Control system and method for feedwater pump turbine unit

Abstract

The application provides a kind of governing system and method of feed water pump turbine unit, belong to power generation technical field.The system includes: main steam turbine unit, steam-driven feed water pump group, exhaust steam conversion unit and control unit;The main steam turbine unit includes: steam turbine unit, condenser and condensate pipeline, the exhaust steam end of the steam turbine unit is communicated with the input end of condenser, the input end of the condensate pipeline is communicated with the condensate output end of condenser;The condensate input end of the steam-driven feed water pump group is communicated with the output end of condensate pipeline, the exhaust steam end of the steam-driven feed water pump group is communicated with the steam input end of exhaust steam conversion unit, the exhaust steam conversion unit is installed on condensate pipeline;The control unit is electrically connected with main steam turbine unit, steam-driven feed water pump group and exhaust steam conversion unit respectively;The application will not affect the thermal load of condenser and the operation efficiency of generator unit, and can improve the system variable load capacity.

Description

Technical Field

[0001] This invention relates to the field of power generation technology, and more specifically to a control system and a control method for a feedwater pump turbine unit. Background Technology

[0002] Coal is China's largest primary energy source, and its efficient utilization is crucial for China's energy security and sustainable economic and social development. Steam-driven feedwater pumps are a primary means of reducing plant power consumption and improving power generation system performance. However, the steam turbines driving these pumps typically exhaust steam to the condenser of the main turbine generator unit, increasing the condenser's heat load, reducing its vacuum, and impacting the generator unit's operating efficiency. Summary of the Invention

[0003] The purpose of this invention is to provide a control system and method for a feedwater pump turbine unit, which solves the problem in the prior art that the feedwater pump turbine usually exhausts steam to the condenser of the main turbine generator unit, which causes an increase in the heat load of the condenser, a decrease in the vacuum of the condenser, and affects the operating efficiency of the generator unit.

[0004] To achieve the above objectives, the present invention provides a control system and method for a feedwater pump turbine unit, the system comprising: a main turbine unit, a steam-driven feedwater pump unit, an exhaust steam conversion unit, and a control unit;

[0005] The main steam turbine unit includes: a steam turbine unit, a condenser, and a condensate pipeline. The exhaust end of the steam turbine unit is connected to the input end of the condenser, and the input end of the condensate pipeline is connected to the condensate output end of the condenser.

[0006] The condensate inlet of the steam-driven feedwater pump set is connected to the output end of the condensate pipeline, and the exhaust end of the steam-driven feedwater pump set is connected to the steam inlet of the exhaust conversion unit. The exhaust conversion unit is installed on the condensate pipeline of the condensing unit.

[0007] The control unit is electrically connected to the main steam turbine unit, the steam-driven feedwater pump unit, and the exhaust steam conversion unit, respectively.

[0008] The control unit is used for:

[0009] Obtain the operating load status of the main steam turbine unit;

[0010] If the operating load of the main steam turbine unit is in a variable load state, obtain the current variable load rate of the main steam turbine unit;

[0011] The operating load of the steam-driven feedwater pump unit is adjusted according to the current load variation rate of the main steam turbine unit so that the operating load of the steam-driven feedwater pump unit matches the operating load of the main steam turbine unit.

[0012] Preferably, the condensate pipeline includes: a delivery pipe, a first-stage condensate pump, a shaft seal heater, a second-stage condensate pump, a low-pressure heater, and a deaerator;

[0013] The inlet of the conveying pipe is connected to the condensate outlet of the condenser, and the outlet is connected to the condensate inlet of the steam-driven feedwater pump group. The first-stage condensate pump, shaft seal heater, second-stage condensate pump, low-pressure heater and deaerator are installed on the conveying pipe in sequence along the condensate conveying direction.

[0014] The exhaust steam conversion unit is installed on the delivery pipe between the shaft seal heater and the second-stage condensate pump.

[0015] Preferably, the exhaust steam conversion unit is a hybrid low-pressure heater.

