WO2011111450A1 - 石炭火力発電プラント及び石炭火力発電プラントの運転方法 - Google Patents
石炭火力発電プラント及び石炭火力発電プラントの運転方法 Download PDFInfo
- Publication number
- WO2011111450A1 WO2011111450A1 PCT/JP2011/052472 JP2011052472W WO2011111450A1 WO 2011111450 A1 WO2011111450 A1 WO 2011111450A1 JP 2011052472 W JP2011052472 W JP 2011052472W WO 2011111450 A1 WO2011111450 A1 WO 2011111450A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- feed water
- exhaust gas
- steam
- temperature
- coal
- Prior art date
Links
Images
Classifications
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
- F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
- F01K7/00—Steam engine plants characterised by the use of specific types of engine; Plants or engines characterised by their use of special steam systems, cycles or processes; Control means specially adapted for such systems, cycles or processes; Use of withdrawn or exhaust steam for feed-water heating
- F01K7/34—Steam engine plants characterised by the use of specific types of engine; Plants or engines characterised by their use of special steam systems, cycles or processes; Control means specially adapted for such systems, cycles or processes; Use of withdrawn or exhaust steam for feed-water heating the engines being of extraction or non-condensing type; Use of steam for feed-water heating
- F01K7/40—Use of two or more feed-water heaters in series
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
- F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
- F01K13/00—General layout or general methods of operation of complete plants
- F01K13/02—Controlling, e.g. stopping or starting
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
- F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
- F01K7/00—Steam engine plants characterised by the use of specific types of engine; Plants or engines characterised by their use of special steam systems, cycles or processes; Control means specially adapted for such systems, cycles or processes; Use of withdrawn or exhaust steam for feed-water heating
- F01K7/34—Steam engine plants characterised by the use of specific types of engine; Plants or engines characterised by their use of special steam systems, cycles or processes; Control means specially adapted for such systems, cycles or processes; Use of withdrawn or exhaust steam for feed-water heating the engines being of extraction or non-condensing type; Use of steam for feed-water heating
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F22—STEAM GENERATION
- F22D—PREHEATING, OR ACCUMULATING PREHEATED, FEED-WATER FOR STEAM GENERATION; FEED-WATER SUPPLY FOR STEAM GENERATION; CONTROLLING WATER LEVEL FOR STEAM GENERATION; AUXILIARY DEVICES FOR PROMOTING WATER CIRCULATION WITHIN STEAM BOILERS
- F22D1/00—Feed-water heaters, i.e. economisers or like preheaters
- F22D1/003—Feed-water heater systems
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F22—STEAM GENERATION
- F22D—PREHEATING, OR ACCUMULATING PREHEATED, FEED-WATER FOR STEAM GENERATION; FEED-WATER SUPPLY FOR STEAM GENERATION; CONTROLLING WATER LEVEL FOR STEAM GENERATION; AUXILIARY DEVICES FOR PROMOTING WATER CIRCULATION WITHIN STEAM BOILERS
- F22D1/00—Feed-water heaters, i.e. economisers or like preheaters
- F22D1/02—Feed-water heaters, i.e. economisers or like preheaters with water tubes arranged in the boiler furnace, fire tubes, or flue ways
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F22—STEAM GENERATION
- F22D—PREHEATING, OR ACCUMULATING PREHEATED, FEED-WATER FOR STEAM GENERATION; FEED-WATER SUPPLY FOR STEAM GENERATION; CONTROLLING WATER LEVEL FOR STEAM GENERATION; AUXILIARY DEVICES FOR PROMOTING WATER CIRCULATION WITHIN STEAM BOILERS
- F22D1/00—Feed-water heaters, i.e. economisers or like preheaters
- F22D1/02—Feed-water heaters, i.e. economisers or like preheaters with water tubes arranged in the boiler furnace, fire tubes, or flue ways
- F22D1/12—Control devices, e.g. for regulating steam temperature
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F22—STEAM GENERATION
- F22D—PREHEATING, OR ACCUMULATING PREHEATED, FEED-WATER FOR STEAM GENERATION; FEED-WATER SUPPLY FOR STEAM GENERATION; CONTROLLING WATER LEVEL FOR STEAM GENERATION; AUXILIARY DEVICES FOR PROMOTING WATER CIRCULATION WITHIN STEAM BOILERS
- F22D1/00—Feed-water heaters, i.e. economisers or like preheaters
- F22D1/32—Feed-water heaters, i.e. economisers or like preheaters arranged to be heated by steam, e.g. bled from turbines
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F22—STEAM GENERATION
- F22D—PREHEATING, OR ACCUMULATING PREHEATED, FEED-WATER FOR STEAM GENERATION; FEED-WATER SUPPLY FOR STEAM GENERATION; CONTROLLING WATER LEVEL FOR STEAM GENERATION; AUXILIARY DEVICES FOR PROMOTING WATER CIRCULATION WITHIN STEAM BOILERS
- F22D1/00—Feed-water heaters, i.e. economisers or like preheaters
- F22D1/32—Feed-water heaters, i.e. economisers or like preheaters arranged to be heated by steam, e.g. bled from turbines
- F22D1/325—Schematic arrangements or control devices therefor
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F22—STEAM GENERATION
- F22D—PREHEATING, OR ACCUMULATING PREHEATED, FEED-WATER FOR STEAM GENERATION; FEED-WATER SUPPLY FOR STEAM GENERATION; CONTROLLING WATER LEVEL FOR STEAM GENERATION; AUXILIARY DEVICES FOR PROMOTING WATER CIRCULATION WITHIN STEAM BOILERS
- F22D1/00—Feed-water heaters, i.e. economisers or like preheaters
- F22D1/40—Combinations of exhaust-steam and smoke-gas preheaters
-
- 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
- F23J15/06—Arrangements of devices for treating smoke or fumes of coolers
-
- 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
- Y02E20/30—Technologies for a more efficient combustion or heat usage
Definitions
- the present invention relates to a coal-fired power plant and a method for operating the coal-fired power plant.
