Turbine master control method, device and equipment based on unit operation

Abstract

The invention discloses a steam turbine master control method, device and equipment based on unit operation, and the method comprises the steps that actual operation information of a historical station unit is acquired, and the actual operation information comprises an actual main steam pressure value, a speed-limiting main steam pressure set value, a load change rate set value, an actual load value and a speed-limiting load set value; the unit operation states are comprehensively analyzed according to the actual operation information, state marking values are determined, and the unit operation states comprise the AGC state, the primary frequency modulation state, the sliding pressure state, the variable load state and the variable load rate state; inputting the main steam pressure ratio into a preselected correction function for correction calculation by taking the state marking value as a selection condition to obtain a correction coefficient; and the steam turbine master control output power is adjusted through a steam turbine master control loop according to the main steam pressure ratio and the correction coefficient. The technical problem that in the prior art, only the main steam pressure is corrected, the unit operation state is ignored, and consequently safe and stable operation of a power grid and a unit is difficult to guarantee through actual control can be solved.

Description

Technical Field

[0001] This application relates to the technical field of thermal power generation control, and particularly to a steam turbine main control method, device and equipment based on unit operation. Background Art

[0002] Under the mainstream coordinated mode of thermal power units, the design idea of the steam turbine main control loop is as follows: The load set value after speed limit is superimposed with the primary frequency modulation amount as the set value of the steam turbine main control regulator. The actual load of the unit is multiplied by the ratio of the main steam pressure set value to the actual value as the process value of the regulator. Then, the output of the regulator is superimposed with the feedforward signal to adjust the output of the steam turbine main control under the coordinated mode.

[0003] Due to the transformation of the energy structure, higher and higher requirements are put forward for the stability of the unit load and the safety of unit operation. However, in the steam turbine main control loop, the stability of the main steam pressure and the load stability during unit operation are relatively contradictory problems. Most of the existing design methods can only unilaterally correct the main steam pressure. For example, when the main steam pressure is low, it is difficult for the unit to reach the load change rate required for AGC input; in this case, it is very difficult to ensure the safe and stable operation of the power grid and the unit itself. Summary of the Invention

[0004] This application provides a steam turbine main control method, device and equipment based on unit operation, which is used to solve the technical problem that the existing technology only corrects the main steam pressure, ignores the unit operation state problem, and makes it difficult for the actual control strategy to ensure the safe and stable operation of the power grid and the unit.

[0005] In view of this, the first aspect of this application provides a steam turbine main control method based on unit operation, including:

[0006] Obtain the actual operation information of the historical station unit, where the actual operation information includes the actual main steam pressure value, the speed-limited main steam pressure set value, the load change rate set value, the actual load value and the speed-limited load set value;

[0007] Comprehensively analyze the unit operation state based on the actual operation information and determine the state indication value. The unit operation state includes AGC state, primary frequency modulation state, sliding pressure state, load change state, and load change rate state;

[0008] Taking the state indication value as the selection condition, input the main steam pressure ratio into the preselected correction function for correction calculation to obtain the correction coefficient;

[0009] Adjust the output power of the steam turbine main control through the steam turbine main control loop according to the main steam pressure ratio and the correction coefficient.

[0010] Preferably, the comprehensively analyzing the unit operation state based on the actual operation information and determining the state indication value includes:

[0011] If the ratio of the difference between the speed limit load setting value at the current moment and that at the previous moment to the operation period is calculated, and the obtained ratio is the load change rate setting value, it is determined that the unit is in a load change state;

[0012] If the unit is in a load change state and the current load change rate setting value of the unit exceeds the deviation threshold, it is determined that the load setting value of the unit is abnormal, and the load change rate state of the unit is determined;

[0013] Combined with the AGC state, primary frequency modulation state, sliding pressure state, the load change state and the load change rate state for comprehensive state analysis, and configure a state identification value.

[0014] Preferably, taking the state identification value as a selection condition, inputting the main steam pressure ratio into a preselected correction function for correction calculation to obtain a correction coefficient, including:

[0015] Performing a ratio calculation based on the actual main steam pressure value and the speed limit main steam pressure setting value to obtain the main steam pressure ratio;

[0016] Selecting a target correction function from candidate correction functions according to the state identification value to obtain a preselected correction function;

[0017] Inputting the main steam pressure ratio into the preselected correction function for correction calculation to obtain a correction coefficient.