[0016] The present invention also provides a method for regulating a feedwater pump turbine unit, which is based on the above-mentioned regulation system for the feedwater pump turbine unit, and the method includes:

[0017] Obtain the operating load status of the main steam turbine unit;

[0018] If the operating load of the main steam turbine unit is in a variable load state, obtain the current variable load rate of the main steam turbine unit;

[0019] The operating load of the steam-driven feedwater pump unit is adjusted according to the current load variation rate of the main steam turbine unit so that the operating load of the steam-driven feedwater pump unit matches the operating load of the main steam turbine unit.

[0020] Preferably, before adjusting the operating load of the steam-driven feedwater pump unit according to the current variable load rate of the main turbine unit, the method further includes: constructing multiple rate intervals according to the magnitude of the variable load rate, and each rate interval has a preset adjustment scheme for adjusting the operating load of the steam-driven feedwater pump unit.

[0021] Preferably, the operating load of the steam-driven feedwater pump unit is adjusted according to the current load variation rate of the main steam turbine unit, including:

[0022] Match the rate range according to the current variable load rate of the main steam turbine unit;

[0023] The operating load of the steam-driven feedwater pump set is adjusted according to the adjustment scheme corresponding to the matched rate range.

[0024] Preferably, the adjustment scheme includes: main adjustment and auxiliary adjustment. The main adjustment includes: adjustment of the speed regulating valve opening of the steam-driven feedwater pump group and / or adjustment of the speed of the first-stage condensate pump on the condensate pipeline. The auxiliary adjustment includes: adjustment of the non-condensable gas extraction volume of the exhaust steam conversion unit.

[0025] Preferably, if the operating load of the main turbine unit is in a stable load state, the stable load includes: the current load of the main turbine unit is in a stable state or the main turbine unit is in a stable state after reaching the target load from a variable load;

[0026] The method further includes:

[0027] Obtain the current operating values ​​of the condensate pipeline;

[0028] The stable operating value of the condensate pipeline is determined based on the operating load of the main steam turbine unit;

[0029] If the current operating value of the condensate pipeline is not equal to the stable operating value, adjust the current operating value of the condensate pipeline to the stable operating value.

[0030] Preferably, the current operating values ​​of the condensate pipeline include: condensate temperature and condensate pressure, and the stable operating values ​​of the condensate pipeline include: a given temperature and a given pressure of the condensate.

[0031] Preferably, determining the stable operating value of the condensate pipeline based on the operating load of the main steam turbine unit includes:

[0032] Obtain the turbine heat rate and plant power consumption rate of the main steam turbine unit under stable load;

[0033] The turbine heat rate and plant power consumption rate are input into the preset algorithm as constraints to determine the given temperature and pressure of the condensate.

[0034] Through the above technical solution, the present invention has at least the following technical effects:

[0035] 1. By setting up an exhaust steam conversion unit, the exhaust steam of the steam-driven feedwater pump set is input to the exhaust steam conversion unit, which will not affect the heat load of the condenser or the operating efficiency of the generator set.

[0036] 2. The control unit of the present invention can quickly adjust the operating load of the steam-driven feedwater pump group according to the operating load status of the main steam turbine unit, and has a strong load change capability.

[0037] Other features and advantages of the present invention will be described in detail in the following detailed description section. Attached Figure Description

[0038] The accompanying drawings are provided to further illustrate embodiments of the present invention and form part of the specification. They are used together with the following detailed description to explain the embodiments of the present invention, but do not constitute a limitation thereof. In the drawings:

[0039] Figure 1This is a partial block diagram of the control system of a feedwater pump turbine unit provided in one embodiment of the present invention;

[0040] Figure 2 This is a flowchart of a control method for a feedwater pump turbine unit provided in one embodiment of the present invention.

