CN116733547A - Control system and method for water supply pump turbine unit - Google Patents
Control system and method for water supply pump turbine unit Download PDFInfo
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- CN116733547A CN116733547A CN202310609932.5A CN202310609932A CN116733547A CN 116733547 A CN116733547 A CN 116733547A CN 202310609932 A CN202310609932 A CN 202310609932A CN 116733547 A CN116733547 A CN 116733547A
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- 238000000034 method Methods 0.000 title claims abstract description 37
- 238000006243 chemical reaction Methods 0.000 claims abstract description 29
- 230000001105 regulatory effect Effects 0.000 claims abstract description 15
- 230000001276 controlling effect Effects 0.000 claims abstract description 11
- 238000009833 condensation Methods 0.000 claims description 23
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- 238000010248 power generation Methods 0.000 abstract description 5
- 238000004590 computer program Methods 0.000 description 10
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- 229920006395 saturated elastomer Polymers 0.000 description 2
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
- F01D—NON-POSITIVE DISPLACEMENT MACHINES OR ENGINES, e.g. STEAM TURBINES
- F01D21/00—Shutting-down of machines or engines, e.g. in emergency; Regulating, controlling, or safety means not otherwise provided for
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Abstract
The application provides a regulation and control system and a regulation and control method for a water supply pump turbine unit, and belongs to the technical field of power generation. The system comprises: the system comprises a main turbine unit, a steam-driven water supply pump set, a steam exhaust conversion unit and a regulation and control unit; the main turbine unit includes: the device comprises a steam turbine unit, a condenser and a condensed water pipeline, wherein the steam discharge end of the steam turbine unit is communicated with the input end of the condenser, and the input end of the condensed water pipeline is communicated with the condensed water output end of the condenser; the condensing water input end of the steam-driven water supply pump set is communicated with the output end of the condensing water pipeline, the steam discharge end of the steam-driven water supply pump set is communicated with the steam input end of the steam discharge conversion unit, and the steam discharge conversion unit is arranged on the condensing water pipeline; the regulating and controlling unit is respectively and electrically connected with the main turbine unit, the pneumatic water supply pump set and the steam exhaust conversion unit; the application can not influence the heat load of the condenser and the operation efficiency of the generator set, and can improve the load-changing capacity of the system.
Description
Technical Field
The application relates to the technical field of power generation, in particular to a regulation and control system and a regulation and control method of a water supply pump turbine unit.
Background
Coal is the primary energy with the largest reserve in China, and the high-efficiency utilization of the coal is an important guarantee for the safety of the energy in China and the sustainable development of the economy and society. The steam feed pump is a main means for reducing the station service power consumption and improving the performance of the power generation system. However, the steam turbine driving the water feed pump usually discharges steam to the condenser of the main steam turbine generator unit, so that the heat load of the condenser is increased, the vacuum degree of the condenser is reduced, and the operation efficiency of the generator unit is affected.
Disclosure of Invention
The application aims to provide a regulation and control system and method for a water supply pump turbine unit, which solve the problems that in the prior art, a steam turbine of a water supply pump normally discharges steam to a condenser of a main turbine generator unit, so that the heat load of the condenser is increased, the vacuum degree of the condenser is reduced, and the operation efficiency of the generator unit is affected.
In order to achieve the above object, the present application provides a regulation and control system and method for a water feed pump turbine set, the system comprising: the system comprises a main turbine unit, a steam-driven water supply pump set, a steam exhaust conversion unit and a regulation and control unit;
the main turbine unit includes: the device comprises a steam turbine unit, a condenser and a condensed water pipeline, wherein the steam discharge end of the steam turbine unit is communicated with the input end of the condenser, and the input end of the condensed water pipeline is communicated with the condensed water output end of the condenser;
the condensing water input end of the steam-driven water supply pump set is communicated with the output end of the condensing water pipeline, the steam discharge end of the steam-driven water supply pump set is communicated with the steam input end of the steam discharge conversion unit, and the steam discharge conversion unit is arranged on the condensing water pipeline of the condensing unit;
the regulating and controlling unit is respectively and electrically connected with the main turbine unit, the pneumatic water supply pump set and the steam exhaust conversion unit;
the regulation and control unit is used for:
acquiring the state of the operation load of the main turbine unit;
if the running load state of the main turbine unit is in a variable load state, acquiring the current variable load rate of the main turbine unit;
and adjusting the operation load of the steam-driven water supply pump set according to the current variable load rate of the main turbine set so as to enable the operation load of the steam-driven water supply pump set to be matched with the operation load of the main turbine set.