[0018] Preferably, adjusting the output power of the turbine main control by the turbine main control loop according to the main steam pressure ratio and the correction coefficient, including:

[0019] Performing speed limit processing after multiplying the main steam pressure ratio by the correction coefficient to obtain a speed limit parameter;

[0020] Multiplying the speed limit parameter by the actual load value to obtain a speed limit instruction;

[0021] Taking the speed limit instruction as the process value of the regulator through the turbine main control loop to realize the adjustment of the output power of the turbine main control.

[0022] Preferably, before adjusting the output power of the turbine main control by the turbine main control loop according to the main steam pressure ratio and the correction coefficient, it further includes:

[0023] Constructing a turbine main control loop under a coordinated mode according to the standards of the thermal power unit operation system to obtain a turbine main control loop.

[0024] The second aspect of the present application provides a turbine main control device based on unit operation, including:

[0025] An information acquisition unit, configured to acquire the actual operation information of a historical unit set, where the actual operation information includes an actual main steam pressure value, a speed-limiting main steam pressure set value, a load change rate set value, an actual load value, and a speed-limiting load set value;

[0026] A state analysis unit, configured to comprehensively analyze the unit operation state according to the actual operation information and determine a state identification value, where the unit operation state includes an AGC state, a primary frequency modulation state, a sliding pressure state, a load change state, and a load change rate state;

[0027] A correction calculation unit, configured to use the state identification value as a selection condition, input a main steam pressure ratio into a preselected correction function for correction calculation, and obtain a correction coefficient;

[0028] A main control regulation unit, configured to adjust the output power of the turbine main control according to the main steam pressure ratio and the correction coefficient through a turbine main control loop.

[0029] Preferably, the state analysis unit is specifically configured to:

[0030] If the ratio of the difference between the speed-limiting load set value at the current moment and the previous moment to the operation period is calculated and the obtained ratio is the load change rate set value, it is determined that the unit is in a load change state;

[0031] If the unit is in a load change state and the current load change rate set value of the unit exceeds a deviation threshold, it is determined that the load set value of the unit is abnormal, and the load change rate state of the unit is determined;

[0032] Perform a comprehensive state analysis in combination with the AGC state, the primary frequency modulation state, the sliding pressure state, the load change state, and the load change rate state, and configure a state identification value.

[0033] Preferably, the correction calculation unit is specifically configured to:

[0034] Perform a ratio calculation according to the actual main steam pressure value and the speed-limiting main steam pressure set value to obtain a main steam pressure ratio;

[0035] Select a target correction function from candidate correction functions according to the state identification value to obtain a preselected correction function;

[0036] Input the main steam pressure ratio into the preselected correction function for correction calculation to obtain a correction coefficient.

[0037] Preferably, the main control regulation unit is specifically configured to:

[0038] Multiply the main steam pressure ratio by the correction coefficient and then perform speed-limiting processing to obtain a speed-limiting parameter;

[0039] Multiply the speed limit parameter by the actual load value to obtain a speed limit instruction;

[0040] Use the steam turbine master control loop to take the speed limit instruction as the process value of the regulator, and realize the regulation of the output power of the steam turbine master control.

[0041] The third aspect of this application provides a steam turbine master control device based on unit operation, and the device includes a processor and a memory;

[0042] The memory is used to store program codes and transmit the program codes to the processor;

[0043] The processor is used to execute the steam turbine master control method based on unit operation described in the first aspect according to the instructions in the program code.

[0044] It can be seen from the above technical solutions that the embodiments of this application have the following advantages:

[0045] In this application, a steam turbine master control method based on unit operation is provided, including: obtaining the actual operation information of the historical station unit, where the actual operation information includes the actual main steam pressure value, the speed limit main steam pressure set value, the load change rate set value, the actual load value, and the speed limit load set value; comprehensively analyzing the unit operation state based on the actual operation information and determining the state indication value, where the unit operation state includes the AGC state, the primary frequency modulation state, the sliding pressure state, the load change state, and the load change rate state; using the state indication value as the selection condition, inputting the main steam pressure ratio into the preselected correction function for correction calculation to obtain a correction coefficient; adjusting the output power of the steam turbine master control according to the main steam pressure ratio and the correction coefficient through the steam turbine master control loop.