- Patent Document 1 discloses a feed water heater in an exhaust reburning combined cycle plant in which a gas turbine power plant is additionally installed in a steam turbine power plant.
- the combined cycle plant of Patent Document 1 heats the condensate by providing a bypass path in the condensate system and supplying the condensate to a heat recovery unit (exhaust gas cooler).
- a heat recovery unit exhaust gas cooler
- Patent Document 1 discloses a water supply adjustment valve that adjusts the amount of water supplied to the water heater side and the heat recovery device (exhaust gas cooler) side.
- Patent Document 1 does not disclose a method for adjusting the heat amount of exhaust gas recovered by a heat recovery device (exhaust gas cooler) and the heating amount of boiler feed water. Therefore, in the invention disclosed in Patent Document 1, when the exhaust gas temperature and the exhaust gas flow rate fluctuate due to the aging of the boiler, the temperature of the exhaust gas discharged from the boiler and the temperature of the water supplied to the boiler are controlled to a predetermined temperature. I could't.
- the dust collection efficiency of the downstream electric dust collector may decrease.
- a heat exchanger that does not assume that the water in the flow path evaporates into steam is provided in the boiler. Therefore, if the temperature of the water supplied to the boiler is higher than the design value, the supplied water evaporates (steams) in the boiler heat exchanger, and the heat exchanger may break down. On the other hand, if the temperature of the water supplied to the boiler is lower than the design value, the amount of water supplied to the boiler does not evaporate and is discharged as drain.
- An object of the present invention is to suppress deterioration of plant reliability and plant efficiency even when exhaust gas temperature and exhaust gas flow fluctuate due to aging of the boiler and the amount of heat recovered by the heat recovery unit provided in the flue fluctuates. is there.
- the present invention provides a first flow control valve that adjusts the amount of water flowing through the feed water bypass system, a second flow control valve that is provided in an extraction pipe that extracts steam from the steam turbine, and a downstream side of the heat recovery unit.
- a first temperature sensor provided, a second temperature sensor provided downstream of the feed water heater, and based on an exhaust gas temperature detected by the first temperature sensor and a feed water temperature detected by the second temperature sensor
- a control device for adjusting the opening degree of the first and second flow control valves is provided.
- the present invention even if the exhaust gas temperature and the exhaust gas flow rate fluctuate due to the aging of the boiler, and the amount of heat recovered by the heat recovery unit provided in the flue varies, the decrease in plant reliability and plant efficiency can be suppressed.
- Example 1 It is the schematic which shows a low voltage
- Example 2 It is a systematic diagram of a coal thermal power plant.
- a coal-fired power plant has an exhaust gas treatment device in order to remove environmentally regulated substances contained in the exhaust gas discharged from the boiler up to a regulation value.
- the exhaust gas treatment device has a denitration device that removes nitrogen oxides, an electric dust collector that removes combustion ash, and a desulfurization device that removes sulfur oxides.
- the exhaust gas treatment device is also provided with a heat exchanger for using surplus heat of the exhaust gas.
- One of the heat exchangers is an air preheater that performs heat exchange between air supplied to the boiler and exhaust gas. By raising the temperature of the supply air using exhaust gas heat, the thermal efficiency of the boiler can be improved.
- GGH gas-gas heater
- the desulfurizer removes sulfur oxides by spraying an aqueous solution of limestone slurry on the flue by spraying. For this reason, at the outlet of the desulfurization apparatus, the moisture concentration in the exhaust gas increases, and the gas temperature also decreases. Therefore, when the exhaust gas discharged from the desulfurization apparatus is released into the atmosphere as it is, the water vapor is condensed at the smoke outlet and becomes white smoke. GGH suppresses the condensation of water vapor at the smoke outlet and prevents white smoke by raising the temperature of the low-temperature exhaust gas downstream from the desulfurizer to 100 degrees or more with the high-temperature exhaust gas upstream of the flue.
