CN114034033B - Liquid level control method and terminal for heater of water supply and heat recovery system of thermal power plant - Google Patents
Liquid level control method and terminal for heater of water supply and heat recovery system of thermal power plant Download PDFInfo
- Publication number
- CN114034033B CN114034033B CN202111387851.2A CN202111387851A CN114034033B CN 114034033 B CN114034033 B CN 114034033B CN 202111387851 A CN202111387851 A CN 202111387851A CN 114034033 B CN114034033 B CN 114034033B
- Authority
- CN
- China
- Prior art keywords
- liquid level
- heater
- heat
- steam
- power plant
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
Classifications
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F22—STEAM GENERATION
- F22D—PREHEATING, OR ACCUMULATING PREHEATED, FEED-WATER FOR STEAM GENERATION; FEED-WATER SUPPLY FOR STEAM GENERATION; CONTROLLING WATER LEVEL FOR STEAM GENERATION; AUXILIARY DEVICES FOR PROMOTING WATER CIRCULATION WITHIN STEAM BOILERS
- F22D5/00—Controlling water feed or water level; Automatic water feeding or water-level regulators
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F17/00—Digital computing or data processing equipment or methods, specially adapted for specific functions
- G06F17/10—Complex mathematical operations
- G06F17/15—Correlation function computation including computation of convolution operations
Landscapes
- Engineering & Computer Science (AREA)
- Physics & Mathematics (AREA)
- General Physics & Mathematics (AREA)
- General Engineering & Computer Science (AREA)
- Computational Mathematics (AREA)
- Theoretical Computer Science (AREA)
- Mathematical Analysis (AREA)
- Mathematical Optimization (AREA)
- Pure & Applied Mathematics (AREA)
- Data Mining & Analysis (AREA)
- Mathematical Physics (AREA)
- Algebra (AREA)
- Software Systems (AREA)
- Databases & Information Systems (AREA)
- Computing Systems (AREA)
- Thermal Sciences (AREA)
- Mechanical Engineering (AREA)
- Engine Equipment That Uses Special Cycles (AREA)
Abstract
The invention provides a liquid level control method and a terminal for a heater of a water supply and heat recovery system of a thermal power plant, and the method and the terminal are used for retrieving parameter data of a steam turbine generator unit stored in a database; classifying the electric power of the steam turbine generator unit, and calculating the extraction coefficients of all stages and the heat consumption rate of the unit; comparing the thermal economy of the liquid levels of different heaters under the same electric power of the steam turbine generator unit, and calculating the optimal working condition point of the liquid levels of the heaters under different loads in an accumulated iterative mode; the unit load is taken as an abscissa, the liquid level of the heater is taken as an ordinate, and a working condition curve is configured; recording a working condition curve into a DCS control system, and collecting the electric power of the steam turbine generator unit in real time to obtain the preset target liquid level of each heater; and comparing the actual liquid level with the target liquid level difference, and adjusting the target value to the preset target liquid level at a constant rate. The invention can realize the automatic control method of the water supply heat recovery system heater liquid level of the heat engine plant based on the DCS system along with the load change, so that the heat recovery system has the best running economy.
Description
Technical Field
The invention relates to the technical field of control of power systems, in particular to a liquid level control method and a terminal for a heater of a water supply and heat recovery system of a thermal power plant.
Background
At present, a feedwater backheating system of a thermal power plant extracts a part of steam from a plurality of intermediate stages of a steam turbine in a steam thermodynamic cycle, and sends the steam to a feedwater heater for heating boiler feedwater, so that the average temperature of a working medium in a heat absorption process of the boiler is improved, and the heat economy of a unit is improved. The water supply regenerative heating system is the most basic component of the principle thermodynamic system, and aims to reduce cold source loss by adopting steam to heat water supplied by a boiler, a certain amount of steam does not release heat to the environment after doing partial work, namely, the heat of the steam is prevented from being taken away by the environment, so that the heat of the steam is fully utilized, the heat consumption rate is reduced, meanwhile, the water supply temperature is improved by utilizing the steam which does partial work on a steam turbine to heat the water supplied, the heat transfer temperature difference of a heating surface of the boiler is reduced, thus the irreversible loss in the water supply heating process is reduced, and the heat absorption capacity in the boiler is correspondingly reduced. By combining the reasons, the water supply regenerative heating system improves the circulation heat efficiency of the unit, so that the steam turbine has a decisive effect on improving the running economy of the unit by adopting the regenerative heating system, and the running reliability and the economy of the regenerative heating system can directly influence the running economy of the whole unit.
