EP2351914A1 - Kraftwerk und Verfahren zum Betrieb eines Kraftwerks - Google Patents

Kraftwerk und Verfahren zum Betrieb eines Kraftwerks Download PDF

Info

Publication number
EP2351914A1
EP2351914A1 EP10150416A EP10150416A EP2351914A1 EP 2351914 A1 EP2351914 A1 EP 2351914A1 EP 10150416 A EP10150416 A EP 10150416A EP 10150416 A EP10150416 A EP 10150416A EP 2351914 A1 EP2351914 A1 EP 2351914A1
Authority
EP
European Patent Office
Prior art keywords
steam
condensate
power plant
preheaters
coal
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.)
Granted
Application number
EP10150416A
Other languages
English (en)
French (fr)
Other versions
EP2351914B1 (de
Inventor
Jacques Mercier
Olivier Drenik
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.)
General Electric Technology GmbH
Original Assignee
Alstom Technology AG
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 Alstom Technology AG filed Critical Alstom Technology AG
Priority to EP10150416.5A priority Critical patent/EP2351914B1/de
Priority to PL10150416.5T priority patent/PL2351914T3/pl
Publication of EP2351914A1 publication Critical patent/EP2351914A1/de
Application granted granted Critical
Publication of EP2351914B1 publication Critical patent/EP2351914B1/de
Active legal-status Critical Current
Anticipated expiration legal-status Critical

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
    • 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
    • F01K7/40—Use of two or more feed-water heaters in series
    • 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
    • F22D1/32—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