Preferably, the condensed water pipeline includes: the device comprises a conveying pipe, a first-stage condensate pump, a shaft seal heater, a second-stage condensate pump, a low-pressure heater and a deaerator;
the input end of the conveying pipe is communicated with the condensed water output end of the condenser, the output end of the conveying pipe is communicated with the condensed water input end of the steam-driven water supply pump group, and the first-stage condensed water pump, the shaft seal heater, the second-stage condensed water pump, the low-pressure heater and the deaerator are sequentially arranged on the conveying pipe along the conveying direction of the condensed water;
the exhaust steam conversion unit is arranged on a conveying pipe between the shaft seal heater and the second-stage condensate pump.
Preferably, the exhaust gas converting unit is a hybrid low pressure heater.
The application also provides a regulating and controlling method of the water feed pump turbine unit, which is realized based on the regulating and controlling system of the water feed pump turbine unit, and comprises the following steps:
acquiring the state of the operation load of the main turbine unit;
if the running load state of the main turbine unit is in a variable load state, acquiring the current variable load rate of the main turbine unit;
and adjusting the operation load of the steam-driven water supply pump set according to the current variable load rate of the main turbine set so as to enable the operation load of the steam-driven water supply pump set to be matched with the operation load of the main turbine set.
Preferably, before adjusting the operating load of the steam-fed water pump set according to the current variable load rate of the main turbine set, the method further comprises: and constructing a plurality of speed intervals according to the variable load speed, wherein an adjusting scheme for adjusting the operation load of the pneumatic water supply pump set is preset in each speed interval.
Preferably, the adjusting the operation load of the steam-driven water supply pump set according to the current load changing rate of the main turbine unit comprises:
matching a speed interval according to the current variable load speed of the main turbine unit;
and adjusting the operation load of the pneumatic water supply pump set according to the adjustment scheme corresponding to the matched speed interval.
Preferably, the adjustment scheme comprises: a primary adjustment and a secondary adjustment, the primary adjustment comprising: the speed regulation valve opening of the steam-driven water supply pump group is regulated, and/or the rotation speed of the first-stage condensate pump on the condensate pipeline is regulated, and the auxiliary regulation comprises: and (5) adjusting the extraction quantity of the non-condensed gas of the exhaust steam conversion unit.
Preferably, if the state of the operating load of the main turbine group is at a steady load, the steady 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 the variable load reaches the target load;
the method further comprises the steps of:
acquiring a current running value of a condensation water pipeline;
determining an operation stable value of a condensation pipeline according to the operation load of the main turbine unit;
and under the condition that the current operation value of the condensation water pipeline is not equal to the operation stable value, adjusting the current operation value of the condensation water pipeline to the operation stable value.
Preferably, the current operation value of the condensed water pipeline includes: the condensate temperature and the condensate pressure, the operational stability values of the condensate line include: a given temperature and a given pressure of the condensed water.
Preferably, determining an operational stability value of the condensate line based on an operational load of the main turbine unit includes:
acquiring the heat rate and the service power rate of a steam turbine of a main steam turbine unit under a stable load;
and inputting constraint conditions of the heat rate of the steam turbine and the plant power consumption into a preset algorithm, and determining the given temperature and the given pressure of the condensed water.
Through the technical scheme, the application has at least the following technical effects:
1. according to the application, the exhaust steam conversion unit is arranged, so that the exhaust steam of the steam feed pump set is input to the exhaust steam conversion unit, and the heat load of the condenser and the operation efficiency of the generator set are not influenced;
2. the regulating and controlling unit can quickly regulate the operation load of the steam-driven water supply pump set according to the state of the operation load of the main turbine unit, and has stronger load-changing capacity.
Additional features and advantages of the application will be set forth in the detailed description which follows.