In the actual production process of the thermal power plant, the liquid level of the heater under the fixed load is determined through a performance test, and the enthusiasm of the adjustment parameters of operators is improved by assisting in index competition, so that the operation efficiency of the water heating and heat returning system is improved, but the problems of adjustment lag, low accuracy and poor economy still exist, and the problem of how to quickly respond to the change of the load working condition to adjust the liquid level of the heater, so that the optimal real-time operation economy of the water heating and heat returning system is still needed to be solved.
Disclosure of Invention
The invention provides a method for controlling the liquid level of a heater of a water supply and heat recovery system of a thermal power plant, which can realize the automatic control of the liquid level of the heater of the water supply and heat recovery system of the thermal power plant along with the load change based on a DCS system, so that the running economy of the heat recovery system is optimal.
The method comprises the following steps: s1, parameter data of a steam turbine generator unit stored in a database are called;
the parameter data includes: the load of the turbo generator set, the pressure and temperature of each extraction steam, the water supply flow, the condensate flow, the pressure, the temperature and flow of main steam, the temperature and pressure of exhaust steam, the liquid level of each heater, the inlet pressure of the water side, the temperature and outlet pressure temperature and the drain temperature of each heater;
s2, classifying the electric power of the steam turbine generator unit, and calculating the extraction coefficients of all levels and the heat consumption rate of the unit by using parameter data and combining a substance balance principle and a heat balance principle;
s3, comparing the thermal economy of the liquid levels of different heaters under the same electric power of the steam turbine generator unit, and carrying out accumulated iterative calculation to obtain the optimal working condition points of the liquid levels of the heaters under different loads;
s4, taking the unit load as an abscissa, the liquid level of the heater as an ordinate, and configuring a working condition curve;
s5, recording a working condition curve into a DCS control system, and collecting the electric power of the steam turbine generator unit in real time to obtain the preset target liquid level of each heater;
s6, comparing the actual liquid level with the target liquid level difference value, and adjusting the target value to the preset target liquid level at a constant rate.
In the step S2, the extraction coefficients of each stage are equivalently calculated by using the principles of material balance and heat balance;
and then, calculating the heat rate corresponding to the historical working condition by utilizing the extraction coefficients of each stage, and iteratively calculating the lowest historical heat rate working condition under the electric load working condition, namely the optimal liquid level of each heater.
In step S2, abnormal operation conditions are screened out by analyzing historical system conditions, the electric load of the turbo generator set is classified, the rated electric load is taken as an example, and when the rated electric load is used, iterative calculation is performed on all the conditions under the load, so as to calculate the corresponding heat consumption rate when different heater liquid levels are obtained.
In step S3, two different operation modes of the same outlet temperature of the condensate pump under the same unit load are selected, when the historical operation mode point of the outlet temperature of the condensate pump is insufficient, the influence of the exhaust steam temperature deviation on the heat consumption of the steam turbine is corrected, the back pressure heat consumption correction curve is used for calculating the micro-increment power of the generator,
wherein the heat consumption can be expressed as a percentage of the effect obtained in the performance test, such as: water supply temperature of circulating waterAffecting 1% heat consumption, the calculation method is delta N= (1% -1) P 0 ；
Preliminary treatment of data of each step-by-step hydrophobic heater:
τ j the specific enthalpy of Zhu Ningjie water per unit mass rises through the heater;
q j heat released by cooling steam per unit mass through a heater;
γ j heat released by cooling the hydrophobic water passing through the heater in unit mass;
coefficient of extraction alpha j Is of the general formula:
for the (j-1) th level hydrophobic fraction, if the j-1 th level is hydrophobic, it is removed as described above, if it is not hydrophobic. Actual specific internal work omega of steam turbine it The method comprises the following steps:
α rh is the backheating steam extraction coefficient;
q rh absorbing heat for reheat steam;
α sgj is the shaft seal steam quantity;
cycle internal work omega of new steam of unit mass i
ω i ＝ω it -τ p
τ p The enthalpy rise for the feed pump;
the cyclic heat absorption quantity q of new steam of unit mass;
q＝h 0 +α rh q rh -h fw
actual cycle efficiency η;
the heat rate q of the steam turbine is
D 0 The steam consumption of the turbo generator set;
p is the power of the steam turbine;
η m is mechanical efficiency;
η g is generator efficiency;
and repeating the steps to obtain economic comparison of different heater liquid levels under different unit loads, and comparing to obtain the working condition with the lowest heat consumption rate, namely the optimal liquid level working condition point of each heater liquid level combination under the electric load.