[0041] Explanation of reference numerals in the attached figures

[0042] 1-Condenser; 2-Transfer pipe; 3-Exhaust steam conversion unit; 4-First-stage condensate pump; 5-Shaft seal heater; 6-Second-stage condensate pump; 7-Low-pressure heater; 8-Deaerator; 9-High-pressure cylinder; 10-Medium-pressure cylinder; 11-Low-pressure cylinder; 12-Generator; 13-Feed water pump; 14-Water pump turbine. Detailed Implementation

[0043] The specific embodiments of the present invention will be described in detail below with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are for illustration and explanation only and are not intended to limit the scope of the present invention.

[0044] Figure 1 This is a partial block diagram of the control system of a feedwater pump turbine unit provided in one embodiment of the present invention, as shown below. Figure 1 As shown, a control system for a feedwater pump turbine unit includes: a main turbine unit, a steam-driven feedwater pump unit, an exhaust steam conversion unit 3, and a control unit;

[0045] The main steam turbine unit includes: a steam turbine unit, a condenser 1, and a condensate pipeline. The exhaust end of the steam turbine unit is connected to the input end of the condenser 1, and the input end of the condensate pipeline is connected to the condensate output end of the condenser 1.

[0046] The condensate inlet of the steam-driven feedwater pump unit is connected to the outlet of the condensate pipeline, and the exhaust outlet of the steam-driven feedwater pump unit is connected to the steam inlet of the exhaust steam conversion unit 3. The exhaust steam conversion unit 3 is installed on the condensate pipeline. After the condensate in the condensate pipeline flows into the exhaust steam conversion unit 3, it undergoes mixing and heat exchange with the exhaust steam of the steam-driven feedwater pump unit. Part of the steam in the exhaust steam of the steam-driven feedwater pump unit condenses into water. In this embodiment, the exhaust steam conversion unit 3 preferably adopts a mixing low-pressure heater. Therefore, with the setting of the mixing low-pressure heater, the exhaust steam of the steam-driven feedwater pump unit will not be input to the condenser 1, and the heat load of the condenser 1 will not be increased, thus reducing the impact of the steam-driven feedwater pump unit on the operating efficiency of the generator 12.

[0047] In this embodiment, the steam-driven feedwater pump unit includes a feedwater pump 13 and a water pump turbine 14. The water pump turbine 14 drives the feedwater pump 13 to work. The condensate input end of the feedwater pump 13 is connected to the output end of the condensate pipeline. The steam of the water pump turbine 14 comes from the exhaust steam of the turbine unit. The exhaust steam end of the water pump turbine 14 is connected to the steam input end of the mixing low-pressure heater.

[0048] The control unit is electrically connected to the main steam turbine unit, the steam-driven feedwater pump unit and the exhaust steam conversion unit 3, respectively.

[0049] The control unit is used to: obtain the operating load of the main steam turbine unit; determine the state of the operating load of the main steam turbine unit; if the operating load of the main steam turbine unit is in a variable load state, obtain the current variable load rate of the main steam turbine unit; adjust the operating load of the steam-driven feedwater pump unit according to the current variable load rate of the main steam turbine unit so that the operating load of the steam-driven feedwater pump unit matches the operating load of the main steam turbine unit.

[0050] In this embodiment, the control unit can quickly adjust the operating load of the steam-driven feedwater pump group according to the operating load status of the main steam turbine unit, and has a strong load-changing capability.

[0051] As a further optimization of this embodiment, the condensate pipeline includes: a delivery pipe 2, a first-stage condensate pump 4, a shaft seal heater 5, a second-stage condensate pump 6, a low-pressure heater 7, and a deaerator 8;

[0052] The input end of the conveying pipe 2 is connected to the condensate output end of the condenser 1, and the output end is connected to the input end of the steam-driven feedwater pump group. The first-stage condensate pump 4, shaft seal heater 5, second-stage condensate pump 6, low-pressure heater 7 and deaerator 8 are installed sequentially on the conveying pipe 2 along the condensate conveying direction.

[0053] The exhaust steam conversion unit 3 is installed on the delivery pipe 2 between the shaft seal heater 5 and the second-stage condensate pump 6.

