Power plant configuration method for primary frequency modulation disturbance test and evaluation

Abstract

The present application relates to power system network source coordination control technical field, it is a kind of power station configuration method of primary frequency modulation disturbance test and evaluation, it builds the configuration logic of triggering test disturbance in power station control system;According to the fitting generation of primary frequency modulation test parameter set of grid condition;Build theoretical and actual frequency modulation calculation basis configuration logic;Build primary frequency modulation response lag time result evaluation configuration logic;Build primary frequency modulation output response ratio result evaluation configuration logic;Build primary frequency modulation electric quantity contribution ratio result evaluation configuration logic;Build primary frequency modulation performance risk alarm configuration logic;Power station side triggers or grid side utilizes remote interface and triggers primary frequency modulation disturbance.The present application greatly reduces system cost input, can trigger the disturbance signal of different grid frequency event simulation, selects the different working conditions of power supply to carry out different parameter set simulation grid disturbance primary frequency modulation test, and verifies the primary frequency modulation performance of power station comprehensively.

Description

Technical Field

[0001] This invention relates to the field of power system grid-source coordination control technology, and is a test method for primary frequency regulation of power plants based on deviation signals during grid frequency faults, to verify the primary frequency regulation performance of power plants under actual grid disturbances. Background Technology

[0002] With the regional power system being interconnected via UHV AC and DC lines under the operation of large power grids, the grid frequency may affect the surrounding power grids in the event of accidents such as DC commutation failure or large-scale disconnection of new energy sources, resulting in a frequency deviation of 50Hz from the nominal value. In such cases, the primary frequency regulation control of power plants in the accident area becomes an important means of maintaining grid frequency stability within one minute of the accident.

[0003] To strengthen the management of primary frequency regulation performance in power plants, the state has issued a series of technical standards, such as GB / T 40594-2021 "Technical Guidelines for Power System Grid-Source Coordination" and GB / T 40595-2022 "Technical Regulations and Test Guidelines for Primary Frequency Regulation of Grid-Connected Power Sources," requiring power plants to conduct a comprehensive primary frequency regulation acceptance test every 5 years or after a major overhaul. However, performance may change between the two acceptance tests, and potential problems in primary frequency regulation may not be exposed in time. This could lead to technical risks of control performance instability, causing numerous problems such as active power oscillations in units involved in primary frequency regulation.

[0004] Currently, the National Power Grid Dispatch and Control Center has established regional compensation and assessment monitoring systems for primary frequency regulation contributions, namely the "two detailed rules," to monitor the primary frequency regulation response performance when the power grid experiences frequency disturbances of varying magnitudes. However, with increasingly sophisticated power grid operation methods, large frequency deviations are becoming less frequent. The primary frequency regulation monitoring system can only monitor the response performance to disturbances with smaller frequency deviations. To obtain greater compensation, power plants alter their primary frequency regulation performance, significantly enhancing regulation of disturbances with frequency deviations less than 0.1Hz while weakening or limiting regulation of larger frequency deviations. This nonlinear control settings for power plant primary frequency regulation increase the probability of active power fluctuations, reducing unit frequency regulation stability and failing to guarantee regulation performance against occasional large frequency deviation disturbances in the power grid.

[0005] At the power technology level, on the one hand, the guidelines for primary frequency regulation tests of thermal, hydroelectric, and nuclear power plants require acceptance tests for frequency deviation step disturbances at different operating points, but there are no tests specifically for grid frequency fault disturbances that have occurred or simulated in the local power grid. Although step disturbances are a standard method for verifying the regulation and stability performance of control systems, primary frequency regulation control systems are more unique than general automatic control systems. For grid frequency regulation, it is an open-loop control, and the effect of each unit on the grid frequency cannot be used as its control feedback. For the power plant, primary frequency regulation control is a local closed-loop control that adjusts the active power generated based on frequency deviation. Therefore, in actual operation, the grid frequency is not a step disturbance but has its own disturbance characteristics. On the other hand, relevant regulations and actual engineering operation indicate that the operating conditions during the test cannot cover all operating conditions of the units. For example, if air-cooled or heating units are accepted in summer, their winter performance cannot be verified. However, the grid frequency may deviate at any time, causing primary frequency regulation to activate. Therefore, the test conditions should reflect all operating conditions of the units as comprehensively as possible. In engineering sites, there have been frequent instances where step disturbance test results are qualified, but actual large deviation disturbance results in the power grid frequency are unqualified. Therefore, there is an urgent need for test methods targeting the characteristics of power grid frequency disturbances to verify the frequency deviation response performance of power plants under different operating conditions and different accidents.