The DCS control system is further used for releasing automation and alarming when the state of the DCS control system is abnormal;
at the same time, manual intervention adjustment is started.
In the step S5, electric load data of the turbo generator set is recorded in real time into the DCS control system to obtain an operation condition curve, and the liquid level target values of the heaters are output according to the landing points of the coordinates.
It should be further noted that in step S6, the difference between the optimal liquid level and the target liquid level is compared, and the actual liquid level is adjusted to the preset target liquid level at a constant rate.
And when the heat consumption rate is calculated, a calculation model is established, and the lowest heat consumption working condition is iterated according to a calculation result.
It should be further noted that, the classification method for the electric power of the turbo generator set includes:
the classification is performed by 50%, 60%, 70%, 80%, 90% and 100% of electric loads of the turbo generator set.
The invention also provides a terminal machine for realizing the liquid level control method of the heater of the water supply and heat recovery system of the thermal power plant, which comprises the following steps:
the memory is used for storing a computer program and a liquid level control method of a heater of a water supply and heat recovery system of the thermal power plant;
and the processor is used for executing the computer program and the liquid level control method of the heater of the water heating and regenerating system of the thermal power plant so as to realize the steps of the liquid level control method of the heater of the water heating and regenerating system of the thermal power plant.
From the above technical scheme, the invention has the following advantages:
the method for controlling the liquid level of the heater of the water supply and heat recovery system of the thermal power plant can collect the electric load of the real-time turbo generator set, and the optimal target liquid level of each heater can be obtained by utilizing the working condition curve; and comparing the actual liquid level with the target liquid level difference, and slowly adjusting the set value to the optimal target liquid level at a constant rate. The invention can realize the automatic control method of the water supply heat recovery system heater liquid level of the heat engine plant based on the DCS system along with the load change, so that the heat recovery system has the best running economy.
In the actual production process of the thermal power plant, the invention determines the liquid level of the heater under fixed load through a performance test, and assists in index competition to improve the enthusiasm of operators for adjusting parameters so as to improve the operation efficiency of the water supply heat recovery system. The invention aims at the steam turbine water supply heat recovery system, realizes real-time automatic control of the liquid level of the heater based on the DCS control system through historical data analysis and processing, and achieves the aim of continuous and optimal operation economy of the steam turbine heat recovery system.
Drawings
In order to more clearly illustrate the technical solutions of the present invention, the drawings that are needed in the description will be briefly introduced below, it being obvious that the drawings in the following description are only some embodiments of the present invention, and that other drawings can be obtained according to these drawings without inventive effort for a person skilled in the art.
FIG. 1 is a flow chart of a method for controlling the liquid level of a heater of a feedwater regenerative system of a thermal power plant;
FIG. 2 is a graph of the optimal level operation of a heater according to one embodiment of the present invention;
fig. 3 is a logic diagram of a method for automatically controlling the heater liquid level of a feedwater regenerative system of a thermal power plant.
Detailed Description
The following description of the embodiments of the present invention will be made clearly and completely with reference to the accompanying drawings, in which it is apparent that the embodiments described are only some embodiments of the present invention, but not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
The units and algorithm steps of each example described in the embodiments disclosed in the method for controlling the liquid level of the heater of the water heating and regenerating system of the thermal power plant can be implemented in electronic hardware, computer software or a combination of the two, and in order to clearly illustrate the interchangeability of hardware and software, the components and steps of each example have been generally described according to functions in the above description. Whether such functionality is implemented as hardware or software depends upon the particular application and design constraints imposed on the solution. Skilled artisans may implement the described functionality in varying ways for each particular application, but such implementation decisions should not be interpreted as causing a departure from the scope of the present invention.
The block diagram shown in the attached drawings of the liquid level control method of the water heating and regenerating system heater of the thermal power plant is only a functional entity and does not necessarily correspond to a physically independent entity. That is, the functional entities may be implemented in software, or in one or more hardware modules or integrated circuits, or in different networks and/or processor devices and/or microcontroller devices.
