EP3415816A1 - Verfahren und system zur erweiterung des lastbereichs eines kraftwerks mit einem kessel zur zuführung von dampf an eine dampfturbine - Google Patents

Verfahren und system zur erweiterung des lastbereichs eines kraftwerks mit einem kessel zur zuführung von dampf an eine dampfturbine Download PDF

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Publication number
EP3415816A1
EP3415816A1 EP18397514.3A EP18397514A EP3415816A1 EP 3415816 A1 EP3415816 A1 EP 3415816A1 EP 18397514 A EP18397514 A EP 18397514A EP 3415816 A1 EP3415816 A1 EP 3415816A1
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EP
European Patent Office
Prior art keywords
steam
temperature
steam turbine
superheater
auxiliary
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Granted
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EP18397514.3A
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English (en)
French (fr)
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EP3415816B1 (de
Inventor
Juhani Isaksson
Matti Nieminen
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Valmet Technologies Oy
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Valmet Technologies Oy
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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22G—SUPERHEATING OF STEAM
    • F22G1/00—Steam superheating characterised by heating method
    • F22G1/16—Steam superheating characterised by heating method by using a separate heat source independent from heat supply of the steam boiler, e.g. by electricity, by auxiliary combustion of fuel oil
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22G—SUPERHEATING OF STEAM
    • F22G5/00—Controlling superheat temperature
    • F22G5/16—Controlling superheat temperature by indirectly cooling or heating the superheated steam in auxiliary enclosed heat-exchanger
    • 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
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22G—SUPERHEATING OF STEAM
    • F22G5/00—Controlling superheat temperature
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22G—SUPERHEATING OF STEAM
    • F22G5/00—Controlling superheat temperature
    • F22G5/02—Applications of combustion-control devices, e.g. tangential-firing burners, tilting burners
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22G—SUPERHEATING OF STEAM
    • F22G5/00—Controlling superheat temperature
    • F22G5/18—Controlling superheat temperature by by-passing steam around superheater sections
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22G—SUPERHEATING OF STEAM
    • F22G5/00—Controlling superheat temperature
    • F22G5/20—Controlling superheat temperature by combined controlling procedures