Definitions

  • the present invention pertains to a power plant comprising a steam production unit, a steam turbine and water steam cycle, and in particular to a power plant of this type that is designed for dynamic response.
  • the invention pertains furthermore to a method of operating such power plant.
  • Power plants are operated and regulated such that they can provide power corresponding to the demand in electrical energy in the grid. Variations in the magnitude of the demand can occur for example when a large user is added or stopped, a large electricity producer trips, or a transmission line fails due to overload, disruption, or short circuit. Large variations in demand or supply of electricity typically result in a variation of the AC-frequency. In order to compensate for this frequency variation, power plants are designed to provide a dynamic response, which is the ability to respond to changes in the demand of electrical energy upon detection of the frequency variations and maintain a balance between the electrical energy drawn and electrical energy provided.
  • Variations in the energy drawn from the grid can be both large in magnitude as well as rapid, that is within a time span as short as a few seconds. They can occur when a number of large users alter their demand or other providers connected to the same grid decrease or stop their service. A dynamic response must be able to react to frequency changes by providing a load change of the power plants still connected to the grid within a short time.
  • grid codes are established by requiring that power plants be able to generate a minimum load response within a certain time frame when rapid frequency variations occur. Such grid code is given for example for the national grid in Great Britain. As documented in "The Grid Code", lssue 4, by the National Grid Electricity Transmission plc, it requires that a power plant operating between 65 and 90% of its nominal power be able to increase the power generated by 10% of its nominal power within 10 seconds. However, many power plants cannot fulfill such requirements because their system reaction times are too long and/or their load changes are too small in amplitude.
  • the live steam injected into the turbines is regulated by means of valves in the high-pressure steam inlet together with a control wheel.
  • This method allows partial steam injection enabling optimization of plant efficiency during part-load operation. It has proven successful up to certain power levels of the power plant. Above these power levels control wheels are no longer reliable. Power plants of greater power require a larger control wheel. However, the length of the blades of a control wheel is limited due to fatigue stresses, which can occur at super critical pressures.
  • the steam flow through the turbines is increased thereby providing a load increase.
  • opening a high-pressure throttle valve increases the live steam flow entering the high-pressure turbine.
  • the steam flow characteristics at the intermediate-pressure stage i.e. the temperature and pressure, adjust only after a full minute following the opening of the high-pressure throttle. Large load changes can therefore not be accommodated by this method within a short time.
  • condensate stop In another method, frequently referred to as condensate stop, a steam extraction from the steam turbines is stopped and the condensate flow extracted by the condensate pump is recirculated back to the condensate well.
  • the total amount of steam passing through the steam turbines is immediately increased and the power output of the generator is increased proportionally.
  • the recirculation of the condensate flow and therefore shutdown of the condensate flow through the condensate preheaters prevents a drop in the temperature of the feedwater in the feedwater tank. The temperature at the boiler inlet is therefore maintained.
  • a condensate stop can be maintained as long as the level in the feedwater tank remains above a critical level necessary to prevent a tripping of the boiler.
  • Condensate stop is an effective method to generate a load jump.
  • known condensate stop in power plants operating today is effective only over a short time period, that is on the order of a few minutes. This is due to the diminished steam extraction resulting in a drop in the feedwater tank level and an increase in condensate level in the condenser well.
  • a condensate stop can only be maintained until certain critical levels are reached in the feedwater tank and condenser well.
  • Presently operating power plants equipped for a condensate stop have several preheaters for the preheating of condensate and feedwater, where the feedwater tank is arranged following five condensate preheaters in series and prior to three feedwater preheaters.
  • Such power plants are able to provide a load jump by means of a condensate stop of up to 7% load increase and are able to maintain the increased power output for 6-8 minutes.
  • Such power plant design is based on thermodynamic and cost considerations, in particular the cost of fabrication and mounting of the feedwater tank. The design is furthermore based on considerations of the grid code requirements at the time of their construction.
  • DE 4344118 discloses a method of operating a power plant including condensate stop together with a control of the power reserve in order provide a primary frequency response.
  • the amount of high-pressure steam extracted for the preheating of feedwater is reduced or shut-off and a load increase is effected by the resulting increase of the high-pressure steam flowing through the high-pressure turbine.
  • a high-pressure preheater bypass can cause a drop in the feedwater temperature, which in turn can cause thermal stresses in the boiler.
  • a change in the feedwater temperature can be avoided by slow regulation of the throttle, which however causes the whole system to react only very slowly causing dead times until the frequency response takes effect.
  • the method is therefore suitable for slow frequency response only taking effect after many minutes.
  • a further method to provide a load jump is additional direct firing in the boiler itself. This can be done quickly when fossil fuels such as oil or gas are used.
  • direct firing is not suitable to generate a rapid load jump because coal milling facilities provide pulverized coal of given coal particle sizes only at a slow rate. Furthermore, coal mills can vary their milling speed only at a slow rate.
  • a power plant comprising a boiler and steam turbines with a water steam cycle designed to enable a high degree of dynamic response, that is to enable a rapid response to frequency variations in the grid by an appropriate load response.
  • a fossil fuel fired power plant having a water steam cycle comprises a boiler, one or more steam turbines, and low- and intermediate-pressure preheaters arranged in series for the preheating of condensate from the steam turbine condenser by means of steam extracted from the steam turbines.
  • six preheaters for the preheating of condensate are arranged in series following a condensate extraction pump, where lines for directing the steam extracted from the steam turbines to the preheaters are configured with quick-action valves.
  • the preheaters are operatable by means of heat exchange with low- and intermediate-pressure steam extracted from low- and intermediate-pressure stages of the one or more steam turbines. All of the steam extraction lines or less than six of the steam extraction lines to the preheaters are configured with valves allowing quick closure of the steam flow when a condensate stop is to be activated.
  • At least four steam extraction lines lead from the low- and intermediate-pressure turbine stages to two intermediate-pressure preheaters and to two low-pressure preheaters, which are arranged prior to the intermediate-pressure preheaters.
  • Each of these four extraction lines is configured with a quick-acting valve.
  • a condensate stop can be activated by closure of the quick-acting valves and stoppage of the extraction steam flow leading to the preheaters.
  • the power plant comprises a stop valve in the condensate extraction line leading away from the condensate extraction pump and a line for recirculating the condensate extracted from the condenser by a condensate extraction pump back into the condenser well.
  • the power plant according to the invention allows a stoppage of the condensate flow through the preheaters and an opening of the condensate recirculation line from the condensate extraction pump to the condenser well.
  • the load increase operation by means of condensate stop has no effect on the feedwater temperature in the boiler feedwater tank, and a drop in temperature of the water to the boiler is avoided.