As shown in fig. 1, the method for controlling the liquid level of the heater of the water supply and heat recovery system of the thermal power plant provided by the invention comprises the following steps:
s1, parameter data of a steam turbine generator unit stored in a database are called;
the parameter data includes: the load of the turbo generator set, the pressure and temperature of each extraction steam, the water supply flow, the condensate flow, the pressure, the temperature and flow of main steam, the temperature and pressure of exhaust steam, the liquid level of each heater, the inlet pressure of the water side, the temperature and outlet pressure temperature and the drain temperature of each heater;
the historical working condition set is established based on the parameter data, and the historical data is processed by referring to the enthalpy-entropy diagram and referring to the design data.
S2, classifying the electric power of the steam turbine generator unit, and calculating the extraction coefficients of all levels and the heat consumption rate of the unit by using parameter data and combining a substance balance principle and a heat balance principle;
the method for classifying the electric power of the steam turbine generator unit comprises the following steps: the classification is performed by 50%, 60%, 70%, 80%, 90% and 100% of electric loads of the turbo generator set.
Further, the extraction coefficients of all levels are equivalently calculated by utilizing the principle of material balance and heat balance;
and then, calculating the heat rate corresponding to the historical working condition by utilizing the extraction coefficients of each stage, and iteratively calculating the lowest historical heat rate working condition under the electric load working condition, namely the optimal liquid level of each heater.
In step S2, abnormal operation conditions are screened out by analyzing historical system conditions, the electrical load of the turbo generator set is classified, and when the rated electrical load is taken as an example, iterative calculation is performed on all conditions under the rated electrical load, so as to calculate the corresponding heat consumption rate when different heater liquid levels are obtained.
That is, the invention processes the history data stored in the database, uses the history database as basic data, uses the vapor enthalpy-entropy diagram and the thermal performance test data of the unit as support, and obtains the basic data processing basis. Extracting unit load, each extraction pressure and temperature, water supply flow, condensate flow, main steam pressure, temperature and flow, exhaust steam temperature and pressure, each heater liquid level, water side inlet pressure, temperature and outlet pressure temperature in a historical database, taking the drainage temperature of each heater as historical working condition data, and counting the historical working conditions of 6 nodes by using electric load classification;
the historical data extraction is carried out by screening the switching conditions of the high-low voltage heater so as to eliminate the influence of uncontrollable factors caused by the withdrawal of the heater or the abnormality of certain measuring points;
s3, comparing the thermal economy of the liquid levels of different heaters under the same electric power of the steam turbine generator unit, and carrying out accumulated iterative calculation to obtain the optimal working condition points of the liquid levels of the heaters under different loads;
selecting two different operation modes of the same condensate pump outlet temperature under the same unit load, correcting the influence of the exhaust steam temperature deviation on the heat consumption of the steam turbine when the historical operation point of the condensate pump outlet temperature is insufficient, calculating the micro-increment power of the generator by using a back pressure heat consumption correction curve,
wherein the heat consumption can be expressed as a percentage of the effect obtained in the performance test, such as: the water supply temperature of the circulating water affects 1% of heat consumption, and the calculation method is delta N= (1% -1) P 0 ；
Preliminary treatment of data of each step-by-step hydrophobic heater:
τ j the specific enthalpy of Zhu Ningjie water per unit mass rises through the heater;
q j heat released by cooling steam per unit mass through a heater;
γ j heat released by cooling the hydrophobic water passing through the heater in unit mass;
coefficient of extraction alpha j Is of the general formula:
for the (j-1) th level hydrophobic fraction, if the j-1 th level is hydrophobic, it is removed as described above, if it is not hydrophobic. Actual specific internal work omega of steam turbine it The method comprises the following steps:
α rh is the backheating steam extraction coefficient;
q rh absorbing heat for reheat steam;
α sgj is the shaft seal steam quantity;
cycle internal work omega of new steam of unit mass i
ω i ＝ω it -τ p
τ p The enthalpy rise for the feed pump;
the cyclic heat absorption quantity q of new steam of unit mass;
q＝h 0 +α rh q rh -h fw
actual cycle efficiency η;
the heat rate q of the steam turbine is
D 0 The steam consumption of the turbo generator set;
p is the power of the steam turbine;
η m is mechanical efficiency;
η g is generator efficiency;
and repeating the steps to obtain economic comparison of different heater liquid levels under different unit loads, and comparing to obtain the working condition with the lowest heat consumption rate, namely the optimal liquid level working condition point of each heater liquid level combination under the electric load.