Drawings
The accompanying drawings are included to provide a further understanding of embodiments of the application and are incorporated in and constitute a part of this specification, illustrate embodiments of the application and together with the description serve to explain, without limitation, the embodiments of the application. In the drawings:
FIG. 1 is a partial block diagram of a control system for a feedwater pump turbine assembly provided by one embodiment of the present application;
FIG. 2 is a flow chart of a method for regulating a feedwater pump turbine assembly according to one embodiment of the present application.
Description of the reference numerals
1-a condenser; 2-a conveying pipe; 3-a steam exhaust conversion unit; 4-a first stage condensate pump; 5-a shaft seal heater; 6-a second stage condensate pump; 7-a low pressure heater; 8-deaerator; 9-a high-pressure cylinder; 10-a medium pressure cylinder; 11-a low pressure cylinder; a 12-generator; 13-a feed pump; 14-a water pump turbine.
Detailed Description
The following describes the detailed implementation of the embodiments of the present application with reference to the drawings. It should be understood that the detailed description and specific examples, while indicating and illustrating the application, are not intended to limit the application.
FIG. 1 is a partial block diagram of a control system for a feedwater pump turbine set according to an embodiment of the present application, as shown in FIG. 1, the control system for a feedwater pump turbine set comprising: the main turbine unit, the steam-driven water supply pump set, the steam exhaust conversion unit 3 and the regulation and control unit;
the main turbine unit includes: the steam turbine unit, condenser 1 and condensate line, the exhaust end of steam turbine unit communicates with the input of condenser 1, the input of condensate line communicates with the condensate output of condenser 1.
The condensed water input end of the steam-driven water supply pump set is communicated with the output end of the condensed water pipeline, the steam discharge end of the steam-driven water supply pump set is communicated with the steam input end of the steam discharge conversion unit 3, the steam discharge conversion unit 3 is arranged on the condensed water pipeline, after condensed water in the condensed water pipeline flows into the steam discharge conversion unit 3, mixed heat exchange is carried out with steam discharged by the steam-driven water supply pump set, and steam in the steam discharged by the steam-driven water supply pump set is partially condensed into water, and in the embodiment, the steam discharge conversion unit 3 preferably adopts a mixed low-pressure heater; therefore, the arrangement of the hybrid low-pressure heater prevents the exhaust steam of the steam-driven water supply pump set from being input into the condenser 1, so that the heat load of the condenser 1 is not increased, and the influence of the steam-driven water supply pump set on the operation efficiency of the generator 12 set is reduced.
In this embodiment, the pneumatic feed water pump stack comprises: the water supply pump 13 and the water pump turbine 14, the water pump turbine 14 is used for driving the water pump 13 to work, the condensate water input end of the water pump 13 is communicated with the output end of the condensate water pipeline, the steam of the water pump turbine 14 comes from the exhaust steam of the turbine unit, and the exhaust steam end of the water pump turbine 14 is communicated with the steam input end of the hybrid low-pressure heater.
The regulating and controlling unit is respectively and electrically connected with the main turbine unit, the pneumatic water supply pump set and the steam exhaust conversion unit 3;
the regulation and control unit is used for: acquiring the operation load of the main turbine unit; judging the state of the operation load of the main turbine unit; if the running load state of the main turbine unit is in a variable load state, acquiring the current variable load rate of the main turbine unit; and adjusting the operation load of the steam-driven water supply pump set according to the current variable load rate of the main turbine set so as to enable the operation load of the steam-driven water supply pump set to be matched with the operation load of the main turbine set.
In the embodiment, the regulating and controlling unit can quickly regulate the operation load of the steam-driven water supply pump set according to the operation load state of the main turbine unit, and has stronger load-changing capacity.
As a further optimization of the present embodiment, the condensation water pipeline includes: the device comprises a conveying 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 communicated with the condensed water output end of the condenser 1, the output end of the conveying pipe is communicated with the input end of the steam-driven water supply pump group, and the first-stage condensed water pump 4, the shaft seal heater 5, the second-stage condensed water pump 6, the low-pressure heater 7 and the deaerator 8 are sequentially arranged on the conveying pipe 2 along the conveying direction of condensed water;
the exhaust steam conversion unit 3 is arranged on the conveying pipe 2 between the shaft seal heater 5 and the second-stage condensate pump 6.