[0046] The steam turbine master control method based on unit operation provided by this application takes into account the influence of the actual operation information during the unit operation, comprehensively analyzes the unit operation state based on the actual operation information, and selects a suitable preselected correction function based on this to calculate the correction coefficient; then adjusts the output power of the steam turbine master control according to the dynamic correction coefficient. This process fully considers the influence of the unit operation state on the steam turbine master control, and using the dynamic correction coefficient to adjust the output of the steam turbine master control also more conforms to the actual operation characteristics of the thermal power generation system. Therefore, the safety and stability of the operation process of the thermal power unit can be ensured. Therefore, this application can solve the technical problem that the existing technology only corrects the main steam pressure, ignores the unit operation state problem, and makes it difficult to ensure the safe and stable operation of the power grid and the unit. Description of the Drawings

[0047] Figure 1 It is a schematic flow chart of the steam turbine master control method based on unit operation provided by the embodiment of this application;

[0048] Figure 2 Structural schematic diagram of the steam turbine main control device based on unit operation provided by the embodiment of the present application;

[0049] Figure 3 Schematic diagram of the comprehensive analysis process of the unit operation status provided by the embodiment of the present application;

[0050] Figure 4 Schematic diagram of the overall control process of the steam turbine main control provided by the embodiment of the present application. Specific embodiments

[0051] In order to enable those skilled in the art to better understand the solution of the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below in conjunction with the accompanying drawings in the embodiments of the present application. Obviously, the described embodiments are only a part of the embodiments of the present application, rather than all the embodiments. Based on the embodiments in the present application, all other embodiments obtained by those of ordinary skill in the art without making creative efforts belong to the scope of protection of the present application.

[0052] For ease of understanding, please refer to Figure 1 , the embodiments of the steam turbine main control method based on unit operation provided by the present application include:

[0053] Step 101: Obtain the actual operation information of the historical station unit, where the actual operation information includes the actual main steam pressure value, the limited-speed main steam pressure set value, the load change rate set value, the actual load value, and the limited-speed load set value.

[0054] Obtaining the actual operation information of the historical station unit is to analyze the operation status of the unit, and then adjust the output of the steam turbine main control loop based on this analysis result, so as to fully consider the influence of the unit operation status on the main steam control. It can be understood that in addition to obtaining these actual operation information including the actual main steam pressure value, the limited-speed main steam pressure set value, the load change rate set value, the actual load value, and the limited-speed load set value, other relevant information can also be obtained according to the needs of status analysis, such as the AGC input signal, the primary frequency modulation input signal, and the sliding pressure input signal, etc.; other unit operation-related data can also be obtained according to the actual situation. This is only an example here and is not limited.

[0055] Step 102: Comprehensively analyze the unit operation status based on the actual operation information and determine the status indication value. The unit operation status includes the AGC status, the primary frequency modulation status, the sliding pressure status, the load change status, and the load change rate status.

[0056] Further, step 102 includes:

[0057] If the ratio of the difference between the speed limit load set value at the current moment and the previous moment to the operation period is calculated, and the obtained ratio is the load change rate set value, it is determined that the unit is in the load change state;

[0058] If the unit is in the load change state and the current load change rate set value of the unit exceeds the deviation threshold, it is determined that the load set value of the unit is abnormal, and the load change rate state of the unit is determined;

[0059] Combined with the AGC state, primary frequency modulation state, sliding pressure state, load change state and load change rate state for comprehensive state analysis, and configure the state identification value.

[0060] It should be noted that the comprehensive state analysis is mainly to clarify the state of the unit operation, and then calculate a more targeted correction coefficient. The unit operation states to be analyzed include but are not limited to the AGC state, primary frequency modulation state, sliding pressure state, load change state, load change rate state; and all are determined according to different actual operation information.

[0061] Specifically, according to the AGC input signal, primary frequency modulation input signal and sliding pressure input signal, it can be determined whether the AGC is input, whether the primary frequency modulation is input, and whether the sliding pressure is input. The determination of the load change state and load change rate state requires certain calculations and analyses. Calculate the difference between the speed limit load set value at the current moment and the previous moment, and then divide the difference by the operation period to obtain the current load change rate value; if the current load change rate value is equal to the load change rate set value, it is determined that the unit is in the load change stage, that is, the load change state. It can be understood that the operation period is configured according to the actual situation and will not be elaborated here. In addition, in actual engineering applications, the current load change rate value being equal to the load change rate set value is not an absolute equality, but within a very small error range, for example , that is, the difference between the two does not exceed which is regarded as equal.