Definitions

  • the disclosed solution relates to the operation of a steam turbine power plant comprising a boiler for steam generation.
  • Steam turbine power plants are commonly used for production of electricity.
  • CHP combined heat and power
  • a boiler burning suitable fuel, produces steam with a mass flow rate, which steam is conveyed to a steam turbine.
  • Steam refers to water in a gaseous state.
  • thermal energy released by the burnt fuel is transferred into the steam.
  • the steam entering the steam turbine is typically pressurized at 80-180 bar and has a temperature typically in the range of 450-560 °C.
  • a power plant i.e. electricity is being produced
  • the pressure of the steam entering the turbine is kept constant while its temperature may change.
  • the steam turbine converts thermal energy in the steam into rotary motion on the turbine output shaft. This shaft then drivers an electric generator via a suitable driveline.
  • a steam turbine requires steam of sufficiently high quality for viable operation. This typically means that the steam entering the steam turbine must contain a sufficiently high amount of thermal energy to be released in the steam turbine as the steam travels through the turbine. If the incoming steam contains too little thermal energy it is not acceptable for the steam turbine, since such steam may condense prematurely and thereby risk steam turbine damage or failure.
  • the load range of a steam turbine power plant can not be lowered below a threshold at which the boiler burns just enough fuel so that the thermal energy transferred in the boiler into the steam enables satisfying the minimum quality criteria for the steam entering the steam turbine.
  • the power plant may not be viably operated.
  • steam turbine power plants have a limitation with respect to their downward load range flexibility, which limits their use in electricity production namely, with low loads i.e. low volume of electricity production.
  • the solution comprises a method of extending the load range for viable operating W V of a steam turbine power plant comprising a boiler with a superheater for supplying superheated steam to a steam turbine, the steam turbine having a required minimum viable temperature T V of steam entering the steam turbine, the load range for viable operating W V of the steam turbine power plant being extended by means of controllably using an auxiliary superheating chamber comprising an auxiliary superheater to further superheat steam.
  • Such controllable use of the auxiliary superheating chamber may entail that based on determining the temperature T of the steam entering the steam turbine:
  • controllable use of the auxiliary superheating chamber may entail that based on determining the temperature T of the steam entering the steam turbine:
  • the solution thereby enables the required minimum viable temperature T V of steam entering the steam turbine to be satisfied both within the load range for normal operating of the power plant and the load range for low load operating of the power plant.
  • the solution comprises a method of maintaining in hot standby mode a steam turbine power plant, which entails generating product gas in the gasifier; supplying product gas from the gasifier to a burner in the auxiliary superheating chamber to maintain the superheating chamber in a hot standby temperature, which temperature is higher than ambient temperature; and supplying product gas from the gasifier to the boiler to be burned in the boiler to maintain the boiler in a hot standby temperature, which temperature is higher than ambient temperature.
  • the solution further comprises a system which may comprise a boiler with a superheater for supplying superheated steam to a steam turbine, the steam turbine having a required minimum viable temperature T V of steam entering the steam turbine; a controllably usable auxiliary superheating chamber comprising an auxiliary superheater and a burner, the auxiliary superheater installed in a steam forward conveyance pathway between the superheater and the steam turbine; and a control unit adapted to:
  • control unit may be adapted to:
  • the system may thereby enable the required minimum viable temperature T V of steam entering the steam turbine to be satisfied both within the load range for normal operating of the power plant and the load range for low load operating of the power plant.
  • a steam turbine has specified minimum quality requirements for incoming steam.
  • Steam quality typically refers to (1) steam temperature, (2) steam pressure and (3) proportion of entrained liquid content in the steam.
  • High quality steam is of high enough temperature and pressure and contains little to no entrained liquid. If steam is not of high enough quality, it will condense too early along its way through the steam turbine, whereby condensate water droplets may cause problems. Such problems comprise, for example, formed water droplets hitting turbine blades, typically towards the end of the steam turbine, which creates a risk of turbine damage or failure.
  • the disclosed solution alleviates this problem by enabling supplying, by controllably using an auxiliary superheating chamber comprising an auxiliary superheater, steam of sufficiently high quality also in situations in which the thermal energy production in the boiler is insufficient alone to maintain sufficient steam quality.
  • Steam of sufficiently high quality requires that a sufficiently large amount of thermal energy is produced in the boiler and then transferred to the steam. Such energy transfer is typically brought about so that water is pre-heated in the boiler to form steam, whereafter steam is further heated in a superheater or superheaters installed in the boiler.
  • Superheater is a device preferably used to convert steam into superheated steam.
  • Superheated steam is steam at a temperature which is higher than the boiling point of the substance such as water at a particular pressure. Steam in a superheated state contains no entrained liquid. Thus, the temperature of superheated steam may decrease by some amount before entrained liquid begins to form. Therefore, the higher the temperature of superheated steam, the more it may cool, i.e. release energy, before entrained liquid begins to form.
  • steam of sufficiently high quality for a steam turbine refers to steam which is superheated to such a temperature that the superheated steam contains high enough energy so that it will not condensate prematurely in the steam turbine as it releases energy while travelling through the steam turbine.