S4, taking the unit load as an abscissa, the liquid level of the heater as an ordinate, and configuring a working condition curve;
and (3) carrying out linear collection on the working condition points, taking an electric load (x) as an abscissa, taking a heater liquid level (y) as an ordinate, and running the optimal curves of the liquid levels of the heaters under different loads. I.e. the optimal level operating mode curve of the heater in the embodiment of fig. 2.
S5, recording a working condition curve into a DCS control system, and collecting the electric power of the steam turbine generator unit in real time to obtain the preset target liquid level of each heater;
in the method, electric load data of the steam turbine generator unit are recorded into a DCS control system in real time, an operation condition curve is obtained, and liquid level target values of the heaters are output according to points where coordinates fall.
When the DCS control system is abnormal, the system is released automatically and alarms; at the same time, manual intervention adjustment is started.
Writing the fitting curve into a DCS control system, taking the fitting curve as a core calculation method, updating and iterating relevant parameters of the fitting curve after the later performance of relevant system equipment is changed, and realizing the matching with actual field equipment, wherein a logic diagram is shown in figure 3; y1max, y2max, y3max are 138 millimeters, y5max, y6max, y7max, y8max are 38 millimeters, y1min, y2min, y3min, y5min, y6min, y7min, y8min are 0 millimeters.
S6, comparing the actual liquid level with the target liquid level difference value, and adjusting the target value to the preset target liquid level at a constant rate.
And comparing the optimal liquid level with the target liquid level difference, and adjusting the actual liquid level to a preset target liquid level at a constant rate.
And when the heat consumption rate is calculated, a calculation model is established, and the lowest heat consumption working condition is iterated according to a calculation result.
In the method provided by the invention, key parameters such as the heat consumption rate and the like are acquired by the historical data processing method, and besides the method, the key parameters can be acquired in other modes and expressed in a function mode. In the running process of the automatic program, the optimal running mode curve of the control system is only required to be written once, automatic control can be realized without subsequent operator operation, when the field actual equipment has larger running condition change, iteration can be performed through the steps, related parameters in the program are changed, and the automatic control system is matched with the field in real time.
The invention further describes an embodiment in which a 350MW unit is provided with three high-pressure heaters, wherein the #3 high-pressure heater is provided with an external steam cooler which is arranged in front of the #1 high-pressure heater to heat water supply, and also a 5, 6, 7 and 8 low-pressure heater to heat condensed water, wherein a 4-pump corresponding heater is a deaerator (hybrid heater), and in normal history working condition optimization, the deaerator relates to safe operation of a water supply pump, and is not in an optimization column, so that the optimized liquid levels of the #1, #2, #3, #5, #6, #7 and #8 heaters are obtained in each working condition. The curve of figure 2 can be obtained through the data processing, and the figure 2 is written into a DCS control system to serve as a core calculation flow to automatically control the liquid level of each heater.
Based on the method for realizing the liquid level control of the heater of the water supply and heat recovery system of the thermal power plant, the invention also provides a terminal, which comprises the following steps:
the memory is used for storing a computer program and a liquid level control method of a heater of a water supply and heat recovery system of the thermal power plant;
and the processor is used for executing the computer program and the liquid level control method of the heater of the water heating and regenerating system of the thermal power plant so as to realize the steps of the liquid level control method of the heater of the water heating and regenerating system of the thermal power plant.
The terminal for implementing the thermal power plant feedwater regenerative system heater level control method is the unit and algorithm steps of the examples described in connection with the embodiments disclosed herein, and can be implemented in electronic hardware, computer software, or a combination of both, and to clearly illustrate the interchangeability of hardware and software, the components and steps of the examples have been generally described in terms of functionality in the foregoing description. Whether such functionality is implemented as hardware or software depends upon the particular application and design constraints imposed on the solution. Skilled artisans may implement the described functionality in varying ways for each particular application, but such implementation decisions should not be interpreted as causing a departure from the scope of the present invention.