  • this power plant has increased load jump capacity due to a condensate stop operation. Due to the large number of low- and intermediate-pressure preheaters and associated steam extraction lines, the power plant has an increased extraction steam flow. When this is closed off during a condensate stop operation, the extraction steam flow is stopped within a very short time. Instead, it flows through the steam turbines and effects a load increase. In other words, the power plant according to the invention has an increased steam reserve available when a frequency variation occurs and the condensate stop is activated. Consequently, a greater load jump can be realized. Compared to conventional power plants, the percentage increase in power output due to condensate stop can be increased in a power plant according to the invention, for example from a 6.5% to about 10% increase in power output.
  • two high-pressure heaters are arranged in series following the feedwater tank and configured for the preheating of feedwater by means of steam extracted from a high-pressure steam turbine.
  • the number of high-pressure preheaters for the preheating of the feedwater following the feedwater tank can be reduced to two. This power plant can be realized with greater cost efficiency compared to a power plant with three high-pressure preheaters.
  • four or more extraction lines lead from the intermediate-pressure turbine stages and from the low-pressure turbine stages to the preheaters, where the low-pressure turbine stages are the turbine stages immediately following the intermediate-pressure turbine stages.
  • Two more steam extraction lines lead from the low-pressure turbine stages of the lowest pressure level in the turbine train to the first low-pressure preheaters in the series of condensate preheaters.
  • the two steam extraction lines extend from the condenser neck of the steam turbine condenser. They can be configured without quick-acting valves.
  • the two steam extraction lines extend from the low-pressure steam turbines. One or both lines can be configured with a quick-action valve.
  • the power plant comprises additionally a steam extraction line leading from an intermediate-pressure turbine stage to the feedwater tank, where this extraction line is configured with a quick-acting valve. This can be closed in case of a condensate stop operation.
  • the power plant configuration according to the present invention may be applied to any power plant with a boiler that is fired by any fossil fuel such as coal, oil, gas, biomass, etc.
  • the power plant is a coal-fired power plant and comprises a combination of features enabling an improved dynamic response.
  • the coal-fired power plant is configured as described above to enable a large and fast load jump by means of condensate stop.
  • this power plant having a boiler with coal milling facilities, where at least one of the facilities comprises a coal supply container for receiving, storing, and dispensing a supply of pulverized coal that is already milled and pulverized to a given particle size and ready for combustion.
  • This power plant with supply container of pulverized coal allows an improved dynamic response of the power plant in that the firing rate in the boiler can be rapidly adjusted.
  • a condensate stop activated by means of closing the extraction lines to the low-pressure preheaters can be maintained for a period of time of several minutes. After a certain time, the level of feedwater in the feedwater tank drops while the level in the condensate well rises.
  • the supply container of pulverized coal which can be in the shape of a silo for example, provides a buffer source of coal ready for combustion such that the supply rate of coal to the boiler and thus also the firing rate of the boiler can be rapidly increased. In coal-fired boilers of the prior art, the supply rate is limited by the milling speed of the coal mill.
  • a buffer silo of already pulverized coal allows a higher rate of providing coal to the boiler for combustion.
  • the supply container of coal allows a rapid adjustment of the firing rate in the boiler and of the boiler steam production.
  • the rapidly adjusted firing rate can thereby support a load jump effected by a condensate stop.
  • the consumption of the feedwater from the tank can be adjusted and the water level in the feedwater tank can be maintained at a suitable level for a longer period of time. A drop of the feedwater level below a critical level, which could trip the boiler, can be avoided.
  • Another possibility of maintaining a minimum level in the feedwater tank during condensate stop would be to provide a larger feedwater tank as well as a larger condensate well. With the arrangement of the preheaters according to the invention together with the buffer coal supply this is not necessary. The feedwater tank as well as condensate well can be maintained with present volumes and wall thicknesses, which further supports cost efficiency of the power plant.
  • the power plant according to the invention has particular advantages in the case that it provides electrical energy to a grid, which is connected to a variety of renewable electrical energy sources such as wind, solar, tidal etc.
  • These energy sources are non-permanent energy sources, which means they provide energy depending on the weather conditions as well as day or night and rapid and large changes in the amount of energy provided can occur. Such changes can be compensated by the increased dynamic response of a power plant as presented, and a grid provided by such power plant can reach greater stability.
  • a buffer silo for pulverized coal allows an indirect coal-firing of the boiler, that is a firing of the boiler using pre-milled and pulverized coal, as opposed to a direct coal-firing by means of coal that is pulverized in the mill and immediately supplied to the boiler.
  • the power plant comprises a buffer silo of pulverized coal for some of its coal mills, for example half of the coal mills, while the other coal mills are operatable by conventional supply only.
  • Such arrangement allows a partial indirect firing, i.e. an indirect firing for some of the boiler units only, which enables sufficient dynamic response of the power plant, but where the cost for the silos is kept at a minimum.
  • a method to operate a fossil fuel fired power plant as presented according to the invention comprises at the occurrence of a frequency variation in the grid, activating a condensate stop process by closing quick-action valves in lines leading from extraction points at low- and intermediate-pressure steam turbine stages to low- and intermediate-pressure preheaters.
  • a particular method further comprises closing a quick-action valve in a line from the condensate extraction pump to the preheaters and opening a recirculation line from the condensate extraction pump to the condenser well of the steam turbine condenser.
  • a condensate stop is activated and, in addition, pulverized coal ready for combustion from a coal supply container is fed to the boiler.
  • valves in the steam extraction lines to the condensate preheaters are opened.
  • a high-pressure throttle valve for the regulation of the live-steam flow to the steam turbines is operated.
  • This high-pressure throttling allows supplementing and completing a load increase in case of a frequency variation in the grid by regulation or fine-tuning of the load increase.
  • Figure 1 shows a power plant PP with a fossil fueled boiler 1 comprising an economizer 2, a superheater 3, and a reheater 4, and several steam turbines 6-10 including a high-pressure turbine stage 6, to which live steam is led via a line with throttling valve 5, an intermediated-pressure turbine stage 7 and low-pressure turbine stages 8-10.
  • Steam expanded in the high-pressure turbine stage 6 is reheated in reheater 4 and led into intermediate-pressure turbine stage 7.
  • the steam is further expanded in the low-pressure turbines 8-10. All turbines are mounted on a shaft 11 driving a generator 12.
  • Exhaust steam is led from the low-pressure turbines 8-10 via line 13' to a condenser 13, where resulting condensate collects in a condensate well of the condenser.
  • a condensate extraction pump 14 pumps the condensate through a series of condensate preheaters 21-26, which are each operated by steam as a heat exchange medium, which is extracted from the low- and intermediate-pressure steam turbines 7-10 and led to the preheaters 21-26 via six individual extraction lines 21'-26', respectively.
  • the extraction lines leading to the intermediate-pressure preheaters 25 and 26 and to the two low-pressure preheaters 23 and 24 arranged prior to the intermediate-pressure preheaters are configured with a quick-action stop valve 23"- 26", respectively.