[0062] If the unit is in the load change state, and the load change rate set value is not 0, and the deviation from the actual load change rate Pe of the unit is too large, exceeding the deviation threshold, for example, the deviation exceeds 1.2%Pe; then it is determined that the load set value of the unit is abnormal, and the load change rate state of the unit can be determined. The deviation threshold can be designed according to the actual situation, and the 1.2%Pe here is only an example and not a limitation.

[0063] Please refer to Figure 3 , in the process of combining the AGC state, primary frequency modulation state, sliding pressure state, load change state and load change rate state for comprehensive state analysis and configuring the state identification value, this embodiment designs 8 analysis schemes to determine 8 different state identification values. Specifically as follows:

[0064] 1) AGC is put into operation, primary frequency modulation is put into operation, sliding pressure is put into operation, the unit is in the variable load state, the set value of the variable load rate is greater than 1.2%Pe, and the output status identification value is 1;

[0065] 2) AGC is put into operation, primary frequency modulation is put into operation, sliding pressure is put into operation, the set value of the variable load rate of the unit is not greater than 1.2%Pe, and the output status identification value is 2;

[0066] 3) AGC is put into operation, primary frequency modulation is put into operation, sliding pressure is not put into operation (constant pressure is put into operation), the unit is in the variable load state, the set value of the variable load rate is greater than 1.2%Pe, and the output status identification value is 3;

[0067] 4) AGC is put into operation, primary frequency modulation is put into operation, sliding pressure is not put into operation (constant pressure is put into operation), the set value of the variable load rate of the unit is not greater than 1.2%Pe, and the output status identification value is 4;

[0068] 5) AGC is put into operation, primary frequency modulation is not put into operation, the set value of the variable load rate of the unit is greater than 1.2%Pe, and the output status identification value is 5;

[0069] 6) AGC is put into operation, primary frequency modulation is not put into operation, the set value of the variable load rate of the unit is not greater than 1.2%Pe, and the output status identification value is 6;

[0070] 7) AGC is not put into operation, primary frequency modulation is put into operation, and the output status identification value is 7;

[0071] 8) AGC is not put into operation, primary frequency modulation is not put into operation, and the output status identification value is 8.

[0072] Step 103: Taking the status identification value as the selection condition, input the main steam pressure ratio into the preselected correction function for correction calculation to obtain the correction coefficient.

[0073] Further, step 103 includes:

[0074] Perform ratio calculation based on the actual main steam pressure value and the limited-speed main steam pressure set value to obtain the main steam pressure ratio;

[0075] Select the target correction function from the candidate correction functions according to the status identification value to obtain the preselected correction function;

[0076] Input the main steam pressure ratio into the preselected correction function for correction calculation to obtain the correction coefficient.

[0077] It should be noted that if the candidate correction function is expressed as , then the ratio of the limited-speed main steam pressure set value to the actual main steam pressure value can be expressed as ; where is the serial number label of the candidate correction function, or it can be the total number label. In view of the fact that 8 state indication values ​​are obtained in the above embodiment, and the pre-selected correction function is selected based on the state indication value, the , that is, 8 candidate correction functions are set; different appropriate pre-selected correction functions can be selected according to the state indication value; then the ratio By inputting the corresponding pre-selected correction function and performing calculation, the correction coefficient can be obtained.

[0078] It is understandable that different state indication values ​​will be generated when the unit is in different operating states, and then different pre-selected correction functions will be selected to calculate different correction coefficients. Therefore, this process is an adaptive dynamic selection calculation process. Compared with the prior art method of directly specifying the correction coefficient, it is more in line with the actual system operation characteristics, so the calculated correction coefficient is more accurate and reliable, and the subsequent steam turbine control based on this is also more scientific and reasonable.

[0079] In addition, in order to optimize the influence of the correction coefficient of this embodiment, the correction coefficient can also be made to achieve the purpose of dead zone limitation and amplitude limitation by reasonably designing the candidate correction function. For example, when the unit is in the stage of AGC input and the unit is in a variable load state, the dead zone can be increased and the function output value can be decreased by modifying the function to ensure the relative stability of the load. For examples of the initial value of the function, please refer to Table 1.