[0054] In this embodiment, the turbine unit includes a high-pressure cylinder 9, an intermediate-pressure cylinder 10, a low-pressure cylinder 11, and a generator 12. The high-pressure cylinder 9, intermediate-pressure cylinder 10, low-pressure cylinder 11, and generator 12 are coaxially connected. The exhaust steam from the low-pressure cylinder 11 is input into the condenser 1. The driving heat source for the shaft seal heater 5 is the extraction steam from the low-pressure cylinder 11. The driving heat source for the low-pressure heater 7 is the extraction steam from the low-pressure cylinder 11. The heat source for the deaerator 8 is the extraction steam from the high-pressure cylinder 9 and intermediate-pressure cylinder 10. The exhaust steam from the low-pressure heater 7 and shaft seal heater 5 is input into the condenser 1. In the condenser 1, the exhaust steam from the low-pressure cylinder 11, shaft seal heater 5, and low-pressure heater 7 is converted into condensate. The condensate is then heated to saturation by the low-pressure heater 7 and deaerator 8. The saturated condensate is then transported to the boiler for recycling, thereby improving the utilization rate of thermal energy and the thermal economy of the power generation system.

[0055] Figure 2 This is a flowchart of a control method for a feedwater pump turbine unit according to one embodiment of the present invention, as shown below. Figure 2 As shown, the method is implemented based on the aforementioned control system of the feedwater pump turbine unit, and the method includes:

[0056] Step S101: Obtain the operating load status of the main steam turbine unit;

[0057] Step S102: If the operating load of the main turbine unit is in a variable load state, obtain the current variable load rate of the main turbine unit. In this embodiment, the variable load is the main turbine unit increasing or decreasing the load at a set rate.

[0058] Step S103: Adjust the operating load of the steam-driven feedwater pump set according to the current variable load rate of the main steam turbine unit so that the operating load of the steam-driven feedwater pump set matches the operating load of the main steam turbine unit.

[0059] As a further optimization of this embodiment, before adjusting the operating load of the steam-driven feedwater pump group according to the current variable load rate of the main turbine unit, the method further includes: constructing multiple rate intervals according to the magnitude of the variable load rate, and each rate interval has a preset adjustment scheme for adjusting the operating load of the steam-driven feedwater pump group.

[0060] As a further optimization of this embodiment, the operating load of the steam-driven feedwater pump unit is adjusted according to the current load rate of the main turbine unit, including:

[0061] Step a01: When the main turbine unit is under variable load, match the rate range according to the current variable load rate of the turbine unit, wherein the current variable load rate is the preset initial rate at which the turbine unit is to reach the target load.

[0062] Step a02: Adjust the operating load of the steam-driven feedwater pump set according to the adjustment scheme corresponding to the matched rate range.

[0063] In this embodiment, the adjustment scheme includes: main adjustment and auxiliary adjustment. The main adjustment includes: adjustment of the speed regulating valve opening of the steam-driven feedwater pump group and / or adjustment of the speed of the first-stage condensate pump 4 on the condensate pipeline. The auxiliary adjustment includes: adjustment of the non-condensable gas extraction volume of the exhaust steam conversion unit 3. In this embodiment, the pressure inside the mixing low-pressure heater can be adjusted by adjusting the speed regulating valve opening of the steam-driven feedwater pump group, adjusting the speed of the first-stage condensate pump 4, and adjusting the non-condensable gas extraction volume. After the pressure inside the mixing low-pressure heater is changed, it is equivalent to adjusting the operating pressure (back pressure) of the steam-driven feedwater pump group, which can change the output of the steam-driven feedwater pump group and quickly change the operating load of the steam-driven feedwater pump group.