  • Extraction lines 21'-24' lead steam extracted from all of the low-pressure steam turbines 8-10 to the preheaters 21-24.
  • the extraction lines 21 and 22 can be arranged within the steam condenser neck and can be configured without valves.
  • the four quick-action valves 23"-26" in the low- and intermediate-pressure extraction lines are closed.
  • the two lowest-pressure steam extraction lines 21' and 22' can be left untouched because their contribution to the condensate stop and load increase is limited compared to that of the four other extraction lines.
  • the steam flow in lines 21' and 22' is proportional to the temperature difference between the piping in the preheaters 21 and 22 and the extracted steam.
  • a thermal equilibrium in the preheaters 21 and 22 is reached.
  • no more steam condenses on the piping of the preheaters 21 and 22 and the extraction of steam through these lines comes to a halt due to a zero pressure difference. This complete process can take about 1 minute and 30 seconds.
  • the line leading from the condensate extraction pump 14 to the first preheater 21 contains a quick-acting valve 15 allowing to close this line at the time of closure of the extraction lines.
  • the recirculation line 16 with a quick-acting valve 17 allows the recirculation of the condensate discharged by the extraction pump 14 back into the condenser 13.
  • the stoppage of the condensate flow through the preheaters prevents a drop in the feedwater temperature. It also allows to maintain the temperature of the preheaters 21-26, which avoids massive condensation and thereby allows an easier restarting of their operation after the condensate stop and load increase.
  • the recirculation of the condensate however, also results in an increase of the level in the condensate well.
  • the condensate preheated in the low-pressure preheaters 21-26 is collected in the boiler feedwater tank 30. Additional heat is provided to the feedwater tank 30 via steam extraction line 30' extracting steam from the intermediate-pressure turbine stage 7, which is used for preheating in a preheater 33.
  • the quick-acting valve 30" in the intermediate-pressure steam extraction line 30' is closed. Thereby the additional steam made available to drive the turbines further supports the load increase.
  • Feedwater pump FWP directs the feedwater through high-pressure preheaters 31 and 32. Following the preheaters 31 and 32, the feedwater is led through a further preheater 33 and finally to the boiler 2 completing the water steam cycle of the power plant PP.
  • the power plant PP will be operated in order to compensate for the variation by increasing its load within a short time period.
  • a condensate stop is activated by closing the stop valves 23" to 26" in the extraction lines 23'-26'. Due to the fact that four extraction lines are available for the condensate stop that significantly contribute to a load increase, an increased amount of steam is available compared to in conventional power plants to drive the turbines.
  • a steam power plant with six intermediate- and low-pressure steam extractions is able to provide a load jump as great as about 10% corresponding to a 50% increase over the possible load jump in a conventional power plant.
  • FIG. 2 shows the same power plant as in figure 1 .
  • the figure illustrates the steam production unit of the power plant PP comprising a coal milling facility 40, a boiler 1 including an economizer 2, a superheater 3 and a reheater 4.
  • the flue gases of the boiler 1 are led through an electrostatic precipitator ESP and a desulphurization unit DS before they are emitted through the stack S.
  • the coal milling facility 40 comprises an air preheater 41, through which air A is directed before it is led to the mill 42, to which raw coal of large size is fed.
  • the coal mill reduces the raw coal to powder with particle sizes in a given range suitable for combustion.
  • the present facility comprises a coal buffer silo 45 and a duct 44 by which the pulverized coal is transported from the coal mill 44 to the silo 45, where the pulverized coal is stored ready for combustion.
  • a feeding device 46 leads from the silo 45 directly to a duct 43, which leads into the boiler.
  • the store 45 of pulverized coal allows a quick release of coal to the boiler at a faster rate than can be provided directly by the coal mill.
  • the feeding device 46 allows the supply of pulverized coal to the boiler at a given rate. It also allows a steady release of the pulverized coal into the duct 43 such that the formation of hollow spaces at the bottom of the silo is avoided.
  • An additional duct 43' leading from the coal mill 43 directly to the duct 43 is intended for emergency coal supply only.
  • the coal facility for indirect firing operates in that coal is milled and provided to the buffer silo 45 and fed by means of the feeding device 46 to the duct 43 for combustion. It is supplied to the boiler at a rate given by the steam demand or boiler load rate.
  • the coal milling rate is set such that the supply silo 45 is gradually filled.
  • the filling of the buffer silo 45 generates readiness for a high degree of dynamic response with increased firing rate in case a frequency instability occurs in the grid.
  • the milling time is long to produce coal particles of the required size, especially in the case of hard coal.
  • the coal mill can change speed only at a slow rate and is therefore not able to rapidly change the supply rate of pulverized coal to the boiler.
  • a condensate stop is activated and an increased firing rate is initiated by the indirect firing system supplying pulverized coal to the boiler from the buffer silo 45 at rate that is higher than during normal steady state as described above or with direct firing system having no pulverized coal supply silo.
  • an increase in steam production can be assured within seconds.
  • the level of pulverized coal in the buffer silo 45 decreases steadily as the rate of pulverized coal consumption is increased.
  • Figure 3a shows the development of a grid frequency over time Gf(Hz) including a typical frequency variation with a sharp decrease from 50 Hz to 49.5 Hz.
  • Gf(Hz) the development of the demanded load Ld and that of the actual measured load Lm of a power plant according to the invention is shown, where the power plant is equipped with six condensate preheaters and two feedwater preheaters and an indirect firing facility with a coal buffer silo.
  • an immediate dynamic response is activated within the time frame of a few seconds from the onset of the frequency drop. In this case, well within 10 seconds after the beginning of the frequency variation the full frequency response is completed in that the effective power load Lm of the power plant has reached the demanded load Ld.
  • Figure 3b shows for the same power plant the development of grid frequency Gf and demanded and measured load Ld and Lm respectively over a longer time frame of 30 minutes following the onset of a frequency variation.
  • the curves show that the power plant according to the invention is able to maintain the dynamic response by load increase over the full 30 minutes.
  • Figure 3c shows as a function of time following a rapid frequency drop, the production of live steam flow by a coal-fired boiler with and without a coal buffer silo.
  • Curve A shows the live steam production in a conventional plant having no coal silo, where pulverized coal is provided to the boiler at the rate that the mill is able to produce the coal particles.
  • Curve B in contrast, shows the production of live steam by means of additional coal already pulverized and provided at a greater rate by the coal silo. Compared to curve A, the rate of increase in steam production is much greater.
  • Figure 3d shows the production of live steam flow LSF as the quantity of pulverized coal CS in the buffer silo is diminished over time. It shows that even if the pulverized coal is supplied almost steadily, the boiler firing rate can be increased. The resulting quick increase in live steam flow enables the support of a load jump within a short time and its maintenance over a long time period, for example up to 30 minutes.
  • Figure 3e shows following the variation of the grid frequency Gf, the development of the condensate level in the condensate well Cwl and the feedwater level in the feedwater tank Fwl. Initiated by the frequency, the condensate well level rises as a result of the condensate stop and stoppage of the condensate extraction flow variation. On the same time scale, as the condensate flow is stopped and the feedwater pump continues to operated, the level of the feedwater in the feedwater tank begins to drop.