  • the pressure of the steam entering the steam turbine is kept constant in a power plant system. This pressure begins to decrease once steam enters the steam turbine, wherein the steam starts to release energy and expand.
  • Lower boiler load i.e. lower heat generation in the boiler, results in less thermal energy being transferred to the steam which, in turn, results in lower quality steam.
  • Boiler load may be controlled by adjusting the amount of fuel being fed into the boiler to be burned. As is well known in the industry, the amount of thermal energy generated in the boiler and/or transferred into the steam can be inferred, for example calculated, from the volume of fuel per unit of time being fed into the boiler and the type of fuel being fed.
  • the boiler comprises an arrangement for automatically adjusting the amount of air and/or other gases required in the fuel burning process as a function of the amount of fuel being fed.
  • Such automatic adjustment of air and/or other gases may be effected, for example, by measuring the level of oxygen present in the combustion gases and adjusting the feed of fuel and/or the air and/or other gases such that an optimal oxygen level in the combustion gases, known as the lambda value, is obtained.
  • the volume of steam produced in terms of mass flow rate typically decreases relatively linearly as a function of the load.
  • the electricity output of the plant i.e. the load of the power plant, is correspondingly reduced.
  • a boiler At and above its minimum rated load a boiler is capable of transferring sufficient amount of thermal energy to the produced steam mass flow for the steam to be of sufficient quality for the steam turbine. Below the minimum rated load of the boiler, the amount of thermal energy transferred to the produced steam mass flow is no longer sufficient for the steam to be of sufficient quality for the steam turbine, even though the reduced mass flow rate of the steam could still be appropriate for electricity generation purposes at that time.
  • the minimum rated load of a boiler is the minimum load with which the boiler is capable of producing steam of sufficient quality for the steam turbine.
  • the steam is not of acceptable quality for the steam turbine. In practice this usually means that the steam is not sufficiently hot, since the pressure of the steam entering the turbine is typically kept constant when electricity is being produced.
  • An advantage of the disclosed solution is that steam turbine-based power generation may be made more capable of such flexible adjusting of power production. This is because below the minimum rated viable load of the boiler, the auxiliary superheating chamber comprising an auxiliary superheater may be employed to further superheat steam thereby ensuring supplying steam of sufficient quality to the steam turbine.
  • the minimum rated viable load of a boiler defines the minimum rated viable load of a power plant comprising a boiler for steam production. Below this minimum rated viable load of a power plant, the power plant typically must be shut down in order to avoid risking a steam turbine damage.
  • the minimum rated viable load of a boiler currently in practice defines the range of downward load flexibility of a power plant, from the full rated load of a power plant to its minimum rated viable load. The disclosed solution enables extending the viable load range of a steam turbine power plant downwards below the minimum rated viable load of the boiler.
  • the minimum rated viable load of a power plant is about 30-40% below its full rated load.
  • Some power plants comprising fluidized bed boilers have a minimum rated viable load of about 60% below the full rated load.
  • the disclosed solution enables running a steam turbine power generation plants with a wide load range for viable operating, particularly such that the load range for viable operating of the power plant extends below the minimum rated viable load of the power plant as typically determined by the minimum rated viable load of the boiler.
  • Such extended load range for viable operating of the power plant below its minimum rated viable load has the benefit of enabling the power plant to better respond to changing power demand conditions.
  • a power plant is used to refer to a steam turbine power plant wherein a steam turbine 3 may be used to convert thermal energy of steam into mechanical work, which mechanical work may be converted into electricity by a generator 9.
  • FIG. 1 schematically illustrates, according to an example embodiment, a system for producing steam to be used in a steam turbine 3 according to the solution.
  • Steam enters the steam turbine 3 with a mass flow rate ⁇ , defined as the mass of steam entering the steam turbine 3 per unit of time.
  • the steam turbine may have minimum requirements for the properties of the steam entering the steam turbine for viable operating of the steam turbine 3.
  • Such minimum requirements may comprise, for example, a minimum viable temperature T V for the steam entering the steam turbine 3 such that if the temperature T of the steam entering the steam turbine is below the minimum viable temperature T V , the steam turbine may not be operated viably.
  • a minimum viable pressure for the steam entering the steam turbine 3 such that if the pressure of the steam entering the steam turbine 3 is below the minimum viable pressure, the steam turbine 3 may not be operated viably.
  • Determining steam properties may be performed by installing a flowmeter and/or a pressure sensor and/or a temperature sensor in a steam conveyance line, and relaying the signal(s) from this/these instruments to an apparatus such as a dedicated steam flow computer and/or a control unit 23 for processing and/or storage. It is to be appreciated that determining steam properties is well known in the industry and appropriate equipment for this purpose commercially available. Steam properties, once determined for example through measurement, may be used as control input data by the control unit 23.
  • steam properties may be determined by way of measurement at least in a line 31 at its terminus at the steam turbine 3.
  • steam properties may be determined otherwise as well, for example based on measurements in other loci in the system.
  • Determining of the properties of steam, including its temperature, as it enters into the steam turbine 3 may be indirect. This means that steam properties are measured further upstream or downstream, for example in the steam conveyance pathway which terminates at the steam turbine 3, and that the measurement results are converted into values for the properties of the steam to be determined, for example as it enters into the steam turbine 3, by using known conversion factors. Such known conversion factors may be obtained through, for example, comparative measurements at loci of interest, of they may be derived from calculations based on the physical properties of the system.