The terminal implementing the thermal power plant feedwater regenerative system heater level control method may write program code for performing the operations of the present disclosure in any combination of one or more programming languages, including an object oriented programming language such as Java, C++, and the like, as well as conventional procedural programming languages such as the "C" language or similar programming languages. The program code may execute entirely on the user's computing device, partly on the user's device, as a stand-alone software package, partly on the user's computing device, partly on a remote computing device, or entirely on the remote computing device or server. In the case of remote computing devices, the remote computing device may be connected to the user computing device through any kind of network, including a Local Area Network (LAN) or a Wide Area Network (WAN), or may be connected to an external computing device (e.g., connected via the Internet using an Internet service provider).
In the actual production process of the thermal power plant, the invention determines the liquid level of the heater under fixed load through a performance test, and assists in index competition to improve the enthusiasm of operators for adjusting parameters so as to improve the operation efficiency of the water supply heat recovery system. The invention aims at the steam turbine water supply heat recovery system, realizes real-time automatic control of the liquid level of the heater based on the DCS control system through historical data analysis and processing, and achieves the aim of continuous and optimal operation economy of the steam turbine heat recovery system.
The previous description of the disclosed embodiments is provided to enable any person skilled in the art to make or use the present invention. Various modifications to these embodiments will be readily apparent to those skilled in the art, and the generic principles defined herein may be applied to other embodiments without departing from the spirit or scope of the invention. Thus, the present invention is not intended to be limited to the embodiments shown herein but is to be accorded the widest scope consistent with the principles and novel features disclosed herein.
Claims (9)
1. A liquid level control method for a heater of a feedwater regenerative system of a thermal power plant is characterized by comprising the following steps:
s1, parameter data of a steam turbine generator unit stored in a database are called;
the parameter data includes: the load of the turbo generator set, the pressure and temperature of each extraction steam, the water supply flow, the condensate flow, the pressure, the temperature and flow of main steam, the temperature and pressure of exhaust steam, the liquid level of each heater, the inlet pressure of the water side, the temperature and outlet pressure temperature and the drain temperature of each heater;
s2, classifying the electric power of the steam turbine generator unit, and calculating the extraction coefficients of all levels and the heat consumption rate of the unit by using parameter data and combining a substance balance principle and a heat balance principle;
s3, comparing the thermal economy of the liquid levels of different heaters under the same electric power of the steam turbine generator unit, and carrying out accumulated iterative calculation to obtain the optimal working condition points of the liquid levels of the heaters under different loads;
in the step S3 of the process,
selecting two different operation modes of the same condensate pump outlet temperature under the same unit load, correcting the influence of the exhaust steam temperature deviation on the heat consumption of the steam turbine when the historical operation point of the condensate pump outlet temperature is insufficient, calculating the micro-increment power of the generator by using a back pressure heat consumption correction curve,
wherein the heat consumption can be expressed as a percentage of the effect obtained in the performance test, such as: the water supply temperature of the circulating water affects 1% of heat consumption, and the calculation method is delta N= (1% -1) P 0 ；
Preliminary treatment of data of each step-by-step hydrophobic heater:
the specific enthalpy of the main condensate water which is the unit mass passing through the heater rises;
heat released by cooling steam per unit mass through a heater;
heat released by cooling the hydrophobic water passing through the heater in unit mass;
coefficient of steam extractionIs of the general formula:
for the j-1 level hydrophobic portion, if the j-1 level has hydrophobicity, as described above, if not, then the portion is removed;
actual specific internal work of steam turbineThe method comprises the following steps:
is the backheating steam extraction coefficient;
absorbing heat for reheat steam;
is the shaft seal steam quantity;
cycle internal work of new steam of unit mass
；
The cyclic heat absorption quantity q of new steam of unit mass;
actual circulation efficiency；
Steam turbine heat rateIs that
Is the steam consumption of the turbo generator set；
Is the power of the steam turbine;
is mechanical efficiency;
is generator efficiency;
repeating the steps to obtain economic comparison of different heater liquid levels under different unit loads, and comparing to obtain the working condition with the lowest heat consumption rate, namely, the optimal liquid level working condition point of each heater liquid level combination under the electric load with the lowest heat consumption rate;
s4, taking the unit load as an abscissa, the liquid level of the heater as an ordinate, and configuring a working condition curve;
s5, recording a working condition curve into a DCS control system, and collecting the electric power of the steam turbine generator unit in real time to obtain the preset target liquid level of each heater;
s6, comparing the actual liquid level with the target liquid level difference value, and adjusting the target value to the preset target liquid level at a constant rate.