Landscapes

  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Physics & Mathematics (AREA)
  • Thermal Sciences (AREA)
  • Control Of Turbines (AREA)
EP10150416.5A 2010-01-11 2010-01-11 Kraftwerk und Verfahren zum Betrieb eines Kraftwerks Active EP2351914B1 (de)

Priority Applications (2)

Application Number Priority Date Filing Date Title
EP10150416.5A EP2351914B1 (de) 2010-01-11 2010-01-11 Kraftwerk und Verfahren zum Betrieb eines Kraftwerks
PL10150416.5T PL2351914T3 (pl) 2010-01-11 2010-01-11 Elektrownia i sposób obsługi elektrowni

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP10150416.5A EP2351914B1 (de) 2010-01-11 2010-01-11 Kraftwerk und Verfahren zum Betrieb eines Kraftwerks

Publications (2)

Publication Number Publication Date
EP2351914A1 true EP2351914A1 (de) 2011-08-03
EP2351914B1 EP2351914B1 (de) 2016-03-30

Family

ID=43357105

Family Applications (1)

Application Number Title Priority Date Filing Date
EP10150416.5A Active EP2351914B1 (de) 2010-01-11 2010-01-11 Kraftwerk und Verfahren zum Betrieb eines Kraftwerks

Country Status (2)

Country Link
EP (1) EP2351914B1 (de)
PL (1) PL2351914T3 (de)