[0080] Table 1 Examples of candidate correction function initial values

[0081]

[0082] Step 104: adjusting the main control output power of the steam turbine according to the main steam pressure ratio and the correction coefficient through the main control loop of the steam turbine.

[0083] Furthermore, step 104 includes:

[0084] The main steam pressure ratio is multiplied by the correction coefficient and then subjected to speed limit processing to obtain the speed limit parameter;

[0085] Multiply the speed limit parameter by the actual load value to obtain the speed limit instruction;

[0086] The speed limit command is used as the process value of the regulator through the steam turbine main control loop to adjust the steam turbine main control output power.

[0087] Furthermore, step 104, before that, also includes:

[0088] According to the standard of the thermal power unit operation system, the main control circuit of the steam turbine is built in a coordinated manner to obtain the main control circuit of the steam turbine.

[0089] It should be noted that the process of building the steam turbine master control loop can be implemented with reference to the prior art, as long as it meets the operating standards and requirements of the thermal power unit operating system and can implement the steam turbine master control strategy provided in this embodiment.

[0090] After multiplying the main steam pressure ratio by the correction factor, perform a speed limit process with seamless switching through the speed limit module of the system to obtain the data recorded as the speed limit parameter; then multiply the speed limit parameter by the actual load value of the unit to obtain the output speed limit instruction; introducing the speed limit instruction into the steam turbine master control loop regulator as the process value can reflect the influence of the unit operating state on the steam turbine master control, thereby adjusting the output power of the steam turbine master control. Since the correction factor is a value dynamically calculated based on the unit operating state, the steam turbine master control process based on this value is also a dynamic regulation process, fully considering the influence of the unit operating state on the steam turbine master control, which is in line with the actual situation. For the overall steam turbine master control process of this embodiment, please refer to Figure 4 .

[0091] It can be understood that the design of the set value and the feedforward signal of the steam turbine master control regulator under the coordinated mode can be implemented according to the prior art operation. This embodiment does not focus on this, so it will not be elaborated here; as long as the control method of this embodiment can be implemented with reference to the existing design scheme.

[0092] The steam turbine master control method based on unit operation provided in the embodiment of the present application considers the influence of the actual operation information during the unit operation process, comprehensively analyzes the unit operating state based on the actual operation information, and selects a suitable preselected correction function based on this to calculate the correction factor; then adjusts the output power of the steam turbine master control according to the dynamic correction factor. This process fully considers the influence of the unit operating state on the steam turbine master control, and using the dynamic correction factor to adjust the steam turbine master control output is more in line with the actual operation characteristics of the thermal power generation system, so it can ensure the safety and stability of the thermal power unit during operation. Therefore, the embodiment of the present application can solve the technical problem that the prior art only corrects the main steam pressure, ignoring the unit operating state problem, resulting in the actual control strategy being difficult to ensure the safe and stable operation of the power grid and the unit.

[0093] For ease of understanding, please refer to Figure 2 , the embodiment of the steam turbine master control device based on unit operation provided by the present application includes:

[0094] An information acquisition unit 201, configured to acquire the actual operation information of the historical station unit, where the actual operation information includes the actual main steam pressure value, the speed limit main steam pressure set value, the load change rate set value, the actual load value, and the speed limit load set value;

[0095] The status analysis unit 202 is used to comprehensively analyze the unit operation status based on the actual operation information and determine the status indication value. The unit operation status includes AGC status, primary frequency regulation status, sliding pressure status, load change status, and load change rate status.

[0096] The correction calculation unit 203 is used to take the status indication value as the selection condition, input the main steam pressure ratio into the preselected correction function for correction calculation, and obtain the correction coefficient.

[0097] The main control regulation unit 204 is used to adjust the output power of the turbine main control through the turbine main control loop according to the main steam pressure ratio and the correction coefficient.

[0098] Furthermore, the status analysis unit 202 is specifically used for:

[0099] If the ratio of the difference between the speed limit load set value at the current moment and the previous moment to the operation period is calculated and the obtained ratio is the load change rate set value, it is determined that the unit is in the load change state.

[0100] If the unit is in the load change state and the current load change rate set value of the unit exceeds the deviation threshold, it is determined that the unit load set value is abnormal, and the load change rate state of the unit is determined.

[0101] Perform a comprehensive status analysis in combination with the AGC status, primary frequency regulation status, sliding pressure status, load change status, and load change rate status, and configure the status indication value.