In this embodiment, the steam turbine unit includes: the high-pressure cylinder 9, the medium-pressure cylinder 10, the low-pressure cylinder 11 and the generator 12 are coaxially connected, the exhaust steam of the low-pressure cylinder 11 is input into the condenser 1, the driving heat source of the shaft seal heater 5 is the extraction steam of the low-pressure cylinder 11, the driving heat source of the low-pressure heater 7 is the extraction steam of the low-pressure cylinder 11, the heat source of the deaerator 8 is the extraction steam of the high-pressure cylinder 9 and the medium-pressure cylinder 10, the exhaust steam of the low-pressure heater 7 and the shaft seal heater 5 is input into the condenser 1, the exhaust steam of the low-pressure cylinder 11, the shaft seal heater 5 and the low-pressure heater 7 is converted into condensate, the condensate is heated into a saturated state through the low-pressure heater 7 and the deaerator 8, and the condensate in the saturated state is conveyed to the boiler for recycling, and the utilization rate of heat energy and the thermal economy of the power generation system are improved.
Fig. 2 is a flowchart of a method for controlling a water pump turbine set according to an embodiment of the present application, and as shown in fig. 2, the method is implemented based on the control system of the water pump turbine set, and the method includes:
step S101: acquiring the state of the operation load of the main turbine unit;
step S102: if the running load state of the main turbine unit is in a variable load state, the current variable load rate of the main turbine unit is obtained, and in the embodiment, the variable load is that the main turbine unit carries out load lifting or load lowering according to the set rate;
step S103: and adjusting the operation load of the steam-driven water supply pump set according to the current variable load rate of the main turbine set so as to enable the operation load of the steam-driven water supply pump set to be matched with the operation load of the main turbine set.
As a further optimization of this embodiment, before adjusting the operational load of the steam-driven water supply pump set according to the current variable load rate of the main turbine set, the method further includes: and constructing a plurality of speed intervals according to the variable load speed, wherein an adjusting scheme for adjusting the operation load of the pneumatic water supply pump set is preset in each speed interval.
As a further optimization of this embodiment, adjusting the operational load of the steam-driven water supply pump set according to the current load rate of the main turbine set includes:
step a01: when the main turbine unit is in variable load, matching a speed interval according to the current variable load speed of the turbine unit, wherein the current variable load speed is the preset initial speed of the current turbine unit to reach the target load;
step a02: and adjusting the operation load of the pneumatic water supply pump set according to the adjustment scheme corresponding to the matched speed interval.
In this embodiment, the adjustment scheme includes: a primary adjustment and a secondary adjustment, the primary adjustment comprising: the speed regulation valve opening of the steam-driven water supply pump group and/or the rotation speed of the first stage condensate pump 4 on the condensate pipeline are/is regulated, and the auxiliary regulation comprises: the extraction amount of the non-condensed gas of the exhaust steam conversion unit 3 is adjusted; in this embodiment, the pressure inside the hybrid low-pressure heater can be adjusted through the speed-adjusting valve opening adjustment of the pneumatic water supply pump set, the rotation speed adjustment of the first-stage condensate pump 4 and the extraction amount adjustment of the non-condensed gas, and after the pressure inside the hybrid low-pressure heater is changed, the operation pressure (back pressure) of the pneumatic water supply pump set is adjusted, so that the output of the pneumatic water supply pump set can be changed, and the operation load of the pneumatic water supply pump set can be changed rapidly.
The speed regulation valve opening degree of the steam-driven water supply pump set and the rotation speed of the first-stage condensate pump 4 can greatly regulate the operation pressure, the extraction amount of non-condensed gas of the steam-discharging conversion unit 3 is relatively small in the regulation range of the operation pressure, so that in the regulation process of the operation pressure, the speed regulation valve opening degree of the steam-driven water supply pump set and the rotation speed of the first-stage condensate pump 4 are used as main regulation modes, the extraction amount of non-condensed gas of the steam-discharging conversion unit 3 is used as auxiliary regulation modes, the output of the steam-driven water supply pump set can be quickly changed by the cooperation of the speed regulation valve opening degree of the steam-driven water supply pump set and the rotation speed of the first-stage condensate pump 4, the water supply flow regulation rate can be quickly and accurately improved, the variable load rate of a power generation system can be increased, namely the preset initial rate can be gradually increased to the maximum limit value of the variable load rate, and after the variable load rate is increased, the step a01 and the step a02 are executed again to improve the variable load capacity of the system.