Cited By (14)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN102635413A (zh) * 2012-04-18 2012-08-15 山西太钢不锈钢股份有限公司 一种提高饱和余热发电机组效能的方法
WO2013005071A1 (en) * 2011-07-07 2013-01-10 Alstom Technology Ltd Power plant and method of operating a power plant
WO2013007802A1 (fr) 2011-07-12 2013-01-17 Electricite De France Procede et systeme de commande d'une centrale electrique ainsi que centrale thermique
DE102012204288A1 (de) * 2012-03-19 2013-09-19 Man Diesel & Turbo Se Dampfturbine und Verfahren zum Betrieb einer Dampfturbine
EP2851616A1 (de) 2013-09-19 2015-03-25 Alstom Technology Ltd Rauchgaswärmerückgewinnungsintegration
EP2868872A1 (de) * 2013-10-31 2015-05-06 Alstom Technology Ltd Speisewasservorwärmungssystem und -verfahren
EP2899374A1 (de) * 2014-01-09 2015-07-29 Doosan Heavy Industries & Construction Co., Ltd. Vorrichtung und verfahren zur reaktorleistungsregelung eines dampfturbinenstromerzeugungssystems
WO2016019927A1 (en) * 2014-08-08 2016-02-11 Natural Power And Energy S.R.O. Thermal energy equipment comprising a steam turbine and an operation method of the thermal energy equipment
CN106765441A (zh) * 2016-12-30 2017-05-31 何宗衡 集烟式供热机组
EP2660511A4 (de) * 2010-12-27 2018-02-28 Mitsubishi Hitachi Power Systems, Ltd. Kondensat-strömungsratensteuervorrichtung für ein kraftwerk und steuerverfahren dafür
CN110107489A (zh) * 2019-04-19 2019-08-09 中国神华能源股份有限公司 用于凝结水水泵的控制方法、系统及机组
JP2020002931A (ja) * 2018-07-02 2020-01-09 株式会社東芝 火力発電プラント
CN111206965A (zh) * 2020-02-20 2020-05-29 秦皇岛秦热发电有限责任公司 利用热网低压蒸汽的功热系统及其自动保护动作系统
CN113217130A (zh) * 2021-03-17 2021-08-06 西安热工研究院有限公司 一种基于凝结水调频的除氧器和凝汽器热井容量选取方法

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP3759321A1 (de) 2018-02-28 2021-01-06 ENEXIO Hungary Zrt. Kraftwerk und betriebsverfahren dafür

Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4003205A (en) * 1974-08-09 1977-01-18 Hitachi, Ltd. Method and apparatus for operating a steam turbine plant having feed water heaters
DE3616797A1 (de) * 1986-05-17 1987-11-19 Koerting Ag Dampfturbinenanlage
DE4344118A1 (de) 1993-12-23 1995-06-29 Abb Patent Gmbh Verfahren und Einrichtung zur Steuerung und Regelung der Dampfkraftwerksleistung unter Einsatz von Kondensatstopp
DE19524171A1 (de) * 1995-07-03 1997-01-09 Rauscher Georg Niedertemperaturmotor (NTM), Tieftemperaturmotor (TTM) bzw. Kältekraftmaschine (KKM)
EP1368555A1 (de) 2001-03-15 2003-12-10 Siemens Aktiengesellschaft Verfahren zum betrieb einer dampfkraftanlage sowie dampfkraftanlage
DE102005034847A1 (de) * 2005-07-26 2007-02-08 Steag Saar Energie Ag Dampfkraftwerksanlage
DE102008004400A1 (de) * 2008-01-14 2009-07-23 Steinmüller-Instandsetzung Kraftwerke Gesellschaft für Energie- und Umwelttechnik mbH Verfahren und Anordnung zur Dosierung von Kohlenstaub in eine Feuerungseinrichtung

Patent Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4003205A (en) * 1974-08-09 1977-01-18 Hitachi, Ltd. Method and apparatus for operating a steam turbine plant having feed water heaters
DE3616797A1 (de) * 1986-05-17 1987-11-19 Koerting Ag Dampfturbinenanlage
DE4344118A1 (de) 1993-12-23 1995-06-29 Abb Patent Gmbh Verfahren und Einrichtung zur Steuerung und Regelung der Dampfkraftwerksleistung unter Einsatz von Kondensatstopp
DE19524171A1 (de) * 1995-07-03 1997-01-09 Rauscher Georg Niedertemperaturmotor (NTM), Tieftemperaturmotor (TTM) bzw. Kältekraftmaschine (KKM)
EP1368555A1 (de) 2001-03-15 2003-12-10 Siemens Aktiengesellschaft Verfahren zum betrieb einer dampfkraftanlage sowie dampfkraftanlage
DE102005034847A1 (de) * 2005-07-26 2007-02-08 Steag Saar Energie Ag Dampfkraftwerksanlage
DE102008004400A1 (de) * 2008-01-14 2009-07-23 Steinmüller-Instandsetzung Kraftwerke Gesellschaft für Energie- und Umwelttechnik mbH Verfahren und Anordnung zur Dosierung von Kohlenstaub in eine Feuerungseinrichtung