[0102] Furthermore, the correction calculation unit 203 is specifically used for:

[0103] Perform a ratio calculation based on the actual main steam pressure value and the speed limit main steam pressure set value to obtain the main steam pressure ratio.

[0104] Select the target correction function from the candidate correction functions according to the status indication value to obtain the preselected correction function.

[0105] Input the main steam pressure ratio into the preselected correction function for correction calculation to obtain the correction coefficient.

[0106] Furthermore, the main control regulation unit 204 is specifically used for:

[0107] Perform speed limit processing after multiplying the main steam pressure ratio by the correction coefficient to obtain the speed limit parameter.

[0108] Multiply the speed limit parameter by the actual load value to obtain the speed limit instruction.

[0109] Use the speed limit instruction as the process value of the regulator through the turbine main control loop to realize the adjustment of the output power of the turbine main control.

[0110] The present application also provides a steam turbine main control device based on the operation of the unit. The device includes a processor and a memory;

[0111] The memory is used to store program codes and transmit the program codes to the processor;

[0112] The processor is used to execute the steam turbine main control method based on the operation of the unit in the above method embodiment according to the instructions in the program codes.

[0113] In several embodiments provided by the present application, it should be understood that the disclosed device and method can be implemented in other ways. For example, the device embodiments described above are merely illustrative. For example, the division of the units is only a logical function division. In actual implementation, there may be other division methods. For example, multiple units or components can be combined or integrated into another system, or some features can be ignored or not executed. Another point is that the displayed or discussed mutual coupling or direct coupling or communication connection can be through some interfaces. The indirect coupling or communication connection of the device or unit can be in electrical, mechanical or other forms.

[0114] The units described as separate components may or may not be physically separated. The components displayed as units may or may not be physical units, that is, they can be located in one place, or they can be distributed to multiple network units. Some or all of the units can be selected according to actual needs to achieve the purpose of the solution of this embodiment.

[0115] In addition, each functional unit in various embodiments of the present application can be integrated in a processing unit, or each unit can exist physically alone, or two or more units can be integrated in one unit. The above integrated unit can be implemented in the form of hardware or in the form of a software functional unit.

[0116] If the integrated unit is implemented in the form of a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this application, in essence, or the part that contributes to the prior art, or all or part of this technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions for a computer device (which can be a personal computer, a server, or a network device, etc.) to execute all or part of the steps of the methods described in various embodiments of this application. The aforementioned storage medium includes: various media that can store program codes, such as USB flash drives, mobile hard disks, read-only memories (English full name: Read-Only Memory, English abbreviation: ROM), random access memories (English full name: Random Access Memory, English abbreviation: RAM), magnetic disks, or optical discs.

[0117] As described above, the above embodiments are only used to illustrate the technical solution of this application, rather than to limit it; although this application has been described in detail with reference to the foregoing embodiments, those of ordinary skill in the art should understand that they can still modify the technical solutions recorded in the foregoing embodiments, or perform equivalent replacements on some of the technical features; and these modifications or replacements do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of various embodiments of this application.

Claims

1. A steam turbine master control method based on unit operation, characterized in that: include: Acquire actual operation information of the historical station unit, wherein the actual operation information includes an actual main steam pressure value, a speed-limiting main steam pressure setting value, a load change rate setting value, an actual load value, and a speed-limiting load setting value; Comprehensively analyzing the unit operation status according to the actual operation information and determining the status indication value, wherein the unit operation status includes AGC status, primary frequency regulation status, sliding pressure status, variable load status, and variable load rate status; Taking the state indication value as the selection condition, the main steam pressure ratio is input into the preselected correction function for correction calculation to obtain the correction coefficient; The main control output power of the steam turbine is adjusted according to the main steam pressure ratio and the correction coefficient through the main control loop of the steam turbine.

2. The steam turbine master control method based on unit operation according to claim 1 is characterized in that: The comprehensive analysis of the unit operation status based on the actual operation information and determination of the status indication value includes: If the difference between the speed limit load setting value at the current moment and the previous moment is calculated by ratio with the operation period, and the obtained ratio is the load change rate setting value, it is determined that the unit is in a variable load state; If the unit is in a variable load state, and the current variable load rate setting value of the unit exceeds the deviation threshold, the unit load setting value is judged to be abnormal, and the variable load rate state of the unit is determined; A comprehensive state analysis is performed in combination with the AGC state, the primary frequency modulation state, the sliding pressure state, the variable load state and the variable load rate state, and a state indication value is configured.

