粉炭燃焼方式
JPS62909U (fr) * 1985-06-17 1987-01-07
JP2016041990A (ja) * 2014-08-18 2016-03-31 東洋エンジニアリング株式会社 ボイラーを含む発熱装置
JP2016183839A (ja) * 2015-03-26 2016-10-20 一般財団法人電力中央研究所 微粉炭焚きボイラ装置及び発電設備
JP2016183840A (ja) * 2015-03-26 2016-10-20 一般財団法人電力中央研究所 発電設備

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JPS58187709A (ja) * 1982-04-26 1983-11-02 Hitachi Ltd 石炭中窒素利用微粉炭燃焼方式
JPS62909U (fr) * 1985-06-17 1987-01-07
JP2016041990A (ja) * 2014-08-18 2016-03-31 東洋エンジニアリング株式会社 ボイラーを含む発熱装置
JP2016183839A (ja) * 2015-03-26 2016-10-20 一般財団法人電力中央研究所 微粉炭焚きボイラ装置及び発電設備
JP2016183840A (ja) * 2015-03-26 2016-10-20 一般財団法人電力中央研究所 発電設備

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