[0064] Among them, the speed regulation valve opening of the steam-driven feedwater pump set and the speed regulation of the first-stage condensate pump 4 can significantly regulate the operating pressure. The non-condensable gas extraction volume of the exhaust steam conversion unit 3 has a relatively small effect on the adjustment of the operating pressure. Therefore, in the process of regulating the operating pressure, the speed regulation valve opening of the steam-driven feedwater pump set and the speed of the first-stage condensate pump 4 are the main adjustment methods, and the non-condensable gas extraction volume of the exhaust steam conversion unit 3 is the auxiliary adjustment method. The combination of the two can quickly change the output of the steam-driven feedwater pump set, and can quickly and accurately improve the feedwater flow rate regulation rate. It can improve the load change rate of the power generation system, that is, the preset initial rate will gradually increase until the maximum limit of the load change rate. After the load change rate increases, steps a01 and a02 are executed again to improve the system's load change capability.

[0065] As a further optimization of this embodiment, if the operating load of the main steam turbine unit is in a stable load state, the stable load includes: the current load of the main steam turbine unit is in a stable state or the main steam turbine unit is in a stable state after reaching the target load from a variable load.

[0066] The method further includes:

[0067] Step b01: Obtain the current operating values ​​of the condensate pipeline. In this embodiment, the current operating values ​​of the condensate pipeline include: condensate temperature and condensate pressure.

[0068] Step b02: Determine the stable operating value of the condensate pipeline based on the operating status of the main steam turbine unit. In this embodiment, the stable operating value of the condensate pipeline includes: the given temperature and the given pressure of the condensate.

[0069] As a further optimization of this embodiment, the stable operating value of the condensate pipeline is determined based on the operating load of the main steam turbine unit, including:

[0070] Step b02.1: Obtain the turbine heat rate and plant power consumption rate of the main steam turbine unit under stable load;

[0071] Step b02.1: Input the turbine heat rate and plant power consumption rate as constraints into the preset algorithm to determine the given temperature and pressure of condensate. In this embodiment, the preset algorithm is a genetic algorithm or a particle swarm optimization algorithm.

[0072] Step b03: If the current operating value of the condensate pipeline is not equal to the stable operating value, adjust the current operating value of the condensate pipeline to the stable operating value. That is, if the condensate temperature is different from the given temperature, adjust the condensate temperature to the given temperature; or if the condensate pressure is different from the given pressure, adjust the condensate pressure to the given pressure.

[0073] This invention ensures the stability of condensate parameters in the low-pressure heating system by adjusting parameters such as condensate temperature and condensate pressure in the condensate pipeline, thereby ensuring the stable operation of the system.

[0074] This invention also provides an electronic device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements the above-described control method for a feedwater pump turbine unit.

[0075] This invention also provides a computer-readable storage medium storing a computer program thereon, which, when executed by a processor, implements the above-described control method for a feedwater pump turbine unit.

[0076] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0077] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this application. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart... Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0078] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0079] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0080] It should also be noted that the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such process, method, article, or apparatus. Unless otherwise specified, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes that element.

[0081] The above are merely embodiments of this application and are not intended to limit the scope of this application. Various modifications and variations can be made to this application by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this application should be included within the scope of the claims of this application.