3. The steam turbine master control method based on unit operation according to claim 1 is characterized in that: The state indication value is used as a selection condition, and the main steam pressure ratio is input into a preselected correction function for correction calculation to obtain a correction coefficient, including: A ratio calculation is performed based on the actual main steam pressure value and the speed-limiting main steam pressure setting value to obtain a main steam pressure ratio; Selecting a target correction function from candidate correction functions according to the state indication value to obtain a pre-selected correction function; The main steam pressure ratio is input into the preselected correction function to perform correction calculation to obtain a correction coefficient.

4. The steam turbine master control method based on unit operation according to claim 1 is characterized in that: The step of adjusting the main control output power of the steam turbine according to the main steam pressure ratio and the correction coefficient through the main control loop of the steam turbine includes: The main steam pressure ratio is multiplied by the correction coefficient and then speed limiting processing is performed to obtain a speed limiting parameter; Multiplying the speed limit parameter by the actual load value to obtain a speed limit instruction; The speed limit instruction is used as the process value of the regulator through the steam turbine main control loop to achieve the regulation of the steam turbine main control output power.

5. The steam turbine master control method based on unit operation according to claim 1 is characterized in that: The main control output power of the steam turbine is adjusted according to the main steam pressure ratio and the correction coefficient by the main control loop of the steam turbine, and the method further includes: According to the standard of the thermal power unit operation system, the main control circuit of the steam turbine is built in a coordinated manner to obtain the main control circuit of the steam turbine.

6. The main control device of the steam turbine based on the operation of the unit is characterized by: include: An information acquisition unit, used to acquire actual operation information of the historical station unit, wherein the actual operation information includes an actual main steam pressure value, a speed-limiting main steam pressure setting value, a load change rate setting value, an actual load value, and a speed-limiting load setting value; A state analysis unit, used to comprehensively analyze the unit operation state according to the actual operation information and determine the state indication value, wherein the unit operation state includes AGC state, primary frequency regulation state, sliding pressure state, variable load state, and variable load rate state; A correction calculation unit, used to input the main steam pressure ratio into a preselected correction function to perform correction calculation and obtain a correction coefficient, using the state indication value as a selection condition; The main control regulating unit is used to regulate the main control output power of the steam turbine according to the main steam pressure ratio and the correction coefficient through the main control loop of the steam turbine.

7. The steam turbine master control device based on unit operation according to claim 6 is characterized in that: The state analysis unit is specifically used for: If the difference between the speed limit load setting value at the current moment and the previous moment is calculated by ratio with the operation period, and the obtained ratio is the load change rate setting value, it is determined that the unit is in a variable load state; If the unit is in a variable load state, and the current variable load rate setting value of the unit exceeds the deviation threshold, the unit load setting value is judged to be abnormal, and the variable load rate state of the unit is determined; A comprehensive state analysis is performed in combination with the AGC state, the primary frequency modulation state, the sliding pressure state, the variable load state and the variable load rate state, and a state indication value is configured.

8. The steam turbine master control device based on unit operation according to claim 6 is characterized in that: The correction calculation unit is specifically used for: A ratio calculation is performed based on the actual main steam pressure value and the speed-limiting main steam pressure setting value to obtain a main steam pressure ratio; Selecting a target correction function from candidate correction functions according to the state indication value to obtain a pre-selected correction function; The main steam pressure ratio is input into the preselected correction function to perform correction calculation to obtain a correction coefficient.

9. The steam turbine master control device based on unit operation according to claim 6, characterized in that: The main control adjustment unit is specifically used for: The main steam pressure ratio is multiplied by the correction coefficient and then speed limiting processing is performed to obtain a speed limiting parameter; Multiplying the speed limit parameter by the actual load value to obtain a speed limit instruction; The speed limit instruction is used as the process value of the regulator through the steam turbine main control loop to achieve the regulation of the steam turbine main control output power.

10. The main control device of the steam turbine based on the operation of the unit is characterized by: The device comprises a processor and a memory; The memory is used to store program code and transmit the program code to the processor; The processor is used to execute the steam turbine master control method based on unit operation as described in any one of claims 1-5 according to the instructions in the program code.

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