- This GGH uses water as a heat transfer medium and performs heat exchange between the upstream side and the downstream side of exhaust gas. That is, a heat recovery device for recovering heat from the high temperature exhaust gas is installed upstream of the flue, and the heat recovery device recovers heat from the high temperature exhaust gas and raises the temperature of the water. Furthermore, a reheater for raising the temperature of the low-temperature exhaust gas is installed on the downstream side of the flue (after the desulfurization device). The reheater heat-exchanges the high-temperature water that has passed through the heat recovery device and the low-temperature exhaust gas to raise the temperature of the low-temperature exhaust gas. Water as a heat transfer medium circulates in the heat recovery unit and the reheater. The heat recovery unit is often installed in front of the electric dust collector. This is because the dust collection efficiency of the electric dust collector depends on the gas temperature. The GGH heat recovery device can adjust (lower) the exhaust gas temperature to maximize the dust collection efficiency.
- GGH a power generation plant outside Japan where there is no white smoke prevention regulation, or a CO 2 recovery type coal-fired power generation plant in which a device for recovering and storing CO 2 in exhaust gas in order to suppress CO 2 emissions is installed, GGH is not provided.
- the following examples relate to a coal-fired power plant, and particularly to a plant having a feed water heater that contributes to improving the efficiency of the coal-fired power plant.
- Fig. 3 is a system diagram of a coal-fired power plant.
- the boiler 50 generates combustion gas using coal as fuel.
- the flue 54 is an exhaust gas system that guides exhaust gas discharged from the boiler 50 to the chimney 58.
- the exhaust gas treatment device 57 is a device that removes environmentally regulated substances contained in the exhaust gas discharged from the boiler 50 to a regulation value or less.
- the chimney 58 releases the exhaust gas treated by the exhaust gas treatment device 57 to the outside.
- the exhaust gas treatment device 57 includes not only the heat recovery device 5 and the electrostatic precipitator 6 but also a denitration device.
- the steam system 55 includes a steam turbine 12 and a condenser 51.
- the steam turbine 12 is driven by steam generated by the boiler 50.
- the condenser 51 condenses the steam discharged from the steam turbine 12.
- Condensate discharged from the condenser 51 is returned to the boiler 50 through the water supply system 11.
- the feed water system 11 includes a condensate pump 52 for supplying condensate, a low pressure feed water heater 10, and a high pressure feed water heater 53.
- the drain steam pipes 25 and 26 are pipes through which drain from the feed water heater flows.
- FIG. 1 is a schematic diagram showing a low-pressure feed water heater and related devices among the components of the coal-fired power plant shown in FIG.
- the coal-fired power plant boosts the condensate from the condenser 51 with the condensate pump 52 and first supplies the water to the low-pressure feed water heater 10 through the water supply system 11.
- the low-pressure feed water heater 10 includes a plurality of heat exchangers. These heat exchangers are called a first heat exchanger 1, a second heat exchanger 2, a third heat exchanger 3, and a fourth heat exchanger 4 in order from the heat exchanger located on the condenser side.
- the feed water heated by the low pressure feed water heater 10 is sent to the high pressure feed water heater 53.
- Each heat exchanger of the low-pressure feed water heater 10 heats feed water with steam extracted from the steam turbine 12.
- the extraction system 23 sends extraction steam to the first heat exchanger 1, and the extraction system 24 sends extraction steam to the second heat exchanger 2.
- the bleed pipes sent to the third and fourth heat exchangers are omitted.
- the extracted steam sent to the second heat exchanger 2 becomes drain after performing heat exchange with water supply. This drain is sent to the first heat exchanger 1 through the drain steam pipe 25.
- the feed water is heated using the drain from the second heat exchanger 2 and the extracted steam extracted from the extraction system 23.
- the drain discharged from the first heat exchanger 1 is finally sent to the condenser 51 through the drain steam pipe 26.
- Each heat exchanger of the low-pressure feed water heater 10 performs heat exchange between the extracted steam from the steam turbine 12 and the feed water flowing through the feed water system 11, but does not mix them.
- the water supply system of this embodiment branches on the upstream side of the low-pressure water heater 10. A part of the feed water flowing through the feed water system 11 is sent through the feed water bypass system 27 to the heat recovery unit 5 installed in the flue. The heat recovery unit 5 heats the feed water with the high-temperature exhaust gas, and then feeds the water to the feed water system 11 again.
- the water supply bypass system 27 is joined on the rear stage side of the second heat exchanger 2. However, the joining position of the feed water bypass system 27 and the feed water system 11 depends on the amount of heat collected that can be recovered from the exhaust gas.
- the feed water bypass system 27 may be joined on the further downstream side of the feed water system 11. Conversely, when the amount of heat recovered from the exhaust gas is small, the water supply bypass system 27 may be merged on the upstream side of the water supply system 11 (that is, the rear stage of the first heat exchanger 1).
- the amount of heat that can be recovered from the exhaust gas is the difference between the temperature of the exhaust gas entering the heat recovery device 5 and the appropriate value of the inlet exhaust gas temperature determined based on the dust collection efficiency of the electric dust collector 6 installed at the subsequent stage of the heat recovery device 5. And the exhaust gas flow rate.