As a further optimization of the present embodiment, if the state of the operating load of the main turbine group is at a steady load, the steady 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 the variable load reaches the target load;
the method further comprises the steps of:
step b01: the current operation value of the condensation water pipeline is obtained, and in this embodiment, the current operation value of the condensation water pipeline includes: condensation water temperature and condensation water pressure;
step b02: determining an operation stability value of a condensate pipeline according to an operation state of the main turbine unit, wherein in the embodiment, the operation stability value of the condensate pipeline comprises: a given temperature and a given pressure of the condensed water;
as a further optimization of the present embodiment, determining an operation stability value of the condensate line according to an operation load of the main turbine unit includes:
step b02.1: acquiring the heat rate and the service power rate of a steam turbine of a main steam turbine unit under a stable load;
step b02.1: inputting constraint conditions of the heat rate of the steam turbine and the plant power rate into a preset algorithm, and determining given temperature and given pressure of condensed water, wherein the preset algorithm is a genetic algorithm or a particle swarm algorithm in the embodiment;
step b03: under the condition that the current operation value of the condensation water pipeline is not equal to the operation stable value, the current operation value of the condensation water pipeline is adjusted to the operation stable value, namely, under the condition that the condensation water temperature is not equal to the given temperature, the condensation water temperature is adjusted to the given temperature; or adjusting the pressure of the condensed water to a given pressure in the case that the pressure of the condensed water is different from the given pressure.
The application can ensure the stability of the condensate parameters of the low-pressure system and ensure the stable operation of the system through adjusting the condensate temperature, the condensate pressure and other parameters in the condensate pipeline.
The embodiment of the application also provides electronic equipment, which comprises a memory, a processor and a computer program stored in the memory and capable of running on the processor, wherein the regulation and control method of the water supply pump turbine unit is realized when the processor executes the computer program.
The embodiment of the application also provides a computer readable storage medium, which stores a computer program, and the program is executed by a processor to realize the regulation and control method of the water supply pump turbine unit.
It will be appreciated by those skilled in the art that embodiments of the present application may be provided as a method, system, or computer program product. Accordingly, the present application may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present application may 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, and the like) having computer-usable program code embodied therein.
The present application is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems) and computer program products according to embodiments of the application. It will be understood that each flow and/or block of the flowchart illustrations and/or block diagrams, and combinations of flows and/or blocks in the flowchart illustrations and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may 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, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
It should also be noted that the terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, an element defined by the phrase "comprising one … …" does not exclude the presence of other like elements in a process, method, article or apparatus that comprises an element.
The foregoing is merely exemplary of the present application and is not intended to limit the present application. Various modifications and variations of the present application will be apparent to those skilled in the art. Any modification, equivalent replacement, improvement, etc. which come within the spirit and principles of the application are to be included in the scope of the claims of the present application.
Claims (10)
1. A regulation and control system for a feedwater pump turbine assembly, said system comprising: the system comprises a main turbine unit, a steam-driven water supply pump set, a steam exhaust conversion unit (3) and a regulation and control unit;
the main turbine unit includes: the device comprises a steam turbine unit, a condenser (1) and a condensation water pipeline, wherein the steam discharge end of the steam turbine unit is communicated with the input end of the condenser (1), and the input end of the condensation water pipeline is communicated with the condensation water output end of the condenser (1);
the condensation water input end of the steam-driven water supply pump set is communicated with the output end of the condensation water pipeline, the steam discharge end of the steam-driven water supply pump set is communicated with the steam input end of the steam discharge conversion unit (3), and the steam discharge conversion unit (3) is arranged on the condensation water pipeline of the condensing unit;
the regulating and controlling unit is respectively and electrically connected with the main turbine unit, the pneumatic water supply pump set and the steam exhaust conversion unit (3);
the regulation and control unit is used for:
acquiring the state of the operation load of the main turbine unit;
if the running load state of the main turbine unit is in a variable load state, acquiring the current variable load rate of the main turbine unit;
and adjusting the operation load of the steam-driven water supply pump set according to the current variable load rate of the main turbine set so as to enable the operation load of the steam-driven water supply pump set to be matched with the operation load of the main turbine set.