2. The method for controlling the liquid level of a heater of a feedwater regenerative system of a thermal power plant according to claim 1, wherein,
in the step S2, the extraction coefficients of all levels are equivalently calculated by utilizing the principle of material balance and heat balance;
and then, calculating the heat rate corresponding to the historical working condition by utilizing the extraction coefficients of each stage, and iteratively calculating the lowest historical heat rate working condition under the electric load working condition, namely the optimal liquid level of each heater.
3. The method for controlling the liquid level of a heater of a feedwater regenerative system of a thermal power plant according to claim 1, wherein,
in step S2, abnormal operation conditions are screened out by analyzing historical system conditions, the electrical load of the turbo generator set is classified, and when the rated electrical load is taken as an example, iterative calculation is performed on all conditions under the rated electrical load, so as to calculate the corresponding heat consumption rate when different heater liquid levels are obtained.
4. The method for controlling the liquid level of a heater of a feedwater regenerative system of a thermal power plant according to claim 1, wherein,
when the DCS control system is abnormal, the system is released automatically and alarms;
at the same time, manual intervention adjustment is started.
5. The method for controlling the liquid level of a heater of a feedwater regenerative system of a thermal power plant according to claim 1, wherein,
in step S5, electric power data of the steam turbine generator unit are recorded into the DCS control system in real time, an operation condition curve is obtained, and liquid level target values of the heaters are output according to the falling points of the coordinates.
6. The method for controlling the liquid level of a heater of a feedwater regenerative system of a thermal power plant according to claim 1, wherein,
in step S6, the difference between the optimal liquid level and the target liquid level is compared, and the actual liquid level is adjusted to the preset target liquid level at a constant rate.
7. The method for controlling the liquid level of a heater of a feedwater regenerative system of a thermal power plant according to claim 1, wherein,
and when the heat consumption rate is calculated, a calculation model is established, and the lowest heat consumption working condition is iterated according to a calculation result.
8. The method for controlling the liquid level of a heater of a feedwater regenerative system of a thermal power plant according to claim 4, wherein,
the method for classifying the electric power of the steam turbine generator unit comprises the following steps:
the classification is performed by 50%, 60%, 70%, 80%, 90% and 100% of electric loads of the turbo generator set.
9. A terminal machine for realizing a liquid level control method of a heater of a water supply and heat recovery system of a thermal power plant is characterized by comprising:
the memory is used for storing a computer program and a liquid level control method of a heater of a water supply and heat recovery system of the thermal power plant;
a processor for executing the computer program and the method for controlling the liquid level of the heater of the feedwater heat recovery system of the thermal power plant, so as to realize the steps of the method for controlling the liquid level of the heater of the feedwater heat recovery system of the thermal power plant according to any one of claims 1 to 8.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202111278512 | 2021-10-30 | ||
| CN2021112785120 | 2021-10-30 |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN114034033A CN114034033A (en) | 2022-02-11 |
| CN114034033B true CN114034033B (en) | 2023-10-20 |
Family
ID=80145106
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202111387851.2A Active CN114034033B (en) | 2021-10-30 | 2021-11-22 | Liquid level control method and terminal for heater of water supply and heat recovery system of thermal power plant |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN114034033B (en) |
Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN2054234U (en) * | 1989-07-29 | 1990-03-07 | 徐尔骏 | Mixed-flow type computer controlled hydroelectric generator |
| JP2009127952A (en) * | 2007-11-26 | 2009-06-11 | Toshiba Corp | Drain control device of low pressure water supply heater and steam turbine plant |
| CN206145660U (en) * | 2016-10-27 | 2017-05-03 | 北京创时能源有限公司 | Hydrophobic water level regulating system of heating network heater |
| CN106765047A (en) * | 2017-01-11 | 2017-05-31 | 中国神华能源股份有限公司 | Water level regulation method and apparatus |