Claims

1. A control system for a feedwater pump turbine unit, characterized in that, The system includes: a main steam turbine unit, a steam-driven feedwater pump unit, an exhaust steam conversion unit (3), and a control unit; The main steam turbine unit includes: a steam turbine unit, a condenser (1) and a condensate pipeline. The exhaust end of the steam turbine unit is connected to the input end of the condenser (1), and the input end of the condensate pipeline is connected to the condensate output end of the condenser (1). The condensate input end of the steam-driven feedwater pump set is connected to the output end of the condensate pipeline, and the exhaust end of the steam-driven feedwater pump set is connected to the steam input end of the exhaust conversion unit (3). The exhaust conversion unit (3) is installed on the condensate pipeline of the condensing unit. The control unit is electrically connected to the main steam turbine unit, the steam-driven feedwater pump unit, and the exhaust steam conversion unit (3), respectively. The control unit is used for: Obtain the operating load status of the main steam turbine unit; If the operating load of the main steam turbine unit is in a variable load state, obtain the current variable load rate of the main steam turbine unit; The operating load of the steam-driven feedwater pump unit is adjusted according to the current load change rate of the main steam turbine unit so that the operating load of the steam-driven feedwater pump unit matches the operating load of the main steam turbine unit. The control unit is also used to: construct multiple rate ranges according to the magnitude of the variable load rate, and each rate range is preset with a control scheme to adjust the operating load of the steam-driven feedwater pump group; The adjustment scheme includes: main adjustment and auxiliary adjustment. The main adjustment includes: speed regulation valve opening adjustment of the steam-driven feedwater pump group and / or speed regulation of the first-stage condensate pump (4) on the condensate pipeline. The auxiliary adjustment includes: non-condensable gas extraction volume adjustment of the exhaust steam conversion unit (3). The condensate pipeline includes: a delivery pipe (2), a first-stage condensate pump (4), a shaft seal heater (5), a second-stage condensate pump (6), a low-pressure heater (7), and a deaerator (8). The input end of the conveying pipe (2) is connected to the condensate output end of the condenser (1), and the output end is connected to the condensate input end of the steam-driven feedwater pump group. The first-stage condensate pump (4), shaft seal heater (5), second-stage condensate pump (6), low-pressure heater (7) and deaerator (8) are installed on the conveying pipe (2) in sequence along the condensate conveying direction. The exhaust steam conversion unit (3) is installed on the conveying pipe (2) between the shaft seal heater (5) and the second-stage condensate pump (6).

2. The control system for a feedwater pump turbine unit according to claim 1, characterized in that, The exhaust conversion unit (3) is a hybrid low-pressure heater.

3. A method for controlling a feedwater pump turbine unit, implemented based on the control system for the feedwater pump turbine unit according to any one of claims 1-2, characterized in that, The method includes: Obtain the operating load status of the main steam turbine unit; If the operating load of the main steam turbine unit is in a variable load state, obtain the current variable load rate of the main steam turbine unit; The operating load of the steam-driven feedwater pump unit is adjusted according to the current load rate of the main steam turbine unit so that the operating load of the steam-driven feedwater pump unit matches the operating load of the main steam turbine unit. Before adjusting the operating load of the steam-driven feedwater pump unit according to the current variable load rate of the main steam turbine unit, the method further includes: constructing multiple rate intervals according to the magnitude of the variable load rate, and each rate interval has a preset adjustment scheme for adjusting the operating load of the steam-driven feedwater pump unit. The adjustment scheme includes: main adjustment and auxiliary adjustment. The main adjustment includes: speed regulation valve opening adjustment of the steam-driven feedwater pump group and / or speed regulation of the first-stage condensate pump (4) on the condensate pipeline. The auxiliary adjustment includes: non-condensable gas extraction volume adjustment of the exhaust steam conversion unit (3). If the operating load of the main steam turbine unit is in a stable load state, the stable load includes: the current load of the main steam turbine unit is in a stable state or the main steam turbine unit is in a stable state after reaching the target load from a variable load; The method further includes: Obtain the current operating values ​​of the condensate pipeline; The stable operating value of the condensate pipeline is determined based on the operating load of the main steam turbine unit; If the current operating value of the condensate pipeline is not equal to the stable operating value, adjust the current operating value of the condensate pipeline to the stable operating value. The current operating values ​​of the condensate pipeline include condensate temperature and condensate pressure, and the stable operating values ​​of the condensate pipeline include a given condensate temperature and a given pressure.

4. The method according to claim 3, characterized in that, Adjust the operating load of the steam-driven feedwater pump unit according to the current load variation rate of the main steam turbine unit, including: Match the rate range according to the current variable load rate of the main steam turbine unit; The operating load of the steam-driven feedwater pump set is adjusted according to the adjustment scheme corresponding to the matched rate range.

5. The method according to claim 3, characterized in that, The stable operating values ​​of the condensate pipeline are determined based on the operating load of the main steam turbine unit, including: Obtain the turbine heat rate and plant power consumption rate of the main steam turbine unit under stable load; The turbine heat rate and plant power consumption rate are input into the preset algorithm as constraints to determine the given temperature and pressure of the condensate.

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