Cited By (18)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2660511A4 (de) * 2010-12-27 2018-02-28 Mitsubishi Hitachi Power Systems, Ltd. Kondensat-strömungsratensteuervorrichtung für ein kraftwerk und steuerverfahren dafür
WO2013005071A1 (en) * 2011-07-07 2013-01-10 Alstom Technology Ltd Power plant and method of operating a power plant
WO2013007802A1 (fr) 2011-07-12 2013-01-17 Electricite De France Procede et systeme de commande d'une centrale electrique ainsi que centrale thermique
FR2977916A1 (fr) * 2011-07-12 2013-01-18 Electricite De France Procede de commande d'une centrale electrique
DE102012204288A1 (de) * 2012-03-19 2013-09-19 Man Diesel & Turbo Se Dampfturbine und Verfahren zum Betrieb einer Dampfturbine
CN102635413A (zh) * 2012-04-18 2012-08-15 山西太钢不锈钢股份有限公司 一种提高饱和余热发电机组效能的方法
EP2851616A1 (de) 2013-09-19 2015-03-25 Alstom Technology Ltd Rauchgaswärmerückgewinnungsintegration
US10288279B2 (en) 2013-09-19 2019-05-14 Alstom Technology Ltd Flue gas heat recovery integration
EP2868872A1 (de) * 2013-10-31 2015-05-06 Alstom Technology Ltd Speisewasservorwärmungssystem und -verfahren
EP2899374A1 (de) * 2014-01-09 2015-07-29 Doosan Heavy Industries & Construction Co., Ltd. Vorrichtung und verfahren zur reaktorleistungsregelung eines dampfturbinenstromerzeugungssystems
WO2016019927A1 (en) * 2014-08-08 2016-02-11 Natural Power And Energy S.R.O. Thermal energy equipment comprising a steam turbine and an operation method of the thermal energy equipment
CN106765441A (zh) * 2016-12-30 2017-05-31 何宗衡 集烟式供热机组
CN106765441B (zh) * 2016-12-30 2022-05-13 何宗衡 集烟式供热机组
JP2020002931A (ja) * 2018-07-02 2020-01-09 株式会社東芝 火力発電プラント
CN110107489A (zh) * 2019-04-19 2019-08-09 中国神华能源股份有限公司 用于凝结水水泵的控制方法、系统及机组
CN110107489B (zh) * 2019-04-19 2020-09-18 中国神华能源股份有限公司 用于凝结水水泵的控制方法、系统及机组
CN111206965A (zh) * 2020-02-20 2020-05-29 秦皇岛秦热发电有限责任公司 利用热网低压蒸汽的功热系统及其自动保护动作系统
CN113217130A (zh) * 2021-03-17 2021-08-06 西安热工研究院有限公司 一种基于凝结水调频的除氧器和凝汽器热井容量选取方法

Also Published As

Publication number Publication date
PL2351914T3 (pl) 2016-09-30
EP2351914B1 (de) 2016-03-30

Similar Documents

Publication Publication Date Title
EP2351914B1 (de) Kraftwerk und Verfahren zum Betrieb eines Kraftwerks
Henderson Increasing the flexibility of coal-fired power plants
US7274111B2 (en) Methods and apparatus for electric power grid frequency stabilization
US7608938B2 (en) Methods and apparatus for electric power grid frequency stabilization
Shagdar et al. Performance analysis and techno-economic evaluation of 300 MW solar-assisted power generation system in the whole operation conditions
US20010023576A1 (en) High density combined cycle power plant process
US9732635B2 (en) Method for enhanced cold steam turbine start in a supplementary fired multi gas turbine combined cycle plant
Tuzson Status of steam-injected gas turbines
KR101825283B1 (ko) 복합 화력 발전소 작동 방법
WO2013005071A1 (en) Power plant and method of operating a power plant
CN104564192A (zh) 联合循环发电机组
US10208630B2 (en) Method for operating a steam power plant and steam power plant for conducting said method
JPS62325B2 (de)
JP5656754B2 (ja) ごみ焼却炉用発電設備及びその制御方法
EP3306044A1 (de) Antwortsysteme mit schneller frequenz mit wärmespeicherung für kombikraftwerke
US11661867B2 (en) Gas turbine exhaust heat recovery plant
EP2589763B1 (de) Verfahren zum Betrieb eines Dampfkraftwerks bei geringer Belastung
JP5656753B2 (ja) ごみ焼却炉用発電設備及びその制御方法
US20240218813A1 (en) Improved thermal power plant
Grzeszczak et al. Environmentally friendly replacement of mature 200 MW coal-fired power blocks with 2 boilers working on one 500 MW class Steam Turbine Generator (2on1 unit concept)
Shaposhnikov et al. Effectiveness of the joint scheme of steam-power and combined-cycle power units using the example of the Nevinnomyssk State Regional Thermal Power Plant
Barinberg et al. Prospective steam turbines for combined-cycle plants
CN103620166A (zh) 具有作为附加的频率调节措施以及初级和/或次级调节措施的辅助蒸汽生成器的蒸汽发电设备及方法