[0006] At the power grid technology level, remote grid-source coordination test systems have been deployed in power grids in North China, Shandong and other regions. In order to ensure the frequency regulation performance of the units under large frequency deviation disturbances, disturbance tests are conducted regularly to monitor the performance. Large frequency deviation disturbance signals can be sent to power plants for testing and evaluation. The remote system is required to reliably receive frequency disturbance commands from simulated power grid accidents. It is necessary to invest tens of millions of yuan to establish millisecond-level channel enhancement devices to improve the signal command accuracy. However, it is still difficult to fully verify the primary frequency regulation response performance of the units under simulated power grid accidents.

[0007] The Northwest Regulatory Bureau of the National Energy Administration released a grid connection test plan for the fast frequency response function of new energy power plants in the Northwest Power Grid, providing acceptance methods for primary frequency regulation of wind and photovoltaic power plants. In addition to step disturbances, the plan includes test requirements such as simulating actual grid frequency disturbances. However, simulating actual grid frequency disturbances requires an external frequency generator. Apart from setting up the instrument during the acceptance test, it is impossible to monitor its performance again after the test. Furthermore, as a backup frequency regulation power source for conventional hydropower and thermal power, the dead zone of new energy in participating in frequency response is larger than that of conventional power sources. Therefore, new energy will only participate in primary frequency regulation when there is a large frequency disturbance in the grid, which further increases the difficulty of subsequent monitoring of primary frequency regulation performance.

[0008] In summary, current technologies cannot enable power plants to generate and evaluate disturbance tests simulating grid frequencies based on grid fault characteristics. They also cannot address the pressure on power plants caused by the construction of remote monitoring terminals for primary frequency regulation, and large-scale deployment is difficult. Therefore, it is necessary to integrate existing power plant resources, fully utilize the control system that enables primary frequency regulation, and build a frequency signal generation configuration structure based on grid frequency disturbance characteristics. This would not only allow for local power plant testing but also provide a remote grid testing interface, thereby verifying the power plant's frequency deviation response performance under different operating conditions and faults. Summary of the Invention

[0009] This invention provides a power plant configuration method for primary frequency regulation disturbance testing and evaluation, overcoming the shortcomings of the prior art. It can effectively solve the problems in the prior art where power plants cannot generate and evaluate disturbances based on the characteristics of power grid accidents to simulate the power grid frequency, and cannot solve the pressure on power plants caused by the construction of remote monitoring terminals for primary frequency regulation of the power grid.

[0010] The technical solution of this invention is achieved through the following measures:

[0011] A power plant configuration method for primary frequency regulation disturbance testing and evaluation includes the following steps: establishing configuration logic for triggering the test disturbance in the power plant control system; generating a primary frequency regulation test parameter set based on grid conditions; establishing basic configuration logic for theoretical and actual frequency regulation calculations; establishing configuration logic for evaluating the primary frequency regulation response lag time results; establishing configuration logic for evaluating the primary frequency regulation output response ratio results; establishing configuration logic for evaluating the primary frequency regulation power contribution ratio results; establishing configuration logic for primary frequency regulation performance risk alarms; and triggering the primary frequency regulation disturbance locally at the power plant or remotely via an interface on the grid side.

[0012] The following are further optimizations and / or improvements to the above-mentioned technical solution:

[0013] When setting up the configuration logic for triggering test disturbances in the power plant control system, the actual grid frequency or turbine speed deviation can be replaced with the simulated grid frequency or turbine speed deviation when the disturbance is triggered.