- a temperature sensor for detecting the feed water temperature is installed at the feed water outlet of each heat exchanger constituting the low-pressure feed water heater 10.
- FIG. 1 representatively shows two temperature sensors 31 and 32.
- a temperature sensor 33 for detecting the inlet gas temperature of the electric dust collector is installed at the inlet of the electric dust collector.
- the temperature signals detected by the temperature sensors 31 to 33 are transmitted to the control device 7.
- the control device 7 adjusts the flow rate of the extracted steam so that the temperature detected by these temperature sensors becomes a predetermined value.
- the flow rate control valve 41 is a valve for adjusting the flow rate of the extracted steam supplied from the steam turbine 12 to the first heat exchanger 1.
- the flow rate control valve 42 is a valve for adjusting the extraction steam flow rate to the second heat exchanger 2.
- the flow rate control valve 43 is a valve for adjusting the feed water bypass flow rate that flows to the feed water bypass system 27.
- the control device 7 transmits an opening degree signal to the flow control valves 41, 42, and 43 so that the temperatures detected by the temperature sensors 31, 32, and 33 become a predetermined value.
- a part of the feed water sent from the condensate pump 52 is sent to the heat recovery unit 5 through the feed water bypass system 27.
- the gas temperature at the inlet of the electric dust collector is set so that the dust collection efficiency is maximized.
- the control device 7 controls the flow rate control valve 43 to adjust the feed water bypass flow rate so that the value of the temperature sensor 33 that detects the gas temperature at the inlet of the electric dust collector becomes the set value.
- the feed water bypass flow rate increases, the amount of heat exchange from the exhaust gas to the feed water increases, and the gas temperature at the inlet of the electric dust collector decreases.
- the feed water bypass flow rate decreases, the amount of heat exchange from the exhaust gas to the feed water decreases, and the gas temperature at the electric dust collector inlet increases.
- the feed water flow rate through the first heat exchanger 1 and the second heat exchanger 2 decreases.
- the control device 7 controls the flow rate control valves 41 and 42 so that the values of the temperature sensors 31 and 32 that detect the feed water outlet temperature of each heat exchanger become the set value, thereby controlling the extraction steam flow rate. adjust.
- the extraction steam flow rate decreases, the amount of heat supplied from the extraction steam to the feed water decreases, and the feed water temperature decreases. If the flow rate of the extracted steam from the steam turbine is reduced, the steam is used for power generation and the plant efficiency is increased.
- the flow rate control valve 43 for adjusting the amount of water flowing through the feed water bypass system 27, the flow rate control valves 41 and 42 provided in the extraction pipe for extracting steam from the steam turbine 12, and the heat recovery unit 5
- a temperature sensor 33 provided on the downstream side and temperature sensors 31 and 32 provided on the downstream side of the heat exchanger are provided. Based on the exhaust gas temperature detected by the temperature sensor 33 and the feed water temperature detected by the temperature sensors 31 and 32, A control device 7 for adjusting the opening degree of the flow control valves 41 to 43 is provided. In a coal-fired power plant, exhaust gas temperature and exhaust gas flow fluctuate due to aging of the boiler.
- the heat recovery device provided in the exhaust gas system fluctuates the amount of heat recovered from the exhaust gas, and affects the dust collection efficiency of the electric dust collector located on the downstream side.
- the amount of steam extracted from the steam turbine also affects the heat exchanger in the boiler. Therefore, by providing the above-described control device, it is possible to maintain the dust collection efficiency of the electric dust collector and to suppress the failure of the heat exchanger due to water evaporation (steaming) in the heat exchanger in the boiler. In addition, it is possible to avoid the phenomenon that the water supplied to the boiler is not completely evaporated and discharged as drain.
- the feed water heater is composed of a plurality of heat exchangers, and the temperature sensor is provided on the downstream side of each heat exchanger.
- the temperature sensor is provided on the downstream side of each heat exchanger.
- FIG. 2 is a schematic diagram showing a low-pressure feed water heating device and related devices among the components of the coal-fired power plant. Here, only a different part from Example 1 is demonstrated.
- Example 2 Although there was one heat recovery device of Example 1, a plurality of heat recovery devices of Example 2 are installed.
- the first heat recovery unit 8 is installed in parallel with the first heat exchanger 1
- the second heat recovery unit 9 is installed in parallel with the second heat exchanger 2.
- Water supply bypass systems 28 and 29 for supplying water to each heat recovery unit and flow rate control valves 44 and 45 for adjusting the flow rate of the water supply bypass are also installed.
- the plurality of flow rate control valves are controlled by the control device 7 and independently adjust the feed water bypass flow rate to the heat recovery unit.
- the control device 7 of the present embodiment adjusts the supply water flow rate to be supplied to the heat recovery device located on the high temperature side of the water supply system among the plurality of heat recovery devices.
- the feed water flow rate to the feed water heater (heat exchanger) installed in parallel with the heat recovery device decreases.
- heat amount required in order to heat feed water using the extraction steam of a steam turbine decreases, the flow volume of turbine extraction steam can be decreased.