  • the notion of determining steam properties, as it used in this text, includes also indirect determining as just described.
  • the pressure of the steam may be kept constant, at least when the power plant produces electricity, in which case the minimum requirements for the properties of the steam entering the steam turbine 3 may in practical terms be captured by the minimum viable temperature T V for the steam entering the steam turbine 3.
  • the steam turbine 3 may be adapted to drive, via a driveline 70, an electric generator 9 which may supply electricity to an electricity-consuming process via a line 44.
  • the electricity-consuming process may be a specific and/or localized process such as in a manufacturing facility, or the electricity-consuming process may be aggregate electricity consumption in an electrical grid such as a district, a regional or a national electrical grid.
  • superheated steam is produced by superheating steam in a superheater 11 installed in a boiler 10.
  • apparatuses upstream from the superheater 11, such as a heat exchanger 25 or a plurality of such heat exchangers may be employed to vaporize the water circulating in the system such that the water is already steam when it enters the superheater 11.
  • upstream from the superheater 11 may be additional apparatuses such as a heat exchanger or heat exchangers 15 for pre-heating the circulating water before vaporization.
  • the superheater 11 may be a single superheater device. Alternatively, the superheater 11 may be an aggregate of a plurality of individual superheater devices. Superheating the steam is brought about by transferring to the steam thermal energy resulting from burning fuel in in the boiler 10 with a burner (not depicted). The same applies to the heat exchanger or heat exchangers 25.
  • the boiler 10 may be of a known type, such as of the fluidized bed type or of the pulverized coal-fired type.
  • Fuel may be supplied from a fuel source 21 via a line 49 to the boiler to be burned. Air or other suitable gas or gas mixture required for burning the fuel may be conveyed to the boiler 10 via a line 50 or multiple such lines. Non-gaseous combustion residues such as ash resulting from burning the fuel may be expelled from the boiler 10 via a line 51. Combustion gases resulting from burning the fuel may be expelled from the boiler 10 via a duct 71.
  • thermal energy may be captured from the combustion gases with means in addition to the superheater 11.
  • additional means of thermal recovery may comprise a heat exchanger or heat exchangers 15.
  • the varieties and using of heat exchangers are well known in the industry, and such knowledge readily applies to the heat exchanger or heat exchangers 15.
  • the power plant may be run with a load W, which refers to the amount of electricity generated by the generator 9 per unit of time, as driven by the steam turbine 3.
  • a load W refers to the amount of electricity generated by the generator 9 per unit of time, as driven by the steam turbine 3.
  • the amount of electricity generated by the generator 9 per unit of time i.e. the power output of the generator 9
  • the load W of the power plant may be inferred from the heat consumption of the power plant, since it is well known that the load W of a power plant is highly correlated with its heat consumption.
  • the heat consumption in turn, can be inferred from the amount of fuel burned in a unit of time for the purposes of heat generation in the power plant.
  • the volume of fuel being burned in a power plant for the purposes of producing and heating steam and the load W of the power plant have a correlation which is characteristic for each power plant and known by the operators and/or programmed into the control apparatuses of the power plant.
  • the load W of the power plant may be controlled by adjusting the fuel being burned for the purposes of producing and heating steam.
  • the power plant may be run with different loads W, as illustrated in Figures 4 a to 4 d .
  • Figure 4 a represents the operation of a conventional system for producing steam to be used in a steam turbine 3.
  • Figures 4 b to 4 d represent the operation a system for producing steam to be used in a steam turbine 3 according to the disclosed solution comprising a controllably utilizable auxiliary superheating chamber comprising an auxiliary superheater.
  • a power plant may have a full rated load W F .
  • the temperature T of the superheated steam entering into the steam turbine 3 is at its maximum, i.e. at the temperature T F of the steam with full power plant load.
  • the temperature T of the superheated steam entering into the steam turbine 3 further decreases and eventually reaches a minimum viable temperature T V , which refers to the lowest acceptable temperature for the superheated steam entering the steam turbine 3.
  • This load W of the power plant, at which the temperature T of the steam entering the steam turbine 3 is at the minimum viable temperature T V is referred to as the minimum rated viable load W MV of the power plant.
  • the load range between for viable operating W V of the power plant is, inclusively, the load range between the minimum rated viable load W MV and the full rated load W F .
  • the load range for unviable operating W U of the power plant is the load range with loads below the range for viable operating W V .
  • the temperature T of the steam entering the steam turbine 3 is at or above the minimum viable temperature T V .
  • the temperature T of the steam entering the steam turbine 3 is below the minimum viable temperature T V .
  • the system comprises an auxiliary superheating chamber 1 which comprises an auxiliary superheater 2.
  • the auxiliary superheater 2 may be used to further superheat the steam originating from the superheater 11 of the boiler 10.
  • the auxiliary superheater 2 may be a single superheater device.
  • the auxiliary superheater 2 may be an aggregate of a plurality of individual superheater devices.
  • the auxiliary superheating chamber 1 may include a burner 24 which burns fuel thereby releasing thermal energy. Fuel may be burned in the burner 24 in such an amount that the released thermal energy is transferred to steam flowing through the auxiliary superheater 2 of the auxiliary superheating chamber 1 to the extent that the steam is further superheated in the auxiliary superheater 2.