Legal Events

Date Code Title Description
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

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): 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 SE SI SK SM TR

AX Request for extension of the european patent

Extension state: AL BA RS

17P Request for examination filed

Effective date: 20120131

17Q First examination report despatched

Effective date: 20130701

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: F01K 7/40 20060101ALI20150911BHEP

Ipc: F22D 1/00 20060101ALI20150911BHEP

Ipc: F22D 1/32 20060101ALI20150911BHEP

Ipc: F01K 13/02 20060101AFI20150911BHEP

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

INTG Intention to grant announced

Effective date: 20151012

INTG Intention to grant announced

Effective date: 20151111

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): 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 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: AT

Ref legal event code: REF

Ref document number: 785648

Country of ref document: AT

Kind code of ref document: T

Effective date: 20160415

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: DE

Ref legal event code: R096

Ref document number: 602010031558

Country of ref document: DE

REG Reference to a national code

Ref country code: LT

Ref legal event code: MG4D

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

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: 20160701

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: 20160330

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: 20160630

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: 20160330

REG Reference to a national code

Ref country code: NL

Ref legal event code: MP

Effective date: 20160330

REG Reference to a national code

Ref country code: AT

Ref legal event code: MK05

Ref document number: 785648

Country of ref document: AT

Kind code of ref document: T

Effective date: 20160330

RAP2 Party data changed (patent owner data changed or rights of a patent transferred)

Owner name: GENERAL ELECTRIC TECHNOLOGY GMBH

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

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: 20160330

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: 20160330

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: 20160330

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: 20160330

REG Reference to a national code

Ref country code: DE

Ref legal event code: R082

Ref document number: 602010031558

Country of ref document: DE

Representative=s name: RUEGER | ABEL PATENT- UND RECHTSANWAELTE, DE

Ref country code: DE

Ref legal event code: R082

Ref document number: 602010031558

Country of ref document: DE

Representative=s name: RUEGER ABEL PATENTANWAELTE PARTGMBB, DE

Ref country code: DE

Ref legal event code: R082

Ref document number: 602010031558

Country of ref document: DE

Representative=s name: RUEGER, BARTHELT & ABEL, DE

Ref country code: DE

Ref legal event code: R081

Ref document number: 602010031558

Country of ref document: DE

Owner name: GENERAL ELECTRIC TECHNOLOGY GMBH, CH

Free format text: FORMER OWNER: ALSTOM TECHNOLOGY LTD., BADEN, CH

Ref country code: DE

Ref legal event code: R082

Ref document number: 602010031558

Country of ref document: DE

Representative=s name: RUEGER ABEL PATENT- UND RECHTSANWAELTE, DE

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

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: 20160730

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: 20160330

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: 20160330

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: 20160330

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: 20160330

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: 20160801

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: 20160330

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: 20160330

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

Ref country code: IT

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: 20160330

Ref country code: BE

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: 20160330

REG Reference to a national code

Ref country code: FR

Ref legal event code: CD

Owner name: ALSTOM TECHNOLOGY LTD, CH

Effective date: 20161124

REG Reference to a national code

Ref country code: DE

Ref legal event code: R097

Ref document number: 602010031558

Country of ref document: DE

REG Reference to a national code

Ref country code: FR

Ref legal event code: PLFP

Year of fee payment: 8

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

Ref country code: DK

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: 20160330

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

26N No opposition filed

Effective date: 20170103

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: 20160330

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: 20160330

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

Ref country code: CH

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

Effective date: 20170131

Ref country code: LI

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

Effective date: 20170131

REG Reference to a national code

Ref country code: IE

Ref legal event code: MM4A

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

Ref country code: LU

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

Effective date: 20170111

REG Reference to a national code

Ref country code: FR

Ref legal event code: PLFP

Year of fee payment: 9

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

Ref country code: IE

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

Effective date: 20170111

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

Ref country code: MT

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

Effective date: 20170111

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

Ref country code: HU

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

Effective date: 20100111

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

Ref country code: BG

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: 20160330

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

Ref country code: CY

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

Effective date: 20160330

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

Ref country code: MK

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: 20160330

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

Ref country code: TR

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: 20160330

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

Ref country code: CZ

Payment date: 20201221

Year of fee payment: 12

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

Ref country code: PL

Payment date: 20201218

Year of fee payment: 12

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

Ref country code: CZ

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

Effective date: 20220111

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

Ref country code: PL

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

Effective date: 20220111

P01 Opt-out of the competence of the unified patent court (upc) registered

Effective date: 20230523

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

Ref country code: GB

Payment date: 20231219

Year of fee payment: 15

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

Ref country code: FR

Payment date: 20231219

Year of fee payment: 15

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

Ref country code: DE

Payment date: 20231219

Year of fee payment: 15