2. The feedwater pump turbine set regulation and control system of claim 1, wherein the condensate line comprises: the device comprises a conveying 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 communicated with the condensed water output end of the condenser (1), the output end of the conveying pipe is communicated with the condensed water input end of the steam-driven water supply pump set, and the first-stage condensed water pump (4), the shaft seal heater (5), the second-stage condensed water pump (6), the low-pressure heater (7) and the deaerator (8) are sequentially arranged on the conveying pipe (2) along the conveying direction of condensed water;
the exhaust steam conversion unit (3) is arranged on the conveying pipe (2) between the shaft seal heater (5) and the second-stage condensate pump (6).
3. The regulation and control system of a water pump turbine set according to claim 1, characterized in that the exhaust steam converting unit (3) is a hybrid low pressure heater.
4. A method for regulating and controlling a water feed pump turbine set, based on a regulating and controlling system of the water feed pump turbine set as claimed in any one of claims 1 to 3, characterized in that the method comprises:
acquiring the state of the operation load of the main turbine unit;
if the running load state of the main turbine unit is in a variable load state, acquiring the current variable load rate of the main turbine unit;
and adjusting the operation load of the steam-driven water supply pump set according to the current load rate of the main turbine set so as to enable the operation load of the steam-driven water supply pump set to be matched with the operation load of the main turbine set.
5. The method of claim 4, wherein prior to adjusting the operating load of the steam driven feedwater pump set based on the current variable load rate of the main turbine set, the method further comprises: and constructing a plurality of speed intervals according to the variable load speed, wherein an adjusting scheme for adjusting the operation load of the pneumatic water supply pump set is preset in each speed interval.
6. The method of claim 5, wherein adjusting the operating load of the steam driven feedwater pump set based on the current variable load rate of the main turbine set includes:
matching a speed interval according to the current variable load speed of the main turbine unit;
and adjusting the operation load of the pneumatic water supply pump set according to the adjustment scheme corresponding to the matched speed interval.
7. The method of claim 6, wherein the adjustment scheme comprises: a primary adjustment and a secondary adjustment, the primary adjustment comprising: the speed regulation valve opening of the steam-driven water supply pump group and/or the rotating speed of a first-stage condensate pump (4) on the condensate pipeline are/is regulated, and the auxiliary regulation comprises: and (3) adjusting the extraction quantity of the non-condensed gas of the exhaust steam conversion unit (3).
8. The method of claim 4, wherein if the operating load condition of the main turbine group is at a steady load, the steady load comprises: the current load of the main turbine unit is in a stable state or the main turbine unit is in a stable state after the variable load reaches the target load;
the method further comprises the steps of:
acquiring a current running value of a condensation water pipeline;
determining an operation stable value of a condensation pipeline according to the operation load of the main turbine unit;
and under the condition that the current operation value of the condensation water pipeline is not equal to the operation stable value, adjusting the current operation value of the condensation water pipeline to the operation stable value.
9. The method of claim 8, wherein the current operating value of the condensate line comprises: the condensate temperature and the condensate pressure, the operational stability values of the condensate line include: a given temperature and a given pressure of the condensed water.
10. The method of claim 9, wherein determining an operational stability value for the condensate line based on the operational load of the main turbine unit comprises:
acquiring the heat rate and the service power rate of a steam turbine of a main steam turbine unit under a stable load;
and inputting constraint conditions of the heat rate of the steam turbine and the plant power consumption into a preset algorithm, and determining the given temperature and the given pressure of the condensed water.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202310609932.5A CN116733547A (en) | 2023-05-26 | 2023-05-26 | Control system and method for water supply pump turbine unit |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202310609932.5A CN116733547A (en) | 2023-05-26 | 2023-05-26 | Control system and method for water supply pump turbine unit |
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| Publication Number | Publication Date |
|---|---|
| CN116733547A true CN116733547A (en) | 2023-09-12 |
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Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202310609932.5A Pending CN116733547A (en) | 2023-05-26 | 2023-05-26 | Control system and method for water supply pump turbine unit |
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| CN (1) | CN116733547A (en) |
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2023
- 2023-05-26 CN CN202310609932.5A patent/CN116733547A/en active Pending
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