  • the auxiliary superheating chamber 1 may additionally be connected to a line 54 constituting an inlet supplying incoming air or other suitable gas or gas mixture for the fuel burning process.
  • the auxiliary superheating chamber 1 comprising the auxiliary superheater 2 is installed in a steam forward conveyance pathway comprising lines 30, 31.
  • the steam forward conveyance pathway thus runs from the superheater 11 to the steam turbine 3.
  • a back conveyance pathway begins with a line 34 at the steam turbine 3 and terminates with a line 55 at the superheater 11.
  • water circulating in the system may at a given point be in a gaseous state, i.e. steam, and/or in a liquid state, depending on its temperature and/or its pressure at that given point.
  • steam may be continuously conveyed through the auxiliary superheater 2 en route from the superheater 11 to the steam turbine 3.
  • steam may be selectably conveyed either through the auxiliary superheater 2 en route from the superheater 11 to the steam turbine 3 or by bypassing the auxiliary superheater 2 via a line 58 constituting a steam diversion pathway.
  • selectable conveyance may be effected by a valve arrangement 26.
  • the valve arrangement 26 may be controlled by the control unit 23.
  • the control unit 23 may effect the selected conveyance, i.e. control the valve arrangement 26, by using steam quality measurements as input data.
  • Such input data may comprise, for example, at least the temperature T of the steam entering the steam turbine 3, for example as measured at the terminus of the line 31 at the steam turbine 3, whereby steam may be selectably conveyed via the auxiliary superheater 2 when the temperature T of the steam entering the steam turbine is near, at or below the minimum viable temperature T V .
  • fuel may be burned continuously in the auxiliary superheating chamber 1 when the power plant is producing electricity or is in a hot standby mode.
  • Hot standby means that while electricity is not being produced in the power plant, the boiler 10 and the superheating chamber 1 and the steam turbine 3 are kept at an elevated temperature, i.e. above ambient temperature, in order to reduce the time required to heat the said system components to a production temperature.
  • the volume of fuel being burned in the auxiliary superheating chamber 1 may vary.
  • a low amount of fuel being burned in the auxiliary superheating chamber 1 may be such that the auxiliary superheating chamber 1 may be kept at a hot standby temperature.
  • This hot standby temperature of the auxiliary superheating chamber 1 may be defined such that at such a temperature the superheated steam travelling through the auxiliary superheater 2 is not further superheated in the auxiliary superheater 2.
  • such a hot standby temperature may be equal to or less than the temperature T of the superheated steam entering the auxiliary superheater 2.
  • the hot standby temperature is higher than ambient temperature.
  • the boiler 10 produces steam with a mass flow ⁇ and a temperature T.
  • the auxiliary superheater 2 may be used to further superheat this steam as needed.
  • the auxiliary superheater 2 may be used, as needed, to increase the temperature T of the steam originating from the boiler 10 before the steam enters the steam turbine 3.
  • the auxiliary superheater may be controllably used to superheat steam.
  • controllable use refers to controlling the amount of fuel being burned in the burner 24 in the superheating chamber 1, thereby controlling the amount of thermal energy released and transferred into the steam flowing through the auxiliary superheater 2.
  • controllable use additionally refers to the selective conveyance and non-conveyance of steam through the auxiliary superheater 2, for example as effected by a valve arrangement 26.
  • the thermal energy transferred into the steam in the boiler 10 is sufficient to maintain the temperature T of the steam entering the steam turbine 3 at or above the minimum viable temperature T V .
  • the auxiliary superheating chamber 1 may be kept at a standby temperature as explained above.
  • the thermal energy transferred into the steam in the boiler 10 may not be sufficient alone to maintain the temperature T of the steam entering the steam turbine 3 at or above the minimum viable temperature T V .
  • the auxiliary superheating chamber 1 may be employed to further superheat the steam conveyed through the auxiliary superheater 2. Such further superheating may be brought about by increasing the volume of fuel being fed to the burner 24.
  • the load W of the power plant is below its minimum rated viable load W MV , i.e. the minimum viable load without further superheating of steam between the boiler 10 and the steam turbine 3, the higher the load of the auxiliary superheating chamber 1 advantageously may be set.
  • the load of the auxiliary superheating chamber 1 and/or the boiler 10 may controlled by the control unit 23.
  • the control unit 23 may effect such load control by using steam quality measurements as input data and/or controlling the volume of fuel fed to the burner 24 and/or the boiler 10.
  • the said input data may comprise, for example, at least the temperature T of the steam entering the steam turbine 3, for example as measured at the terminus of the line 31 at the steam turbine 3.
  • alert temperature T A for the temperature T of the steam entering the steam turbine 3.
  • the alert temperature T A is higher than the minimum viable temperature T V and lower than the temperature of steam entering the steam turbine 3 with full power plant load T F .
  • the primary purpose of the alert temperature T A is to serve as a control signal for the controllable use of the auxiliary superheating chamber 1 such that lowering the load of the boiler 10 does not result in the temperature T of the steam entering into the steam turbine 3 dropping below the minimum viable temperature T V until the load W of the power plant reaches the minimum viable load W MVA with the auxiliary superheating chamber 1 in use.
  • That the alert temperature T A serving as a control signal means that when the temperature T of the steam entering the steam turbine 3 reaches the alert temperature T A , this may be used as a trigger for control actions. Such control actions may be effected, for example, by the control unit 23.
  • the alert temperature T A may be fixed to a certain temperature, for example as being a certain number of temperature degrees above the minimum viable temperature T V .
  • the alert temperature T A may be variable, for example as a function of the load W of the power plant, or depending on the rate with which the temperature T of the steam entering the steam turbine 3 is changing.
  • the value or the value function of the alert temperature T A may be specified according to the properties of the power plant system and its behavior in different situations such that the auxiliary superheating chamber 1 may be appropriately employed to further superheat steam so that lowering the load of the boiler 10 does not result in the temperature T of the steam entering into the steam turbine 3 dropping below the minimum viable temperature T V until the load W of the power plant reaches the minimum viable load W MVA with the auxiliary superheating chamber 1 in use.
  • the controllable use of the auxiliary superheating chamber 1 does not necessarily have to be such that it strictly maintains the steam at a fixed temperature at or near the alert temperature T A .
  • the employment of the auxiliary superheating chamber 1 may be such that the temperature T of the steam entering the steam turbine 3 may fluctuate above the minimum viable temperature T V , as illustrated in Figure 4 c .
  • the range of load W of the power plant in which the auxiliary superheating chamber 1 is used to further superheat steam is referred to as the load range for low load operating W L of the power plant.
  • the load range for viable operating W V of the power plant may be extended below the minimum rated viable load W MV ( W MV being unviable without the auxiliary superheating chamber 1 used to further superheat the steam originating from the superheater 11 ) such that the load range for viable operating W V comprises both the load range for normal operating W N and the load range for low load operating W L , as illustrated in Figures 4 b to 4 d .
  • decrease in the load of the boiler 1 may result in decrease in the mass flow ⁇ and the temperature T in the steam originating from the boiler 10.
  • the load W of the power plant decreases.
  • the load of the superheating chamber 1 may be increased, by increasing the fuel feed to the burner 24, to compensate the reduced load of the boiler 1, and thusly maintain the reduced mass flow rate ⁇ of the steam at or above the minimum viable temperature T V when the steam enters the steam turbine 3.
  • the load range for viable operating W V of the power plant may be extended downwards below the minimum rated viable load W MV (without the auxiliary superheater 2, as illustrated in Figure 4 a ) by installing and controllably using the auxiliary superheater 2 between the boiler 10 and the steam turbine 3.
  • such controllable use of the auxiliary superheater may additionally mean selectably conveying or not conveying steam through the auxiliary superheater 2 with the valve arrangement 26 as explained above.
  • the minimum viable temperature T V of the steam entering into the steam turbine 3 may be satisfied according to the solution both within the load range W N for normal operating of a power plant as well as within the load range W L for low load operating of a power plant.
  • fuel may be supplied to the auxiliary superheating chamber 2 from a fuel source 6 via a line 42.
  • a fuel source 6 may be the same as supplied to the boiler 10.
  • the fuel may be different from the fuel which is supplied to the boiler 10.
  • the fuel sources 6, 21 may be, but need not be, combined into a common fuel source.
  • the fuel supplied to and burned in the auxiliary superheating chamber 1 may be product gas generated by gasification with a gasifier 4.
  • the fuel supply 6 may contain initial fuel to be gasified into final fuel burned in the auxiliary superheating chamber 1.
  • Such initial fuels to be gasified may comprise, for example, biomass and/or waste.
  • initial fuel may be conveyed from the fuel source 6 via a line 39 to the gasifier 4.
  • the final fuel may be conveyed from the gasifier 4 to the auxiliary superheating chamber 1 via a line or lines 40, 41, 42.
  • the gasifier 4 may be of a known type, such as of the fluidizing bed type.
  • air or other suitable gas or gas mixture may be supplied to the gasifier 4 via a line 38 or multiple such lines.
  • Gasification residues may be expelled from the gasifier via a line 36.
  • the product gas conveyance pathway comprising the lines 40, 41, 42 may further comprise a cooler 5 for cooling the product gas and/or a filter 7 for filtering out undesirable substances from the product gas before the product gas is supplied to the auxiliary superheating chamber 1.
  • a cooler 5 for cooling the product gas
  • a filter 7 for filtering out undesirable substances from the product gas before the product gas is supplied to the auxiliary superheating chamber 1.
  • heat energy may be conveyed from the cooler 5 to a heat exchanger 8 installed in the back conveyance pathway between lines 32 and 48, wherein the heat energy may be released into the water in the back conveyance pathway en route to be vaporized.
  • heat conveyance from the cooler 5 to the heat exchanger 8 may be brought about by circulating an appropriate heat transfer medium in the lines 52 and 53 between the cooler 5 and the heat exchanger 8.
  • the heat exchanger 8 may be used to pre-heat the water to be vaporized.
  • product gas may be additionally conveyed via line 47 to the boiler 10 to be used as fuel.
  • Such fuel use may be advantageously used, for example, as fuel being burned during hot standby, and/or as supplementary fuel, and/or as main fuel and/or as the only fuel for the boiler 10.
  • the fuel conveyed via line 47 to the boiler may be burned with a burner 72 installed in the boiler 10.
  • This burner 72 may be dedicated to burning fuel to maintain the boiler 10 in hot standby.
  • the burner 72 may have multiple functionalities, such as burning fuel conveyed via lines 49 and/or 47 during normal operations when electricity is being produced in the power plant and/or burning fuel conveyed via lines 49 and/or 47 during hot standby.
  • fuel is continuously consumed in the burner 24 of the auxiliary superheating chamber 1 and/or the boiler 10 so that the gasifier 4 may be kept in continuous operation.
  • This has the benefit of avoiding start-up (i.e. heating) and shut-down periods for the gasifier 4.
  • start-up and shut-down periods may be several hours in duration, which imposes disadvantageous restrictions on the flexibility in terms of the load variability of the power plant.
  • the combustion gases resulting from burning fuel in the auxiliary superheating chamber 1 may be conveyed via a gas conveyance passage into the boiler 10 in which thermal energy may be recovered from the combustion gases.
  • the combustion gases may be conveyed from the auxiliary superheating chamber 1 into the boiler 10 via a line 43 as the gas conveyance passage as illustrated in Figure 1 .
  • the auxiliary superheating chamber 1 is installed to the outer wall of the boiler 10 the combustion gases may be conveyed from the auxiliary superheating chamber 1 to the boiler 10 via an opening between the auxiliary superheating chamber 1 and the boiler 10.
  • Thermal recovery of the said combustion gases in the boiler 10 may be effected, for example, by the superheater 11 and/or the heat exchanger 15 and/or any other means of recovering thermal energy that the boiler 1 comprises.
  • the combustion gases resulting from burning fuel in the auxiliary superheating chamber 1 may be vented out from the auxiliary superheating chamber via a line 37 such that the said combustion gases are not conveyed into the boiler 10.
  • the said combustion gases may be conveyed via a line 37 to elsewhere in the system (not shown), or alternatively to another system or process (not shown), or alternatively to the atmosphere (not shown).
  • thermal energy may be captured from these gases with a suitable heat exchanger arrangement, for example in a manner similar to how the heat exchanger 15 may be used to capture thermal energy from the combustion gases expelled from the boiler 10.
  • the back conveyance pathway may additionally comprise a condenser 14 for recovering heat from the steam and transferring it to a heat-consuming process 22.
  • the condenser 14 may comprise a single condenser device, or it may comprise a plurality of individual condenser devices. The varieties and using of condensers are well known in the industry, and such knowledge readily applies to the condenser 14.
  • the condenser 14 may be connected to a heat-consuming process 22 with lines 45, 46, in which a heat transfer medium, such as water, may circulate between the condenser 14 and the heat-consuming process 22.
  • the back conveyance pathway may comprise a pump or pumps 20 for effecting the circulation of the circulating substance between the boiler 10 and the steam turbine 3.
  • the back conveyance pathway may comprise a heat exchanger 25 in the boiler 10 for pre-heating or preferably vaporizing the water before it enters the superheater 11.
  • the heat exchanger 25 may comprise a single heat exchanger device, or it may comprise a plurality of individual heat exchanger devices. The properties and use of such heat exchangers is well known in the industry and this knowledge readily applies to the heat exchanger 25.
  • the heat exchanger 25 may comprise a plurality of tubes (not specifically illustrated) integrated into the side walls of the boiler 10.
  • Additional pre-heating of water in the back conveyance pathway may be effected by a heat exchanger 15 installed in the boiler 10, such as in the duct 71 for expelling the combustion gases from the boiler 10 as illustrated in Figure 1 .
  • the heat exchanger 15 installed in the boiler 10 may comprise a single heat exchanger device, or it may comprise a plurality of individual heat exchanger devices. If installed in the duct 71 as illustrated in Figure 1 , the heat exchanger 15 may capture thermal energy from the combustion gases of the boiler 10 and/or the auxiliary superheating chamber 2 before the combustion gases are expelled from the boiler 10 via the duct 71 of the boiler.
  • the capacity of the auxiliary superheating chamber 1, i.e. the amount of thermal energy it can generate in a unit of time, is selected such that when the power plant is run with a load W below its minimum rated viable load W MV , the auxiliary superheating chamber 1 is capable of further superheating the steam originating from the superheater 11 such that the minimum viable temperature T V of the steam entering the steam turbine 3 is satisfied.
  • the auxiliary superheating chamber 1 advantageously is capable of transferring to the steam the thermal energy required after the steam has been superheated at the superheater 11 so that the temperature T of the steam entering the steam turbine 3 is at least the minimum viable temperature T V such that the load range W L for the low load operating of the power plant extends substantially below its minimum rated viable load W MV .
  • the auxiliary superheating chamber 1 comprising the auxiliary superheater 2 may be used to extend the load range for viable operating of a power plant W V such that the load range for viable operating W V of the power plant comprises both the load range for normal operating W N and the load range for low load operating W L , wherein the auxiliary superheating chamber 1 may be used to further superheat steam in the load range for low load operating W L .
  • the auxiliary superheating chamber 1 may be used within the load range for normal operating of the power plant W N as well for example so as to use the auxiliary superheater 2 to further superheat the steam originating from the superheater 11 already before the minimum viable temperature T V of the steam entering the steam turbine 3 is reached, as illustrated in Figures 4 b to 4 d .
  • the load range for viable operating W V of the power plant is, inclusively, the load range between its minimum viable load W MVA and its full rated load W F .
  • the auxiliary superheating chamber 1 may additionally be utilized as a means to maintain the system in a hot standby mode.
  • Standby means that no electricity is being produced in the power plant, in which case the boiler 10 may be run down for example by way of no or very little fuel being burned in the boiler 10, or kept in a hot standby mode by way of burning fuel in the boiler in an amount sufficient to keep the boiler 10 at an elevated temperature.
  • Hot standby for the system means that the circulating water, in gaseous and/or liquid state, is maintained in such a high temperature that the system can be started up, i.e. electricity production with the generator 9 be started, with a start-up time substantially shorter than would be the case of the system was shut down without maintaining high temperature in the circulation of the circulating substance.
  • the thermal energy release to the circulating water required for maintaining the system in a hot standby temperature may be brought about by the superheating chamber 1 in which case no fuel or very little fuel may be burned in the boiler 10.
  • the thermal energy release to the circulating water required for maintaining the system in a hot standby temperature may be brought about by both the superheating chamber 1 and the boiler 10.

Landscapes

  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Control Of Steam Boilers And Waste-Gas Boilers (AREA)
EP18397514.3A 2017-05-10 2018-04-24 Verfahren und system zur erweiterung des lastbereichs eines kraftwerks mit einem kessel zur zuführung von dampf an eine dampfturbine Active EP3415816B1 (de)

Priority Applications (1)

Application Number Priority Date Filing Date Title
PL18397514T PL3415816T3 (pl) 2017-05-10 2018-04-24 Sposób i układ zwiększania zakresu obciążenia elektrowni z kotłem dostarczającym parę do turbiny parowej

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
FI20175419A FI128267B (fi) 2017-05-10 2017-05-10 Menetelmä ja järjestelmä höyryä höyryturbiinille tuottavan kattilan käsittävän voimalaitoksen kuormitusalueen laajentamiseksi

Publications (2)

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EP3415816A1 true EP3415816A1 (de) 2018-12-19
EP3415816B1 EP3415816B1 (de) 2020-10-28

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EP18397514.3A Active EP3415816B1 (de) 2017-05-10 2018-04-24 Verfahren und system zur erweiterung des lastbereichs eines kraftwerks mit einem kessel zur zuführung von dampf an eine dampfturbine

Country Status (7)

Country Link
EP (1) EP3415816B1 (de)
DK (1) DK3415816T3 (de)
ES (1) ES2848053T3 (de)
FI (1) FI128267B (de)
HU (1) HUE052435T2 (de)
PL (1) PL3415816T3 (de)
PT (1) PT3415816T (de)

Citations (3)

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Publication number Priority date Publication date Assignee Title
GB682410A (en) * 1950-02-24 1952-11-12 Vickers Electrical Co Ltd Improvements relating to power plant
US3002347A (en) * 1956-05-24 1961-10-03 Babcock & Wilcox Co Method and apparatus for a binary fluid power plant
US20150114320A1 (en) * 2013-10-29 2015-04-30 Emerson Process Management Power & Water Solutions, Inc. Steam temperature control using model-based temperature balancing

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US3213831A (en) 1963-12-23 1965-10-26 Combustion Eng Vapor generating apparatus
SU1048237A1 (ru) 1982-01-20 1983-10-15 Всесоюзный Заочный Политехнический Институт Котельна установка
SU1208406A1 (ru) 1984-06-25 1986-01-30 Всесоюзный Дважды Ордена Трудового Красного Знамени Теплотехнический Научно-Исследовательский Институт Им.Ф.Э.Дзержинского Парогенерирующа установка
US4676177A (en) 1985-10-09 1987-06-30 A. Ahlstrom Corporation Method of generating energy from low-grade alkaline fuels
JPH04129601U (ja) 1991-05-16 1992-11-27 金井 宏之 蒸気発生装置
FI102395B1 (fi) 1991-11-26 1998-11-30 Ahlstrom Machinery Oy Menetelmä energian talteenottamiseksi selluprosessien jäteliemistä
JPH05256428A (ja) 1992-03-13 1993-10-05 Takuma Co Ltd ごみ焼却処理装置
US5239946A (en) 1992-06-08 1993-08-31 Foster Wheeler Energy Corporation Fluidized bed reactor system and method having a heat exchanger
JPH08303718A (ja) 1995-05-10 1996-11-22 Mitsubishi Heavy Ind Ltd 循環流動層ボイラ
US20040011484A1 (en) 2002-05-13 2004-01-22 Andritz Oy, Helsinki, Finland Method of producing energy at a pulp mill
FI117479B (fi) 2002-07-22 2006-10-31 Metsae Botnia Ab Oy Menetelmä lämpö- ja sähköenergian tuottamiseksi
WO2008156397A1 (en) 2007-06-20 2008-12-24 Metso Power Ab Method for recovering chemicals and production of steam

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB682410A (en) * 1950-02-24 1952-11-12 Vickers Electrical Co Ltd Improvements relating to power plant
US3002347A (en) * 1956-05-24 1961-10-03 Babcock & Wilcox Co Method and apparatus for a binary fluid power plant
US20150114320A1 (en) * 2013-10-29 2015-04-30 Emerson Process Management Power & Water Solutions, Inc. Steam temperature control using model-based temperature balancing

Also Published As

Publication number Publication date
PT3415816T (pt) 2021-01-11
DK3415816T3 (da) 2021-02-01
EP3415816B1 (de) 2020-10-28
PL3415816T3 (pl) 2021-05-04
FI128267B (fi) 2020-02-14
FI20175419A (fi) 2018-11-11
HUE052435T2 (hu) 2021-04-28
ES2848053T3 (es) 2021-08-05

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