- the second heat exchanger 2 has a greater contribution to improve the turbine output by reducing the extraction steam flow rate than the first heat exchanger 1.
- the water supply temperature rises on the downstream side of the water supply system compared to the upstream side.
- the extracted steam for heating the feed water requires higher temperature and pressure steam in the second heat exchanger 2 located on the high temperature side of the feed water system than in the first heat exchanger 1. It is. Therefore, by increasing the flow rate of feed water sent to the heat recovery unit located on the high temperature side of the feed water system, high temperature and high pressure steam is not used for feed water heating, but can be used for turbine rotational power, and the increase in turbine output can be increased. It can be enlarged.
- the contribution of the increase in turbine output can be increased by preferentially reducing the extraction steam at a higher temperature and pressure.
- the control method of this embodiment will be described. Also in the present embodiment, the point that the flow rate of the feed water pie bath is adjusted so that the inlet gas temperature of the electrostatic precipitator 6 in the exhaust gas treatment apparatus becomes a predetermined value is the same as in the first embodiment.
- the control device 7 when the inlet gas temperature of the electrostatic precipitator 6 is higher than a predetermined value and the feed water bypass flow rate is increased, the control device 7 operates to open the flow rate control valve 45 to the second heat recovery device 9. Increase the water supply bypass flow rate preferentially. At this time, in order to prevent the outlet feed water temperature of the second heat exchanger 2 from rising, the control device 7 controls the extraction steam flow control valve 42 in the closing direction to extract the extraction steam to the second heat exchanger 2. Reduce the flow rate and adjust the outlet water supply temperature to a predetermined value.
- the control device 7 has a lower limit value of the flow rate of the extracted steam supplied to the second heat exchanger 2.
- the control device 7 When the extracted steam flow rate reaches the lower limit value or when the lower limit value is not set, the control device 7 fully closes the flow control valve 42. When the extraction steam flow rate becomes 0, the control device 7 operates in a direction to open the flow rate control valve 44 to increase the amount of water supply bypass to the first heat recovery unit 8. Along with this, the flow rate of the extracted steam to the first heat exchanger 1 is reduced.
- the first heat recovery unit 8 is not capable of recovering heat from the exhaust gas when the second heat recovery unit 9 alone is insufficient in the amount of heat recovered from the exhaust gas, and the inlet gas temperature of the electrostatic precipitator does not decrease to a predetermined value. It has an assistant role to collect.
- the procedure is the reverse of the above control method.
- the control device 7 operates the flow rate control valve 44 to control the feed water bypass flow rate to the first heat recovery unit 8 to be reduced with priority over the second heat recovery unit 9.
- the extraction steam flow rate control valve 41 is controlled in the opening direction to increase the extraction steam flow rate to the first heat exchanger 1, The outlet water supply temperature is adjusted to a predetermined value.
- a lower limit value of the feed water bypass flow rate to the first heat recovery unit 8 is set in the control device 7.
- the control device 7 When the feed water bypass flow rate reaches the lower limit value or when the lower limit value is not set, the control device 7 fully closes the flow control valve 44. When the feed water bypass flow rate becomes zero, the control device 7 operates the flow control valve 45 in the closing direction to reduce the feed water bypass amount to the second heat recovery unit 9. Along with this, the control device 7 increases the flow rate of the extracted steam to the second heat exchanger 2.
- the feed water bypass flow rate of the heat exchanger located downstream of the feed water system is preferentially increased. Therefore, by reducing the higher-temperature / high-pressure turbine bleed steam, it is possible to increase the increase in the turbine output and realize a highly efficient plant operation.
- the present invention can be applied to a coal-fired power plant having a feed water heating device that heats feed water with exhaust gas heat.