| CN110056858A (en) * | 2019-05-15 | 2019-07-26 | 贵州电网有限责任公司 | A kind of fired power generating unit Heater Terminal Temperature Difference adaptive regulation method and device |
| CN111911908A (en) * | 2020-06-17 | 2020-11-10 | 东南大学 | High-pressure heater water level fuzzy control mechanism and method for unit flexible peak regulation |
| CN112096602A (en) * | 2020-09-29 | 2020-12-18 | 国电华北电力有限公司廊坊热电厂 | Method for automatically controlling frequency conversion circulating water pump set of wet cooling steam turbine power generation set |
-
2021
- 2021-11-22 CN CN202111387851.2A patent/CN114034033B/en active Active
Patent Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN2054234U (en) * | 1989-07-29 | 1990-03-07 | 徐尔骏 | Mixed-flow type computer controlled hydroelectric generator |
| JP2009127952A (en) * | 2007-11-26 | 2009-06-11 | Toshiba Corp | Drain control device of low pressure water supply heater and steam turbine plant |
| CN206145660U (en) * | 2016-10-27 | 2017-05-03 | 北京创时能源有限公司 | Hydrophobic water level regulating system of heating network heater |
| CN106765047A (en) * | 2017-01-11 | 2017-05-31 | 中国神华能源股份有限公司 | Water level regulation method and apparatus |
| CN110056858A (en) * | 2019-05-15 | 2019-07-26 | 贵州电网有限责任公司 | A kind of fired power generating unit Heater Terminal Temperature Difference adaptive regulation method and device |
| CN111911908A (en) * | 2020-06-17 | 2020-11-10 | 东南大学 | High-pressure heater water level fuzzy control mechanism and method for unit flexible peak regulation |
| CN112096602A (en) * | 2020-09-29 | 2020-12-18 | 国电华北电力有限公司廊坊热电厂 | Method for automatically controlling frequency conversion circulating water pump set of wet cooling steam turbine power generation set |
Also Published As
| Publication number | Publication date |
|---|---|
| CN114034033A (en) | 2022-02-11 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN109325255B (en) | Optimal vacuum on-line guiding system of wet cooling steam turbine based on fixed power | |
| WO2013006302A2 (en) | Automatic identification of operating parameters for power plants | |
| CN111664504B (en) | Method for predicting influence of turbine thermodynamic system micro-increment variable on turbine heat consumption | |
| Opriş et al. | Parametric optimization of the thermodynamic cycle design for supercritical steam power plants | |
| CN107762581A (en) | A kind of screw expansion generating set full-automatic control system and method | |
| CN114034033B (en) | Liquid level control method and terminal for heater of water supply and heat recovery system of thermal power plant | |
| CN111142381A (en) | Control-oriented NCB type steam turbine heating system composite dynamic modeling method | |
| KR102126427B1 (en) | high pressure pump failure prediction Method And System | |
| CN112131780B (en) | Thermal power plant circulating water system control method based on data mining | |
| JP4108097B2 (en) | Nuclear power plant thermal efficiency diagnostic system, nuclear power plant thermal efficiency diagnostic program, and nuclear power plant thermal efficiency diagnostic method | |
| CN111027186B (en) | Performance diagnosis method and system for steam-water separation reheater in running state | |
| CN105781639B (en) | System and method for adjusting floor pressure levels to improve combined cycle plant startup | |
| CN113868836B (en) | Intelligent thermodynamic system on-line expert analysis platform based on big data | |
| CN113359450B (en) | Valve flow characteristic curve fitting method and system | |
| KR100752765B1 (en) | A real-time calculation system and method on performance impact of controllable operation parameters for combined-cycle power plant | |
| CN112100751B (en) | Method and system for calculating influence of back pressure change of extraction condensing unit on unit power | |
| CN105804819A (en) | Regulation and control method for improving recovery amount of sintering waste heat and operational stability of power generation system | |
| CN113111600A (en) | On-line analysis method for cleanliness of condenser cooling pipe of saturated steam generator set | |
| CN109492855B (en) | Condenser type steam turbine exhaust temperature prediction method based on data model | |
| CN112880761B (en) | Method and system for measuring circulating water flow | |
| CN117846731A (en) | Energy-saving optimization method for nuclear power unit circulating water system and circulating water system | |
| CN114357023B (en) | Data-driven direct air cooling unit operation optimization method and system | |
| KR102327828B1 (en) | Damper Opening Ratio Control System Based On Development Pattern | |
| CN114753892B (en) | Method and device for controlling main steam pressure of steam turbine and electronic equipment | |
| Kim et al. | Development of performance analysis system (NOPAS) for turbine cycle of nuclear power plant |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |