• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    The solution comprises a method of and a system for maintaining steam temperature and therefore electricity production efficiency with decreased loads of a steam turbine power plant comprising a fluidized bed boiler (12) and a fluidized bed superheater (2) adapted to superheat steam supplied to a steam turbine (3). According to the solution, the steam temperature may be maintained by providing, outside a furnace (10), additional heating to the fluidized bed material in its outer circulation, thereby increasing the amount of thermal energy available in the fluidized bed material to be transferred in the fluidized bed superheater (2) to the steam supplied to the steam turbine (3). Such additional heating may be performed by selectably supplying combustible gas with nozzles (111) into the fluidized bed material outside the furnace (10). As an additional aspect of the disclosed solution, the combustible gas may be produced with a gasifier (4).
    公开号:FI20175975A1
    申请号:FI20175975
    申请日:2017-11-02
    公开日:2019-05-03
    发明作者:Mikko Varonen；Matti Nieminen
    申请人:Valmet Technologies Oy；
    IPC主号:
    专利说明:

    A METHOD AND A SYSTEM FOR MAINTAINING STEAM TEMPERATURE WITH DECREASED LOADS OF A STEAM TURBINE POWER PLANT COMPRISING A FLUIDIZED BED BOILER
    FIELD OF THE DISCLOSED SOLUTION
    The disclosed solution deals with the operation of a steam turbine power plant comprising a fluidized bed boiler for steam generation.
    BACKGROUND OF THE DISCLOSED SOLUTION
    Steam turbine power plants are commonly used for the production of electricity. In combined heat and power (CHP) plants, thermal energy is not captured by the steam turbine.
    In steam turbine power generation, a boiler, Burning a suitable fuel in a furnace produces steam with a mass flow rate which steam is conveyed to a steam turbine. Steam refers to a circulating substance such as water in a gaseous state. In the boiler, the thermal energy released by the burnt fuel is transferred into the water circulating in the system, or other such circulating medium.
    In the system, a circulating fluidized bed (CFB) boiler, fluidized bed material in the system and transfer, to elsewhere in the system. The ultimate in heat, the vaporize, superheat, and the ultimate superheating for the steam to be supplied to the steam turbine. The final superheating is typically performed with a fluidized bed superheater with which the fluidized bed material comes into contact in its outer circulation.
    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. That is, the steam Entering the steam turbine typically is in a superheated state. Typically, when a power plant is in operation, 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 the rotary motion on the turbine output shaft. This shaft then drives an electric generator via a suitable driveline.
    Currently, decreasing the load of a steam turbine power plant adversely affects the efficiency with which the steam turbine power plant produces electricity. Close-up of a refurbished bed in a bed, isolated on a bed. cease altogether. This, in turn, adversely and significantly effects the temperature of the steam supplied to the steam turbine.
    The power of the steam turbine is the power plant in the steam turbine. gets lower. This is undesirable because steam with lower temperature may condense prematurely as it travels through the steam turbine, which water droplets may form which, in turn, may hit the turbine blades creating blade damage.
    SUMMARY OF THE DISCLOSED SOLUTION
    The method according to the disclosed solution is defined by the claim 1. The system is defined by the solution stated by the claim 12.
    A solution for a steam turbine in a power plant.
    The boiler is of a circulating fluidized bed (CFB) type, whereby the fluidized bed material may circulate in the system. More specifically, the fluidized bed material is circulating in a fluidized bed. The loop seal may comprise a fluidized bed superheater or it may be connected to a fluidized bed superheater.
    In the world, the city is in the midst of a flowing bed in the furnace. and as a result of burning fuel in the furnace. Is the burning in the furnace, the less fuel is being burned in the furnace. The steam turbine is superheated by the steamy bed superheater. have been exhausted. This is a conventional means of water spraying and the fluidized bed superheater.
    In the field of heat, the amount of heat generated by the furnace is lower than that of the fluidized bed material. This also has the effect of reducing the amount of thermal energy available to be transferred from the circulating fluidized bed material into the steam in the fluidized bed superheater.
    With very low loads of power plant, outer circulation of fluidized bed material may cease or nearly cease. As a result, the arrival of thermal energy with the fluidized bed material to the fluidized bed superheater may cease or nearly cease.
    Is the steam turbine in the steam turbine is a steam turbine. This may have adverse and undesirable consequences such as the reduction in efficiency with which electricity is produced with the steam turbine.
    As a result of the steam turbine, there is a risk of damage to the steam turbine.
    This article is intended for the purpose of reviewing the General Terms and Conditions of Use of the Substance. With the disclosed solution, it is possible to ensure that the fluidized bed material in contact and in the vicinity of the fluidized bed superheater has sufficient amount of thermal energy to be transferred into the steam supply to the steam turbine even under circumstances in which the outer circulation of fluidized bed material has diminished significantly or ceased.
    Thus, this is the solution, which is the only way to reduce the amount of heat that can be absorbed by the furnace. Therefore, with the disclosed solution, the temperature of the steam can be maintained sufficiently high even with a reduced power plant load.
    According to the disclosed solution, such additional heating of the fluidized bed material may be done by selectably supplying, i.e. selectably injecting, combustible gas into the fluidized bed material outside the furnace, whereby the combustion of the combustible gas Releases additional thermal energy into the fluidized bed material.
    According to the exploration chamber, or a heat exchanger chamber, or into a heat exchanger chamber, or a heat exchanger chamber.
    As an additional possibility according to the disclosed solution, the combustible gas may be produced by Gasification.
    The selectable injection of combustible gas to additionally heat the fluidized bed material outside the furnace may be effected by a control unit. The control unit can bring about such selectable injection by using, for example, the load of the power plant as input data. Thereby, the injection of combustible gas may be initiated, for example, once the load of the power plant decreases below the trigger load. Such a trigger load may be set for an example such that it is a load or is near the load below which the temperature of the steam entering the steam turbine cannot be maintained at or near its maximum temperature with conventional means. This is a conventional means of water spraying and the fluidized bed superheater.
    Alternatively, and as another example, the control unit may bring about such a selectable injection of combustible gas by using, for example, steam quality measurements as input data. This input data may comprise, for example, the temperature of the steam Entering the steam turbine. Thereby, the injection of combustible gas may be initiated, for example, once the temperature of the steam Entering the steam turbine drops below a specified alert temperature.
    Therefore, with the disclosed solution, the temperature of the steam entering the steam turbine can be maintained sufficiently high even with reduced power plant loads, i.e. when the production of thermal energy in the furnace is not, by itself, sufficient to maintain the temperature of the steam Entering the steam turbine sufficiently high.
    In this context, a sufficiently high temperature means a temperature with which the efficiency of electricity production is at or near the maximum efficiency obtainable with a full power plant load. Sufficiently high temperature can be the temperature which is the maximum temperature of the steam Entering the steam turbine which can be obtainable with full power plant load. Alternatively, a sufficiently high temperature may be 1-10 ° C lower, or 10-20 ° C lower, or 20-30 ° C lower, or 30-40 ° C lower, or 40-50 ° C lower, or 50-60 ° C lower than the maximum temperature of the steam Entering the steam turbine.
    Thus, with the disclosed solution, the efficiency of electricity production in a steam turbine power plant can be maintained at a high level even with reduced power plant loads.
    The additional heating of the fluidized bed material according to the disclosed solution advantageously requires no modifications in the steam circulation and supply system of the power plant. A power plant that can be used as a power source for a steam turbine. the steam turbine by transferring thermal energy to the steam from the fluidized bed material. According to the method, the temperature of the steam supplied to the steam turbine may be maintained by means of selectively additionally heating the fluidized bed material outside the furnace. Powered by a power plant, the method may not be the one that can be used for the power plant. the load of the power plant is at or above the trigger load, superheating steam with the fluidized bed superheater such that the temperature of the superheated steam Entering the steam turbine is at or near its maximum temperature; a superheating steam superheater, and a superheating steam superheat, , and conveying the superheated steam from the fluidized bed superheater to the steam turbine.
    (3) According to the fluidized bed material, there is an exited the furnace (2) (10), or (2) but not earlier than that of the fluidized bed (1).
    According to the disclosed solution, additional heating of the fluidized bed material may be brought about by the combustion of the combustible gas injected into the fluidized bed material. This article was previously published under Q399299 A system based on the solution of the steam turbine, a circulating fluidized bed boiler, and a fluidized bed superheater. The system of the power plant is below the power plant, and the power plant is below the power plant. Trigger load of the power plant, Trigger load of the power plant, Trigger load of the power plant, Trigger load of the power plant, the steam turbine is maintained at or near its maximum temperature.
    In addition, the system according to the solution may comprise a gasifier adapted to generate the product gas, and the lines adapted to convey the product gas from the gasifier to the gas injection nozzles for injection as the combustible gas.
    BRIEF DESRCIPTON OF THE FIGURES
    Figure 1 schematically illustrates a conventional steam production system of a power plant.
    Figure 2 schematically illustrating the production of a power plant according to an example, the system is selectively supplying combustible gas in a loop.
    Figure 3 schematically illustrates a steam production system of a power plant according to an example, the system comprising selectively supplying a combustible gas to be combusted in a combustion chamber.
    Figures 4a-c schematically illustrate a conventional loop seal heat exchanger chamber from different cross-sectional perspectives.
    Figure 5a schematically illustrates, according to an example, a loop seal heat exchanger chamber in a cross-sectional perspective as viewed from above.
    Figure 5b schematically illustrates, according to an example, a loop in the exchanger chamber with selectable injection of combustible gas, in a cross-sectional perspective with Figure 5a.
    Figure 5c schematically illustrates, according to an example, a loop seal chamber comprising a selectable injection of combustible gas, in a cross-sectional perspective B-B in a denotational line with Figure 5a.
    Figure 6 schematically illustrating the steam production system of a power plant.
    Figure 7 schematically illustrating the steam production system of a power plant.
    Figure 8 schematically illustrates a conventional arrangement of a heat exchanger chamber adjacent to a boiler, which comprises a heat exchanger houses a superheater.
    Figure 9a schematically illustrates, according to an example, an arrangement of a heat exchanger chamber adjacent to a boiler, comprising a heat exchanger houses a superheater, and an arrangement of additionally selectively supplying combustible gas to be combusted in the heat exchanger chamber.
    Figure 9b schematically illustrates, according to an example, an arrangement of a heat exchanger chamber adjacent to a boiler, comprising a heat exchanger house and a superheater, and including the arrangement additionally supplying a combustible gas to be fired in a gas lock between a dip leg and the heat exchanger chamber.
    Figure 10a schematically illustrating the steam flow of a steam turbine power plant in a conventional steam production system.
    Figures 10b schematically illustrate idealized relationships of mass flow of steam and temperature of steam Entering a steam turbine to load a steam turbine power plant in a steam production system according to the disclosed solution.
    Figure 11a schematically illustrates the idealized relationship between load and heat consumption of a power plant.
    Figure lib schematically illustrates the idealized relationship between fuel consumption and heat consumption of a power plant.
    Figure 12 schematically illustrates, according to an example, an arrangement comprising a loop seal chamber and an adjacent heat exchanger chamber, the arrangement comprising selectively supplying combustible gas to the heat exchanger chamber.
    Figure 13 schematically illustrates, for clarifying purposes, the notional scope of a boiler in terms of its key inflows and outflows.
    The figures are not in scale or suggestive of physical layout or dimensions of system components.
    DETAILED DESCRIPTION OF THE INVENTION
    In the text, the reference is made to the figures with the following numerals and denotations: W Load of a power plant at a point of time
    Wf Full rated load of a power plant
    Wmv Minimum rated viable load of a power plant
    Wth Trigger load of a power plant Wth Trigger load of a power plant
    Wu Load range for unviable operating of a power plant
    Wv Load range for viable operation of a power plant T Temperature of steam entering a turbine TF Maximum temperature of steam entering a turbine
    Ty Minimum viable temperature of steam Entering a steam turbine itl Mass flow rate of steam ITIf Mass flow rate of steam with full boiler load 1 Loop seal heat exchanger chamber 2 Fluidized bed superheater 3 Steam turbine 4 Gasifier 5 Cooler 6 Fuel source 7 Filter 8 Heat exchanger 9 Generator 10 Furnace 11 Heat exchanger 12 Boiler 13 Electricity-consuming process 14 Condenser 15 Heat exchanger 16 Combustion chamber 19 Plenum 20 Pump 21 Fuel source 22 Heat-consuming process 25 Heat exchanger 31-57 Line 60 Solids separator 61 Loop seal outlet 70 Driveline 71.72 Duct 100 Dip leg 101 Distributing zone 102 Feeding upleg 103 Bypass upleg 104 Superheater chamber 105 Discharge upleg 106 ^ - / Plenum 107 Recirculation channel 110 Nozzle 111 Gas nozzle 200 Heat exchanger chamber 201 Discharge passageway 202 Gas lock 203 Opening 300 Loop seal chamber 301 Distributing zone 303 Feeding upleg 304 «, ^ Superheater chamber 305 Bypass upleg 306 ^ / Plenum 307 Dip leg 308 Entrance chamber 310 Valve 320 Heat e xchanger chamber 361 Loop seal outlet 362 Heat exchanger chamber outlet
    The text of the passageway is not the same as in the text. It is appreciated that a person skilled in the art is capable of determining the physical properties of a passageway according to the properties and volume of the material to be conveyed as well as other such pertinent conveyance parameters and requirements.
    A power plant is a turbine power plant, which is a power plant, which is a power plant, which is a mechanical power plant. into electricity by a Generator 9.
    A furnace 10, a solids separator 60, ducts 72, 71, a loop there heat exchanger chamber 1 or a loop seal chamber 300, heat exchangers 25, 11, 15 and a superheater or superheaters 2. As schematically illustrated in Figure 13 for notional clarification purposes, such assemblage takes in air, fuel and water, and provides steam and flue gas as key outputs.
    In the text, the notion of a "fluidized bed material" is used to refer to a bed material which, under normal operating conditions, circulates in the system. It is appreciated that in a fluidized bed, the "fluidized bed material" may also be in. a non-fluidized state such as in a dip leg 100 via which the "fluidized bed material" may be conveyed back to the furnace 10 for re-use.
    Figure 1 schematically illustrating a conventional system for producing a superheated steam to be used in a steam turbine. In the system, such as a limestone, and from a duct 72, a solids separator 60 such as a cyclone, and from there via a dip leg 100 to a loop seal heat exchanger chamber 1, and from there via a loop seal outlet 61 back to the furnace 10. Such a circulation is thus referred to as the "outer circulation" of the fluidized bed material. By "internal circulation", in the form of a circulation element, such as inside the furnace.
    This is the type of heat exchanger 2, which is located in the loop seal heat exchanger. superheating of steam may be premised on transferring thermal energy from the fluidized bed material circulating in the system as described just above to the steam circulating in the system.
    Superheated steam is steam at a temperature T which is higher than the boiling point of a substance, such as water, at a particular pressure. Steam in a superheated state contains no entrained liquid. Thus, the temperature T of the superheated steam may decrease by some amount before the entrained liquid begins to form. Therefore, the higher the temperature T of the superheated steam, the more it may cool, i.e. release energy, before entrained liquid begins to form at a particular pressure.
    Typically, steam of sufficiently high quality for a steam turbine 3 refers to the 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 travels through the steam turbine 3.
    Typically, the pressure of the steam Entering the steam turbine 3 is kept constant in a power plant system. This pressure begins to decrease once steam enters the steam turbine 3, the steam starts to release energy and expand.
    In such a system is located in the loop seal heat exchanger chamber 1, also in the loop; dependent on the amount of thermal energy transferred to the fluidized bed material earlier in the outer circulation in the furnace 10 and as a result of the burning fuel in the furnace 10, the less fuel is being burned in the furnace 10, the less thermal 2. The lesser energy is over the steam in the fluidized bed superheater. exiting the fluidized bed superheater 2 and conveyed via line 31 to the steam turbine 3.
    In such a system, and as is known in the industry, as the generation of thermal energy in the furnace 10 is reduced as a result of Burning less fuel in the furnace 10, the outer circulation of the fluidized bed material is reduced in terms of mass flow of circulating fluidized bed material. That is, as the load W of the power plant is reduced, the outer circulation of the fluidized bed material may be reduced. This results in less thermal energy being available to be transferred from the circulating fluidized bed material into the steam in the fluidized bed superheater 2.
    As is well known in the industry, the amount of thermal energy generated in the furnace 10 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 furnace 10 and the type of fuel being fed. Typically, the boiler 12 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 to the furnace 10. Such automatic adjustment of the air and / or other gases may be effected, for example, in the combustion gases; t value, is obtained.
    Wing the power plant. Conventional, the temperature T of the steam turbine 3 may, to a degree. As a first example, steam attemperation may not be a good one. Hence, reducing the amount of attemperation will, ceteris paribus, cause the temperature T of steam to rise. 2) be the second example of the fluidized bed superheater; in the outer circulation which travels through the fluidized bed superheater 2 will, ceteris paribus, cause the temperature T of steam to rise.
    However, the fluidized bed superheater 2 is set to its maximum - lowering of power plant load W typically results in temperature T of steam Entering into steam turbine 3 getting lower. Henceforth, the load Wth and the full power plant Wth and the full power plant load Wf, for example steam attemperation may be over and over the fluidized bed superheater 2 decreases. Below the threshold load Wth, such preventive measures are no longer sufficient to prevent the steam temperature T from dropping as the power plant load W further decreases.
    Furthermore, with a low load W of the power plant, viz. with little fuel being burned in furnace 10, outer circulation of fluidized bed material may cease or nearly cease. As a result, the arrival of thermal energy with fluidized bed material to fluidized bed superheater 2 may cease or nearly cease.
    Such a low load W of the power plant may be, for example, 55-60%, or 50-55%, or 45-50%, or 40-45%, or 35-40%, or 30-35%, or 25-30%, or 20-25% of its full rated load Wf. Such a low load may be below the threshold load Wth ·
    Available, as the thermal energy available to be transferred in the fluidized bed superheater 2 into the steam to be supplied to the steam turbine 3 is reduced, especially below the threshold load WTH of the power plant, the temperature T of said steam may be reduced as a result. This article is from: http://www.facebook.com/watch tThe conditional prematurely while traveling through the steam turbine 3, causing water droplets being formed which may hit and cause damage to blades of steam turbine 3.
    Weaknesses in the use of the power plant are not available.
    With the disclosed solution, it is possible to provide the heat of the steam turbine 3. Thus, with the disclosed solution , the reduced production of thermal energy in the furnace 10 and therefore the reduced transfer of thermal energy to the fluidized bed material in the furnace 10 can be compensated by additionally heating the fluidized bed material outside the furnace 10.
    Hence, the temperature can be lower than the maximum temperature limit, T, or even with a reduced power plant load, reduced power plant load W may be below the threshold load Wth-
    This article is from: http://www.articledashboard.com/watch tAnti-heating, in the fluidized bed material.
    Figure 1 schematically illustrates, a system for producing a superheated steam to be used in a steam turbine. system, steam enters the steam turbine 3 with a temperature flow rate rh, the last of the time of the steam turbine 3 per unit of time.
    Determining steam properties may be performed by means of a flowmeter and / or a temperature sensor; steam flow computer and / or a control unit 23 for processing and / or storage. It is appreciated that determining steam properties are well known in the industry and suitable equipment for this purpose commercially available. Steam properties, once determined for example through measurement, may be used as control input data by control unit 23.
    Still referring to Figure 2, the steam properties may be determined by the method of measurement at least in line 31 at its Terminus at the steam turbine 3. In addition, as will be explained below, the steam properties may be otherwise determined as well, for example based on measurements in other loci in the system.
    Determining the properties of steam, including its temperature, as it enters into the steam turbine 3 may be indirect. This article is intended to provide a summary of the steam turbine 3 and terminates at the steam turbine. 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 the loci of interest, or they may be derived from the calculations based on the physical properties of the system. The notion of determining steam properties, as used in this text, includes also indirect determining as just described.
    In a power plant, the power plant is producing electricity, in which the power plant is generating electricity. steam Entering the steam turbine 3.
    The steam turbine 3 can be adapted to drive, via a driveline 70, an electric generator 9 which can supply electricity to an electricity-consuming process via line 44. The electricity consuming process can be specific and / or a localized process such as in a manufacturing facility, or in the electricity-consuming process may be aggregate electricity consumption in an electrical grid such as a district, a regional or a national electrical grid.
    Still referring to Figure 2, in the system, superheated steam may be produced by superheating steam or providing the final superheating for the steam in a fluidized bed superheater 2. Such a fluidized bed superheater 2 may be located in a loop seal heat exchanger chamber 1 .
    As is well known, apparatuses upstream from a fluidized bed superheater 2 such as a heat exchanger 25 and / or a heat exchanger 11 and / or a plurality of such heat exchangers may be employed to vaporize and / or superheat the water circulating in the system such that the water is already steam or steam in a superheated state when it enters the fluidized bed superheater 2.
    According to the example illustrated in Figure 2, the heat exchangers 11, 15 may be installed in the furnace 10.
    The fluidized bed superheater 2 may be a single heat exchanger device. Alternatively, the fluidized bed superheater 2 may be an aggregate of a plurality of individual heat exchanger devices. The same applies to heat exchangers 25, 11, 15.
    Still referring to Figure 2, fuel may be supplied to the furnace 10 from a fuel source 21 via a line 49 to be burned into the furnace 10. Air or other suitable gas or gas mixture required for Burning the fuel and / or bringing about fluidization of fluidized bed material may be conveyed to furnace 10 via line 50 or multiple such lines. Non-gaseous combustion residues such as ash resulting from Burning the fuel may be expelled from the furnace 10 via line 51. Combustion gases arising from the combustion of the fuel as well as other gases possibly injected into the furnace 10 may be expelled together with the fluidized bed material from the furnace 10 via a duct 72 to the solids separator 60.
    In the solids separator 60, the fluidized bed material may be separated from combustion and other possible gases. Thereby, the fluidized bed material may travel from the solids separator 60 via the dip leg 100 into the loop seal heat exchanger chamber 1. Correspondingly, the gases and the fine residue of the fluidized bed material such as fly ash may travel via a duct 71 to elsewhere in the process (not depicted). The solids separator 60 may be, for example, a cyclone.
    Before being expelled from the duct 71, thermal energy may be captured from the combustion and other gases with heat exchangers 11, 15.
    There is still a heat exchanger in the hole, but the heat is still in the air. the solids separator 60, one of the functions of the loop seal heat exchanger.
    1 2 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4. in which travel of fluidized bed material is denoted with Arrows. In Figures 4 «to 4r, an average typical surface of a fluidized bed material is schematically illustrated with an undulating dashed line. It is appreciated that due to possible fluidization in the loop seal heat exchanger chamber 1, the surface of the fluidized bed material is strictly speaking not definite. The same applies to other surfaces of fluidized bed material discussed below and illustrated in other Figures unless otherwise specified.
    4 Exterior Exposure to Heat Exchanger in the Exposure Exposure of Heat Exchanger 4 1 from the solids separator 60 via the dip leg 100 of the loop there heat exchanger chamber 1 into two flows, one of which travels via a bypass upleg 103 to 104. The Travel of the Flooded House 104. The Travel of the Flooded House 104 106 ^ -c, which nozzles 110 may have an appropriate directionality of injection. 102, and the feeding upleg 102, respectively, where the flow of the fluidized bed material may be controlled, such as controlling the proportion of fluidized bed material traveling via bypass upleg 103 and / or feeding upleg 102.
    Referring to Figures 4 «and Figure 4r, which is a BB cross section of a loop seal heat exchanger chamber 1 as denoted in Figure 4, a fluidized bed superheater 2 may be located in a superheater chamber 104 section of a loop seal heat exchanger chamber 1, the fluidized bed superheater 2 may be used to capture thermal energy form the fluidized bed material traveling through the superheater chamber 104. From the superheating chamber 104 the fluidized bed material may travel via discharge upleg 105 to the bypass upleg 103 and thereafter 61. The Nucleage of Nucleation of Nucleate 110 (//) which nozzles 110 may have an appropriate directionality of injection. The discrete plenums may allow feeding of air or other non-combustible gas with Plenum-specific flow rates and / or directions. Alternatively, there may be a different configuration of plenums such as one Plenum common to the superheater chamber 104 and discharge upleg 105.
    It is appreciated that the exchanger chamber 1 is known as heat exchanger chamber 1.
    From the loop seal heat exchanger chamber 1, the fluidized bed material may be conveyed for re-use to the furnace 10 via the loop seal outlet 61.
    Referring to Figures 10 «and 10 / in the industry, the amount of electricity generated by Generator 9 per unit of time, ie the power output of Generator 9, may be measured based on the voltage and current of the electricity output. Alternatively, or in addition, 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 the power plant is highly correlated with its heat consumption. The heat consumption in the power plant is the heat production in the power plant. A plant-specific energy loss is a plant-specific energy loss. Figures Ila and lib illustrate the idealized relationships between these measures. Such measurements are part of a normal power plant instrumentation.
    The power plant is burning in the furnace. the power plant. Thus, the load W of the power plant may be controlled by adjusting the fuel being burned for purposes of producing and heating the steam and the amount of fuel being burned and / or fed can usually be taken as a reasonably proxy for the load W of the power plant.
    The power plant may be run with different loads W, as illustrated in Figures 1 {D and 10 / i.
    Figure 1 (Figure 3) The operation of the system for generating steam in a steam turbine. additional heating to the fluidized bed material outside the furnace 10.
    As illustrated in Figure 10 «, a power plant may have full rated load Wf. This refers to the load of the power plant which may be obtained with a full rated load of the furnace 10, viz. when the maximum rated amount of fuel is burned in the furnace 10. With the full rated load wf, the maximum amount of thermal energy is transferred in the heat exchanger 25, 11, 15 and the fluidized bed superheater 2 into the steam fed into the steam turbine 3. At this full rated load Wf of the power plant, the temperature T of the superheated steam Entering into the steam turbine 3 is at its maximum Tf, which can be the maximum temperature of the steam available with full power plant load Wf.
    The maximum temperature is Tf of the steam turbine. steam and / or by adjusting the proportion of fluidized bed material in outer circulation traveling via fluidized bed superheater 2, as explained earlier.
    With such an arrangement, the temperature T of the steam Entering the steam turbine 3 may be baked at the maximum temperature Tf across the load range between the threshold load Wth and the full load Tf of the power plant as illustrated in Figure 10 <x
    Still referring to Figure 10 «, below the threshold load Wth of the superheated steam Entering into the steam turbine Typically, the pressure of the superheated steam is kept constant, but the mass of the superheated steam is a turbulent steam turbine. superheater 2 into steam, illustrated in Figure Khz
    It is as much as possible, as is the power of the plant.
    With respect to the fluidized bed superheater 2 in particular, the amount of thermal energy transferrable to the steam, thereafter to be supplied to the steam turbine 3, may be further influenced by adjusting the fluidization rate or fluidization rates in the loop seal heat exchanger chamber 1, such as increasing the rate of fluidized bed material circulation for increased transfer of thermal energy from the fluidized bed material to steam in the fluidized bed superheater 2. Such an influence may be brought about by, for example, adjusting the gas injection rate through plenum 106v - / 'to the corresponding nozzles 110. The supply of fluid gas to the furnace 10 via the line 50 may be used in the same way.
    This is the case of the power plant further decreases.
    In addition, low power plant loads W may increase emissions of the power plant, which emissions may have a regulatory ceiling which may not be exceeded. In other words, there may be an emissions-imposed floor for the power plant load W beyond which the load W may not be reduced. Such an emissions ceiling may be higher than in the past, due to the cost of the furnace 10.
    Still referring to Figure 10 <z, as the load W of the power plant gets lower from the threshold load WTH, it may reach the minimum viable load Wmv below which the power plant may not be viably operated. Wu of the Wu of the Wu of the Wu of the Wu of the Wu of the Wu the power plant is the load range with loads W below the minimum viable load Wmv · The range is viable operating Wv is the power plant is, in turn, the load range with loads W at and above the minimum viable load Wmv ·
    At the minimum viable load Wmv, there may be very little outer circulation of the fluidized bed material, or the outer circulation of the fluidized bed material may have ceased.
    10. In this article: t continental,,,,,,,,,,,,,,,,.
    This is the case for the Wth. Wth, including the threshold load Wth.
    Into the loop there is a heat exchanger chamber 1, by illustrated in Figure 2 the combustible gas is combusted as it comes into contact with the hot fluidized bed material. As a result, thermal energy is the fluidized bed.
    In such a case, it is necessary to ensure that the combustible gas is present. The minimum temperature for this ignition depends on the gas being used. Typically, at least 700-750 ° C, or 800-850 ° C. The same principle applies, mutatis mutandis, to other examples described below.
    In such a case, and in general, the combustion of the combustible gas when in contact with the fluidized bed material requires that there is oxygen available for the combustion at or in the immediate vicinity of the locus of injection. The same principle applies, mutatis mutandis, to other examples described below.
    Still referring to the example illustrated in Figure 2, with such a selectable injection of combustible gas into the loop seal heat exchange chamber 1, the temperature T of the steam entering the steam turbine 3 may be maintained sufficiently high, preferably at its maximum temperature Tf, even under circumstances in which the outer circulation of the fluidized bed material has been reduced or has ceased and / or below the threshold load Wth of the power plant.
    Such selectable injection of combustible gas into the loop seal heat exchanger chamber 1 may be done at least in two ways.
    Firstly, as illustrated in Figure 5b, combustible gas can be selectively injected, with gas nozzles 111 installed in the feed of the feeding upleg 102 section. A fluidized bed superheater chamber 104 housing the fluidized bed superheater 2.
    Secondly, as illustrated in Figure 5c, combustible gas can be selectively injected via the line 42, with gas nozzles 111 installed in the superheater chamber 1, for example in the floor 104, the fluidized bed superheater 2.
    5th to 5c, the loop there heat exchanger chamber 1 be Such with 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. 7. the feeding upleg section 102 and the superheater chamber 104 section. Such a recirculation channel 107 may be provided in order to enable circulation of the fluidized bed material within the loop seal heat exchange chamber 1, especially under circumstances in which the outer circulation of the fluidized bed material has been significantly reduced or has ceased.
    As illustrated in Figure 3, as illustrated in Figure 3; the combustible gas is combusted as it comes into contact with the hot fluidized bed material. 16 such fluidized bed material circulation between the loop and the combustion chamber 16 heat exchanger chamber 16. there is a heat exchanger chamber in the air. chamber 1 and the combustion chamber 16 may be brought about in accordance with the principle of communicating vessels via the lines 56 and 57.
    Thereby, the example of the fluidized bed material, in the loop in the fluidized bed superheater 2 in the loop there heat exchanger chamber 1.
    According to the following example, as illustrated in Figure 9, with a fuel source 6 via a line 42, with gas nozzles 111 This gas nozzles 111 may be installed in the heat exchanger chamber 200 as it comes in the heat exchanger chamber. into the fluid in the fluidized bed of the fluid in the fluidized bed. superheater 2 in heat exchanger chamber 200 may be increased. For illustrative clarity, Figure 8 illustrates a typical such setup without the injection of combustible gas according to the disclosed solution.
    According to another example, as illustrated in Figure 9 gas lock 202 between the dip leg and the heat exchanger chamber 200 adverts to the furnace 10. Thus, the gas nozzles 111 may be installed in the gas lock 202, or traveling through the gas lock 202 en route to the heat exchange chamber 200 is the heat exchanger chamber in the heat exchanger chamber 200 may be Increased.
    According to another example, as illustrated in FIG. 12, there is provided a loop seal chamber 300 devoid of any superheater (s). In such a setup, a fluidized bed superheater 2 may be located in the heat exchanger chamber 320, but alternatively the exchanger chamber 320, but alternatively the heat exchanger chamber 320 may be provided with one, three, four or more fluidized bed superheaters 2.
    This is the example of the exterior exchanger chamber 320 may be connected to the loop. by means of a valve;
    Chambers 304 «, / housing the fluidized bed superheater (s) 2.9. (s) 304 «, A, the thermal energy of the fluidized bed superheater (s) 2 in the superheater chamber (s) 304«, b may be increased.
    This is an example of a fluidized exchanger chamber outlet 300 via a heat exchanger chamber outlet. 361 -rinto the nozzles 110, and, mutatis mutandis, in the heat exchanger chamber 320 through plenums 3Q {sd-f into the nozzles 110.
    As an additional possibility, the combustible gas to be selectively injected to additionally heat the fluidized bed material outside the furnace 10 may be produced with a gasifier 4. Figures 6 and 7 illustrate this according to examples.
    According to the example illustrated in Figure 6, the fuel supply of a gasifier can be a gas generator. without being gasified into the final fuel, ie into product gas, i.e. into combustible gas. Such initial fuels can be gasified may comprise, for example, biomass and / or waste. As illustrated in Figure 6, the initial fuel may be conveyed from the fuel source 6 via line 39 to the gasifier 4. The final fuel may be conveyed from the gasifier 4 to the loop seal heat exchanger chamber 1 via line or lines 40, 41 , 42.
    The gasifier 4 may be of a known type such as of a fluidizing bed type. For Gasification, 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 line 36 or multiple such lines.
    If the combustible gas is produced by the gasifier 4, the product gas conveyance pathway is the lines 40, 41, 42 1. and the filter 7.
    If the cooler is not used, then the heat energy may not be present in the water. and 48. Such heat conveyance 5 is the heat exchanger 8 and the heat exchanger 8 and the heat exchanger 8.
    This product is not part of the original version of this product. only fuel for the boiler 10.
    This is a description of the product, as well as a generic description of the product. gas can be selectively injected into the combustion chamber 1 illustrated in Figure 7, or into the heat exchange chamber 200 illustrated to the furnace 10 illustrated in Figure 9, or into the heat exchanger chamber 320 adjacent to the loop seal chamber 300 illustrated in Figure 12.
    The selectable injection of combustible gas to additionally heat the fluidized bed material outside the furnace 10 may be effected by a control unit 23.
    The control unit 23 may bring about such a selectable injection of combustible gas by using, for example, steam quality measurements as input data. Said input data may comprise, for example, temperature T of steam Entering steam turbine 3, for example as measured at Terminal of line 31 at steam turbine 3.
    As another example, the control unit 23 may bring about such a selectable injection of combustible gas by using the load W of the power plant as input data. As explained above, and / or the amount of fuel used in the plant, and / or or fed into the furnace 10 in a unit of time.
    Towards this end, and referring to Figure 10 // there may be a trigger load Wtr for the power plant. The trigger load Wtr may be used to trigger the commencement of injecting combustible gas. ie is below the trigger load Wtr. Alternatively, and as another example, the injection of combustible gas may be commenced when the load W is at or below the trigger load Wtr.
    The trigger load Wtr may be set, for example, to coincide with the threshold load Wth of the power plant. As another example, the trigger load Wtr may be set above the threshold load Wth, as illustrated in Figure 10 / . The trigger load Wtr is greater than the minimum rated load Wmv and less than the full rated load Wf of the power plant.
    According to the example example, the trigger load is the same as that of the wind turbine. steam with water spraying, have not quite been exhausted when the injection of combustible gas is commenced.
    For example, the injection of combustible gas may be commenced when 1% or 5% of 10% or 15% of the maximum attemperation water spray volume is being used. In other words, the trigger load is the amount of water spraying that is used to keep the steam Entering the steam turbine 3 at its maximum temperature Tf. The temperature of the steam turbine 3. Such control may be, for example, keeping the temperature T of the steam Entering the steam turbine 3 at or near its maximum temperature Tf during the injection of the combustible gas.
    60% or 55% or 50% or 45% or 40% or 35% or 45% or 40% or 35% % or 30% or 25% of full power plant load Wf. This is a specific level of load. Wtr may be such a load.
    The injection of combustible gas may be discontinued once the load W of the power plant is raised above the trigger load Wtr, or another set de-triggering load W (not specifically illustrated). In addition, the injection of combustible gas may be discontinued once the load W of the power plant is lowered below its minimum rated effective load Wmv ·
    Alternatively, the injection of the combustible gas may be commenced once it is observed, for example by the control unit 23 the temperature T the steam entering the steam turbine 3 has dropped by a certain amount, for example by a certain number of temperature degrees such as by 1 ° C, or 5 ° C, or 10 ° C, or 15 ° C, or 20 ° C below the maximum temperature Tf. In other words, there may be an alert temperature That which may be used as a trigger for commuting the injection of combustible gas in correspondence with what is explained above.
    Alternatively; and / or the heat exchanger chamber 1 and / or the heat exchanger chamber. the boiler 10 and / or the superheater chamber (s) 304,, a trigger for control actions, such as example, the control unit 23. Such control actions may be, for example, discontinuing the selection of the combustible bed material in the locus o f injection is too low for adequate combustion of the combustible gas, which may imply reaching the minimum rated viable load Wmv of the power plant, as illustrated in Figures 10 £ to KW.
    With respect to the examples provided above, and generally with respect to the disclosed solution, the gas nozzles 111 may advantageously be provided with the gas flow over the entire running load W range of the power plant such as over the load range for the viable operating Wv or over combined load range of viable operating Wv plus unviable operating Wu- By doing so the gas nozzles may be prevented from becoming clogged by the fluidized bed material. For example, the gas nozzles 111 may be provided with a flow of combustible gas when the power plant is run with a load below the trigger load Wtr, and be provided with a flow of non-combustible gas such as the air when the power plant is run with a load at or above the trigger load Wtr (the commission of non-combustible gas not specifically depicted).
    As an additional possibility (not specifically depicted), the gas injected with the gas nozzles is also present in the air. Such an arrangement may be a source of oxidizing gas for the combustion of the combustible gas. to a degree.
    Referring back to Figures 2 to 3 and 6 to 7, after the steam turbine 3 has been utilized in the steam turbine 3 may be conveyed back to the furnace 10 via a pathway comprising line or lines 34, 35, 33, 32, 48.
    This is a condenser 14 for a single condenser device, or for a condenser. of individual condenser devices. The varieties and using of the condensers are well known in the industry, and such knowledge is readily applied 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.
    In addition, or alternatively, the back conveyance pathway may comprise a pump or pumps 20 for effecting the circulation of the circulating substance such as water between boiler 12 and steam turbine 3.
    Advantageously, and referring to Figures 10 / to 10 //, the amount of combustible gas injected in accordance with the solution is selected such that when the power plant is run with the load W below the trigger load Wtr, the energy content of the combustible gas is, when burned, sufficient for further superheating the steam coming from the fluidized bed superheater 2 such that at least the minimum stable temperature Ty of the steam Entering the steam turbine 3 is satisfied and preferably such that the temperature T of the steam Entering the steam turbine 3 is maintained at or very close to its maximum temperature Tf. Controlling the amount of injected combustible gas may be performed, for instance, by the control unit 23, there may be a pre-programmed injection volume map for different loads W of the power plant based, for example, on known energy contents per unit volume of gas being injected.
    The disclosed solution is not limited to the examples and embodiments presented above. Furthermore, these examples and embodiments should not be considered as limiting but they can be used in various combinations to provide the desired results. More specifically, the disclosed solution is defined by the appended claims.
    权利要求:
    Claims (13)
    [1] 1. A method of maintaining the temperature (T) of steam supplied to a steam turbine (3) of a steam turbine power plant which power plant further comprises a circulating
    5 fluidized bed boiler (12) comprising a furnace (10) and a fluidized bed superheater (2) adapted to superheat steam supplied to the steam turbine (3) by transferring thermal energy to said steam from fluidized bed material, the temperature (T) of steam supplied to a steam turbine (3) being maintained by means 10 of selectably additionally heating the fluidized bed material outside the furnace (10); the method comprising:
    selecting a trigger load (Wtr) for the power plant, which trigger load (Wtr) is less than the full rated load (Wf) of the power plant and greater than the minimum rated viable load (Wmv) of the power plant,
    15 - determining the load (W) of the power plant, when the load (W) of the power plant is at or above the trigger load (Wtr), • superheating steam with the fluidized bed superheater (2) such that the temperature (T) of the superheated steam entering the steam turbine (3) is at or near its maximum temperature (Tf); and
    20 - when the load (W) of the power plant is below the trigger load (Wtr), • superheating steam with the fluidized bed superheater (2), and • additionally heating the fluidized bed material outside the furnace (10) such that the temperature (T) of superheated steam entering the steam turbine (3) is at or near its maximum temperature (TF), and
    25 - conveying the superheated steam from the fluidized bed superheater (2) to the steam turbine (3).
    [2] 2. The method according to claim 1, wherein the additional heating of the fluidized bed material occurs, with respect to an outer circulation of the fluidized bed material, at or
    30 before the fluidized bed superheater (2) and after the fluidized bed material has exited the furnace (10).
    [3] 3. The method according to claim 1 or 2, wherein the additional heating of the fluidized bed material occurs, with respect to the outer circulation of the fluidized bed material,
    20175975 prh 02 -11- 2017 at or before the fluidized bed superheater (2) but not earlier than the entrance of the fluidized bed material into a loop seal heat exchanger chamber (1).
    [4] 4. The method according to any of the preceding claims, wherein the additional heating of
    [5] 5 the fluidized bed material is brought about by the combustion of combustible gas injected into the fluidized bed material.
    5. The method according to claim 4, wherein the combustible gas is injected into the loop seal heat exchanger chamber (1).
    [6] 6. The method according to claim 4, wherein the combustible gas is injected into a combustion chamber (16), which combustion chamber (16) is arranged adjacent to the loop seal heat exchanger chamber (1) such that there is a circulation of fluidized bed material between the loop seal heat exchanger chamber (1) and the combustion chamber
    15 (16).
    [7] 7. The method according to claim 4, wherein the combustible gas is injected into a heat exchanger chamber (200) which heat exchanger chamber (200) houses the fluidized bed superheater (2) and is arranged adjacent to the furnace (10).
    [8] 8. The method according to claim 4, wherein the combustible gas is injected into a gas lock located between a dip leg (100) and a heat exchanger chamber (200) which heat exchanger chamber (200) houses the fluidized bed superheater (2) and is arranged adjacent to the furnace (10).
    [9] 9. The method according to claim 4, wherein the combustible gas is injected into a heat exchanger chamber (320) housing at least one superheater (2) and arranged adjacent to a loop seal chamber (300) devoid of any superheater(s).
    30 10. The method according to any of the claims 4 to 9, the method further comprising generating product gas by gasification with a gasifier (4) and using said product gas as the combustible gas.
    20175975 prh 02 -11- 2017
    11. The method according to claim 10, the method further comprising conveying at least some of the product gas generated with the gasifier (4) to the furnace (10) to be used as fuel to be burned in the furnace (10).
    5 12. A system comprising a steam turbine (3), a circulating fluidized bed boiler (12) comprising a furnace (10) and a fluidized bed superheater (2) adapted to superheat steam supplied to the steam turbine (3) by transferring thermal energy to said steam from fluidized bed material, and 10 - a control unit (23) adapted to:
    receive a set value for a trigger load (Wtr) for a power plant comprising the system which trigger load (Wtr) is less than the full rated load (Wf) of the power plant and greater than the minimum rated viable load (Wmv) of the power plant,
    15 - determine the load (W) of the power plant, and when the load (W) of the power plant is below the trigger load (Wtr), control the injection of combustible gas into the fluidized bed material outside the furnace (10) such that the temperature (T) of steam entering the steam turbine (3) is maintained at or near its maximum temperature 20 (Th).
    13. The system according to claim 12, the system further comprising a loop seal heat exchanger chamber (1) provided with gas injection nozzles (111) adapted to inject the combustible gas into the loop seal heat exchanger chamber (1).
    14. The system according to claim 12, the system further comprising a combustion chamber (16) arranged adjacent to the loop seal heat exchanger chamber (1) such that there is a circulation of fluidized bed material between the loop seal heat exchanger chamber (1) and the combustion chamber (16), and
    30 - gas injection nozzles (111) in the combustion chamber (16) adapted to inject the combustible gas into the combustion chamber (16) to additionally heat the fluidized bed material.
    15. The system according to claim 12, the system further comprising
    20175975 prh 02 -11- 2017 a heat exchanger chamber (200) housing the fluidized bed superheater (2) and arranged adjacent to the boiler (10), and gas injection nozzles (111) in the heat exchanger chamber (200) adapted to inject the combustible gas into the heat exchanger chamber (200) to additionally heat the 5 fluidized bed material.
    16. The system according to claim 12, the system further comprising a heat exchanger chamber (200) housing the fluidized bed superheater (2) and arranged adjacent to the boiler (10),
    [10] 10 - a gas lock (202) located between a dip leg (100) and the heat exchanger chamber (200), and gas injection nozzles (111) in the gas lock (202) adapted to inject the combustible gas into the gas lock (202) to additionally heat the fluidized bed material.
    [11] 15 17. The system according to claim 12, the system further comprising a heat exchanger chamber (320) housing at least one superheater (2) and arranged adjacent to a loop seal chamber (300) devoid of any superheater(s), and gas injection nozzles (111) in the heat exchanger chamber (320) adapted to inject the combustible gas into the heat exchanger chamber (320) to additionally heat the 20 fluidized bed material.
    [12] 18. The system according to any of the claims 12 to 17, the system further comprising a gasifier (4) adapted to generate product gas, and lines (40, 41, 42) adapted to convey the product gas from the gasifier (4) to the gas 25 injection nozzles (111) for injection as the combustible gas.
    [13] 19. The system according to claim 18, the system further comprising a line (47) adapted to convey product gas from the gasifier (4) to the furnace (10) for use as fuel in the furnace (10)·
    类似技术:
    公开号 | 公开日 | 专利标题
    RU2245446C2|2005-01-27|Combined cycle power plant and its operating process
    US4316420A|1982-02-23|Furnace heat absorption control
    JP6653862B2|2020-02-26|Method and ignition device for combustion management in an ignition device
    JP2014526595A|2014-10-06|Gasification reactor
    JP2004264002A|2004-09-24|Reheat steam temperature control method and apparatus for boiler
    FI128409B|2020-04-30|A method and a system for maintaining steam temperature with decreased loads of a steam turbine power plant comprising a fluidized bed boiler
    CS33090A3|1992-03-18|Steam generator and method of its intermediate superheater temperature control
    US4237825A|1980-12-09|Furnace heat absorption control
    JP4266879B2|2009-05-20|Gasification furnace and combined recycling equipment
    JP2009156553A|2009-07-16|Reheat steam temperature control method
    JP2007187352A|2007-07-26|Starting method of boiler
    JP5151921B2|2013-02-27|Combined power generation method and apparatus using two-column gasifier
    CN101666495A|2010-03-10|Method for controlling material return quantity of hearth of circulating fluidized bed boiler
    FI128267B|2020-02-14|A method and a system for extending the load range of a power plant comprising a boiler supplying steam to a steam turbine
    CN106524141B|2019-04-19|A kind of subcritical circulating fluidized bed boiler unit quick load change control method
    TWI435034B|2014-04-21|Fluidized bed combustor temperature controlling method
    CN102042587B|2012-09-19|Fluidized bed combustion furnace and control method thereof
    JP2017187199A|2017-10-12|Wet biomass incineration system and operational method of wet biomass combustion furnace
    US10260740B2|2019-04-16|Method and device for producing superheated steam by means of the heat produced in the boiler of an incineration plant
    JP2001041414A|2001-02-13|Inner temperature controller for circulating fluidized- bed combustor and operating method thereof
    CN215573803U|2022-01-18|High-temperature exhaust test bench
    CN207990607U|2018-10-19|A kind of system using this stove of adjacent stove Hot-blast Heating
    US10808191B2|2020-10-20|Gasification apparatus, control device, integrated gasification combined cycle, and control method
    JP2019148379A|2019-09-05|Power generation plant
    JP2004333036A|2004-11-25|Economizer tube water feed device for fire tube boiler
    同族专利:
    公开号 | 公开日
    FI128409B|2020-04-30|
    US20200363056A1|2020-11-19|
    WO2019086752A1|2019-05-09|
    EP3704410A1|2020-09-09|
    JP2021501866A|2021-01-21|
    CN212869719U|2021-04-02|
    引用文献:
    公开号 | 申请日 | 公开日 | 申请人 | 专利标题
    US5133943A|1990-03-28|1992-07-28|Foster Wheeler Energy Corporation|Fluidized bed combustion system and method having a multicompartment external recycle heat exchanger|
    US5239946A|1992-06-08|1993-08-31|Foster Wheeler Energy Corporation|Fluidized bed reactor system and method having a heat exchanger|
    FI110205B|1998-10-02|2002-12-13|Foster Wheeler Energia Oy|Method and apparatus in a fluidized bed heat exchanger|
    法律状态:
    2020-04-30| FG| Patent granted|Ref document number: 128409 Country of ref document: FI Kind code of ref document: B |
    优先权:
    申请号 | 申请日 | 专利标题
    FI20175975A|FI128409B|2017-11-02|2017-11-02|A method and a system for maintaining steam temperature with decreased loads of a steam turbine power plant comprising a fluidized bed boiler|FI20175975A| FI128409B|2017-11-02|2017-11-02|A method and a system for maintaining steam temperature with decreased loads of a steam turbine power plant comprising a fluidized bed boiler|
    CN201890001334.2U| CN212869719U|2017-11-02|2018-10-17|Steam generating system|
    PCT/FI2018/050757| WO2019086752A1|2017-11-02|2018-10-17|A method and a system for maintaining steam temperature with decreased loads of a steam turbine power plant comprising a fluidized bed boiler|
    JP2020524526A| JP2021501866A|2017-11-02|2018-10-17|Methods and systems for reducing the load on steam turbine power plants, including fluidized bed boilers, to maintain steam temperature|
    EP18796998.5A| EP3704410A1|2017-11-02|2018-10-17|A method and a system for maintaining steam temperature with decreased loads of a steam turbine power plant comprising a fluidized bed boiler|
    US16/754,681| US20200363056A1|2017-11-02|2018-10-17|A method and a system for maintaining steam temperature with decreased loads of a steam turbine power plant comprising a fluidized bed boiler|
    [返回顶部]