Landscapes
- Engineering & Computer Science (AREA)
- Mechanical Engineering (AREA)
- General Engineering & Computer Science (AREA)
- Physics & Mathematics (AREA)
- Thermal Sciences (AREA)
- Chemical & Material Sciences (AREA)
- Combustion & Propulsion (AREA)
- Engine Equipment That Uses Special Cycles (AREA)
- Control Of Steam Boilers And Waste-Gas Boilers (AREA)
- Chimneys And Flues (AREA)
Abstract
Description
なる(視覚的公害と呼ばれる)。
を調整する。
2 第二熱交換器
3 第三熱交換器
4 第四熱交換器
5 熱回収器
6 電気集塵機
7 制御装置
8 第一熱回収器
9 第二熱回収器
10 低圧給水加熱器
11 給水系統
12 蒸気タービン
23,24 抽気系統
25,26 ドレン蒸気配管
27,28,29 給水バイパス系統
31,32,33 温度センサ
41,42,43,44,45 流量制御弁
Claims (6)
- ボイラから排出された排ガスを流す排ガス系統と、
前記ボイラが生成する蒸気によって蒸気タービンを駆動し、前記蒸気タービンを駆動した後に復水器へ蒸気を供給する蒸気系統と、
前記復水器によって復水された水を前記ボイラに供給する給水系統を備え、
前記給水系統は、前記蒸気タービンから抽気した蒸気によって水を昇温する熱交換器を有した給水加熱器を備え、
前記熱交換器の上流側は、前記排ガス系統を流れる排ガスと前記給水系統の水を熱回収器で熱交換させるために給水バイパス系統を備えた石炭火力発電プラントであって、
前記給水バイパス系統を流れる水量を調整する第1の流量制御弁と、前記蒸気タービンから蒸気を抽気する抽気管に設けられた第2の流量制御弁と、
前記熱回収器の下流側に設けられた第1の温度センサ,前記熱交換器の下流側に設けられた第2の温度センサを備え、
前記第1の温度センサが検出する排ガス温度、及び前記第2の温度センサが検出する給水温度に基づき、前記第1及び第2の流量制御弁の開度を調整する制御装置を設けることを特徴とする石炭火力発電プラント。 - 請求項1記載の石炭火力発電プラントであって、
前記給水加熱器は複数の熱交換器によって構成され、
前記第2の温度センサは、それぞれの前記熱交換器の下流側に設けていることを特徴とする石炭火力発電プラント。 - 請求項1記載の石炭火力発電プラントであって、
前記第1の流量制御弁は、前記熱回収器の下流側に設けられた電気集塵機の入口ガス温度に基づいて、その開度を制御することを特徴とする石炭火力発電プラント。 - 請求項1記載の石炭火力発電プラントであって、
前記第2の流量制御弁は、前記熱交換器から排出された給水温度に基づいて、その開度を制御することを特徴とする石炭火力発電プラント。 - 請求項1記載の石炭火力発電プラントであって、
複数の前記熱交換器と複数の前記熱回収器が対となって構成されており、それぞれの前記熱交換器の上流側で分岐する給水バイパス系統を有し、
前記制御装置は、複数の前記熱回収器のうち、前記給水系統の高温側に位置する前記熱回収器へ送る給水の流量をより増やすように調整することを特徴とする石炭火力発電プラント。 - ボイラから排出された排ガスを流す排ガス系統と、
前記ボイラが生成する蒸気によって蒸気タービンを駆動し、前記蒸気タービンを駆動した後に復水器へ蒸気を供給する蒸気系統と、
前記復水器によって復水された水を前記ボイラに供給する給水系統を備え、
前記給水系統は、前記蒸気タービンから抽気した蒸気によって水を昇温する熱交換器を有した給水加熱器を備え、
前記熱交換器の上流側は、前記排ガス系統を流れる排ガスと前記給水系統の水を熱回収器で熱交換させるために給水バイパス系統を備えた石炭火力発電プラントの運転方法であって、
前記熱回収器の下流側ガス温度、及び前記熱交換器の下流側の給水温度に基づき、
前記給水バイパス系統を流れる水量と、前記蒸気タービンから蒸気を抽気する抽気量を調整することを特徴とする石炭火力発電プラントの運転方法。
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/578,642 US20120324893A1 (en) | 2010-03-12 | 2011-02-07 | Coal-Fired Power Plant, and Method for Operating Coal-Fired Power Plant |
AU2011225455A AU2011225455B2 (en) | 2010-03-12 | 2011-02-07 | Coal-fired power plant, and method for operating coal-fired power plant |
EP11753112.9A EP2546477A4 (en) | 2010-03-12 | 2011-02-07 | COAL POWER PLANT AND OPERATING PROCEDURES FOR THE COAL POWER PLANT |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
JP2010055229A JP5260585B2 (ja) | 2010-03-12 | 2010-03-12 | 石炭火力発電プラント及び石炭火力発電プラントの運転方法 |
JP2010-055229 | 2010-03-12 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2011111450A1 true WO2011111450A1 (ja) | 2011-09-15 |
Family
ID=44563276
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/JP2011/052472 WO2011111450A1 (ja) | 2010-03-12 | 2011-02-07 | 石炭火力発電プラント及び石炭火力発電プラントの運転方法 |
Country Status (5)
Country | Link |
---|---|
US (1) | US20120324893A1 (ja) |
EP (1) | EP2546477A4 (ja) |
JP (1) | JP5260585B2 (ja) |
AU (1) | AU2011225455B2 (ja) |
WO (1) | WO2011111450A1 (ja) |
Cited By (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2017018253A1 (ja) * | 2015-07-29 | 2017-02-02 | 三菱日立パワーシステムズ株式会社 | 排ガスの潜熱回収装置 |
CN106524119A (zh) * | 2016-11-11 | 2017-03-22 | 华北电力科学研究院有限责任公司 | 辅机故障减负荷过程中给水流量的控制方法及装置 |
CN106838961A (zh) * | 2017-01-06 | 2017-06-13 | 上海羲蓝节能环保科技有限公司 | 一种火电厂超低排放精简式wggah节能环保设备及方法 |
CN109296411A (zh) * | 2018-07-31 | 2019-02-01 | 常州市新港热电有限公司 | 一种锅炉汽轮发电装置及发电方法 |
US10968783B2 (en) | 2016-03-25 | 2021-04-06 | Mitsubishi Power, Ltd. | Thermal power generation system and control method for same |
Families Citing this family (15)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US7506617B2 (en) * | 2007-03-09 | 2009-03-24 | Lochinvar Corporation | Control system for modulating water heater |
JP5783458B2 (ja) * | 2011-10-14 | 2015-09-24 | 東京電力株式会社 | 蒸気発電プラントにおける増出力運転方法 |
US20140060459A1 (en) * | 2012-09-06 | 2014-03-06 | Mitsubishi Heavy Industries, Ltd. | Heat recovery system and heat recovery method |
JP5994605B2 (ja) * | 2012-11-28 | 2016-09-21 | 宇部興産株式会社 | 発電システム |
CN103267271A (zh) * | 2013-06-05 | 2013-08-28 | 蓝秀文 | 冷凝式平衡型燃气蒸汽发生器 |
JP6163994B2 (ja) * | 2013-09-18 | 2017-07-19 | 株式会社Ihi | 酸素燃焼ボイラの排ガスクーラ蒸気発生防止装置 |
PL2942494T3 (pl) * | 2014-05-08 | 2020-03-31 | General Electric Technology Gmbh | Instalacja opalana mieszanką tlenowo-węglową z integracją ciepła |
EP2942495B1 (en) * | 2014-05-08 | 2018-10-10 | General Electric Technology GmbH | Coal fired oxy plant with heat integration |
EP2942497B1 (en) | 2014-05-08 | 2018-10-31 | General Electric Technology GmbH | Oxy boiler power plant oxygen feed system heat integration |
EP2942496B1 (en) * | 2014-05-08 | 2018-10-10 | General Electric Technology GmbH | Oxy boiler power plant with a heat integrated air separation unit |
US10378763B2 (en) * | 2015-12-03 | 2019-08-13 | General Electric Company | Method and apparatus to facilitate heating feedwater in a power generation system |
SE542257C2 (en) * | 2016-09-26 | 2020-03-24 | Clean Bio Heat Sverige Ab | Flue gas treatment system and method |
JP7039403B2 (ja) * | 2018-07-02 | 2022-03-22 | 株式会社東芝 | 火力発電プラント |
CN110726150A (zh) * | 2019-11-08 | 2020-01-24 | 江苏慧峰仁和环保科技有限公司 | 一种利用旁路热量加热一次风及凝结水的系统及方法 |
CN114184235B (zh) * | 2021-12-16 | 2023-09-22 | 内蒙古科技大学 | 一种沿空留巷侧采空区采集装置及方法 |
Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
JPS61205309A (ja) * | 1985-03-08 | 1986-09-11 | Hitachi Ltd | 給水加熱器の保護運転方法及びその装置 |
JPH05149501A (ja) * | 1991-11-28 | 1993-06-15 | Ishikawajima Harima Heavy Ind Co Ltd | 排気再燃型コンバインドサイクルプラント |
JPH062806A (ja) | 1992-06-22 | 1994-01-11 | Toshiba Corp | 給水加熱装置 |
JPH0953414A (ja) * | 1995-08-09 | 1997-02-25 | Mitsubishi Heavy Ind Ltd | タービン抽気制御装置 |
JP2009008365A (ja) * | 2007-06-29 | 2009-01-15 | Hitachi Ltd | 汽力プラント |
Family Cites Families (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5029535A (en) * | 1990-05-14 | 1991-07-09 | Wahlco, Inc. | Control of addition of conditioning agents to flue gas |
JP3065794B2 (ja) * | 1992-06-30 | 2000-07-17 | 株式会社東芝 | 給水加熱装置 |
WO2009125929A2 (ko) * | 2008-04-08 | 2009-10-15 | 이앤이텍 주식회사 | 환경 오염물 저감 시스템 |
-
2010
- 2010-03-12 JP JP2010055229A patent/JP5260585B2/ja not_active Expired - Fee Related
-
2011
- 2011-02-07 US US13/578,642 patent/US20120324893A1/en not_active Abandoned
- 2011-02-07 EP EP11753112.9A patent/EP2546477A4/en not_active Withdrawn
- 2011-02-07 WO PCT/JP2011/052472 patent/WO2011111450A1/ja active Application Filing
- 2011-02-07 AU AU2011225455A patent/AU2011225455B2/en not_active Ceased
Patent Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
JPS61205309A (ja) * | 1985-03-08 | 1986-09-11 | Hitachi Ltd | 給水加熱器の保護運転方法及びその装置 |
JPH05149501A (ja) * | 1991-11-28 | 1993-06-15 | Ishikawajima Harima Heavy Ind Co Ltd | 排気再燃型コンバインドサイクルプラント |
JPH062806A (ja) | 1992-06-22 | 1994-01-11 | Toshiba Corp | 給水加熱装置 |
JPH0953414A (ja) * | 1995-08-09 | 1997-02-25 | Mitsubishi Heavy Ind Ltd | タービン抽気制御装置 |
JP2009008365A (ja) * | 2007-06-29 | 2009-01-15 | Hitachi Ltd | 汽力プラント |
Non-Patent Citations (1)
Title |
---|
See also references of EP2546477A4 * |
Cited By (9)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2017018253A1 (ja) * | 2015-07-29 | 2017-02-02 | 三菱日立パワーシステムズ株式会社 | 排ガスの潜熱回収装置 |
JP2017032166A (ja) * | 2015-07-29 | 2017-02-09 | 三菱日立パワーシステムズ株式会社 | 排ガスの潜熱回収装置 |
US10514183B2 (en) | 2015-07-29 | 2019-12-24 | Mitsubishi Hitachi Power Systems, Ltd. | Exhaust gas latent heat recovery device |
US10968783B2 (en) | 2016-03-25 | 2021-04-06 | Mitsubishi Power, Ltd. | Thermal power generation system and control method for same |
CN106524119A (zh) * | 2016-11-11 | 2017-03-22 | 华北电力科学研究院有限责任公司 | 辅机故障减负荷过程中给水流量的控制方法及装置 |
CN106524119B (zh) * | 2016-11-11 | 2019-02-01 | 华北电力科学研究院有限责任公司 | 辅机故障减负荷过程中给水流量的控制方法及装置 |
CN106838961A (zh) * | 2017-01-06 | 2017-06-13 | 上海羲蓝节能环保科技有限公司 | 一种火电厂超低排放精简式wggah节能环保设备及方法 |
CN106838961B (zh) * | 2017-01-06 | 2019-08-23 | 上海羲蓝节能环保科技有限公司 | 一种火电厂超低排放精简式wggh节能环保设备及方法 |
CN109296411A (zh) * | 2018-07-31 | 2019-02-01 | 常州市新港热电有限公司 | 一种锅炉汽轮发电装置及发电方法 |
Also Published As
Publication number | Publication date |
---|---|
EP2546477A1 (en) | 2013-01-16 |
JP2011190696A (ja) | 2011-09-29 |
EP2546477A4 (en) | 2015-08-05 |
AU2011225455A1 (en) | 2012-09-13 |
JP5260585B2 (ja) | 2013-08-14 |
AU2011225455B2 (en) | 2014-10-23 |
US20120324893A1 (en) | 2012-12-27 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
JP5260585B2 (ja) | 石炭火力発電プラント及び石炭火力発電プラントの運転方法 | |
EP2375012B1 (en) | Boiler apparatus | |
JP4839273B2 (ja) | 汽力プラント | |
KR101920110B1 (ko) | 열 집적하는 석탄 연소 순산소 발전소 | |
KR101674705B1 (ko) | 배열 발전 방법 및 배열 발전 시스템 | |
KR101610613B1 (ko) | 화력 발전 플랜트 및 화력 발전 플랜트의 운전 방법 | |
JP2014009877A (ja) | 排煙処理装置と方法 | |
JP5523810B2 (ja) | コンバインドサイクル発電設備及びその給水加熱方法 | |
JP5852252B2 (ja) | 石炭焚きボイラ設備、石炭焚きボイラ設備における石炭の乾燥方法 | |
CN106090971A (zh) | 一种组合型蒸汽烟气mggh系统和方法 | |
CN106123002A (zh) | 一种采用凝结水换热的烟气mggh系统和方法 | |
US9151185B2 (en) | Steam power plant with steam turbine extraction control | |
JP2007248018A (ja) | 再燃ボイラの給水予熱器の制御装置 | |
JP2002206701A (ja) | 排ガス熱回収装置及び方法 | |
JP2014009624A (ja) | 廃熱利用方法、廃熱利用システム及びボイラ排ガスの処理方法 | |
KR20220100065A (ko) | 스팀 보일러 시스템을 작동하는 배열체 및 방법 | |
US20150330628A1 (en) | Oxy boiler power plant with a heat integrated air separation unit | |
JP2006250493A (ja) | 排熱回収ボイラ煤塵捕獲装置 | |
CN111495175A (zh) | 废气处理装置 | |
JP6526763B2 (ja) | ボイラプラント及びボイラプラント運転方法 | |
CN210688281U (zh) | 一种烟气处理系统 | |
JP2019090559A (ja) | ボイラ排ガス用熱交換器の温度制御装置 | |
JP6707058B2 (ja) | 廃熱ボイラ、廃熱回収システム、及び廃熱回収方法 | |
JPH0245763B2 (ja) | Jokitaabinpurantonokyusuikanetsukeito | |
Forman et al. | Reference Case Lignite-Fired Power Station |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
121 | Ep: the epo has been informed by wipo that ep was designated in this application |
Ref document number: 11753112 Country of ref document: EP Kind code of ref document: A1 |
|
WWE | Wipo information: entry into national phase |
Ref document number: 13578642 Country of ref document: US |
|
WWE | Wipo information: entry into national phase |
Ref document number: 2011753112 Country of ref document: EP |
|
WWE | Wipo information: entry into national phase |
Ref document number: 2011225455 Country of ref document: AU |
|
NENP | Non-entry into the national phase |
Ref country code: DE |
|
ENP | Entry into the national phase |
Ref document number: 2011225455 Country of ref document: AU Date of ref document: 20110207 Kind code of ref document: A |