[0014] When fitting and generating a primary frequency regulation test parameter set based on power grid conditions, different parameter fitting settings can be used to generate disturbance signals that simulate power grid frequencies based on power grid accident characteristics.

[0015] When setting up the configuration logic for evaluating the lag time of a primary frequency modulation response, the lag time of a primary frequency modulation response can be the time required from the introduction of the disturbance to the change of the controlled variable to 10% of the disturbance.

[0016] When a primary frequency regulation disturbance is triggered locally at the power plant or remotely via the grid, a primary frequency regulation test disturbance can be triggered. After the test, this method outputs values ​​of relevant indicators characterizing the primary frequency regulation performance of the unit. If unqualified performance occurs, an alarm is output. In response to the corresponding performance alarm, the power plant promptly optimizes the primary frequency regulation control logic and parameters.

[0017] The power plant can periodically select different output levels, adjustment methods, control modes, and equipment status changes to execute this step operation, and periodically update the power grid frequency fitting parameter set under the scenario of power grid accidents, so as to comprehensively simulate and verify the performance of the power plant in supporting power grid frequency regulation.

[0018] It may also include the following steps: building configuration logic, configuring parameter sets, providing parameter set data for different power grid accidents or power grid simulation results, inputting the data into the configuration logic to implement disturbance tests that simulate accidents or power grid characteristics, and truly verifying the primary frequency regulation performance of the power station.

[0019] After the signal disturbance is generated and applied to the primary frequency regulation control of the power plant, the response performance can be evaluated by the power plant control system, thus realizing performance verification under different operating conditions and different sets of power grid frequency characteristic parameters.

[0020] The configured logic can reserve a remote trigger command interface to realize the test operation of the power grid remote monitoring system.

[0021] Based on the primary frequency regulation response of the power plant, evaluation results can be generated to effectively characterize the primary frequency regulation performance of the unit, including response lag time, output response ratio, and power contribution ratio. When the evaluation results are unqualified, an alarm can be issued to the operators in a timely manner to promptly investigate and eliminate potential problems under different operating conditions and accidents.

[0022] This invention utilizes a power plant's control system for primary frequency regulation power, establishing a frequency signal generation configuration logic based on the characteristics of power grid frequency disturbances. Unlike other evaluation platforms, this saves on system investment, provides local feedback to maintenance personnel on relevant issues, and facilitates timely detection of potential problems by the power plant. This invention provides a method for simulating primary frequency regulation tests and evaluations under simulated fault conditions using the power plant's own control system, targeting the disturbance characteristics of different power grid frequency accidents. The processing performance of the relevant control systems of the power plant involved in primary frequency regulation can meet the requirements for implementation of this method. Configuration development is performed on the original system, significantly reducing additional system costs. By collecting historical power grid frequency accident or simulated power grid frequency data, the characteristics of the regional power grid frequency can be used as the object to fit and generate a primary frequency regulation test parameter set, simulating trigger signals for different power grid frequency events. Primary frequency regulation disturbance commands can be triggered independently on the power source side, while a remote trigger command interface is reserved to realize test operations of the power grid remote monitoring system. Simulated power grid disturbance primary frequency regulation tests with different parameter sets can be conducted under different power source operating conditions to comprehensively verify the primary frequency regulation performance of the power plant. This invention evaluates the active power variation pattern during primary frequency regulation disturbances, providing highly representative primary frequency regulation performance results in terms of response lag time, power contribution ratio, and output response ratio. It triggers an alarm in the control system for unqualified results, reminding power plant operation and maintenance personnel to promptly carry out performance optimization and maintenance. This invention involves configuration development on the original system, significantly reducing additional system costs. It can trigger disturbance signals simulating different grid frequency events. Primary frequency regulation disturbance commands can be triggered independently at the power source side, or a remote trigger command interface can be reserved to realize experimental operations of the grid remote monitoring system. Simulated grid disturbance primary frequency regulation tests with different parameter sets can be conducted under different power source operating conditions. The flexible parameter set configuration and convenient operation comprehensively verify the primary frequency regulation performance of the power plant. Attached Figure Description

[0023] Appendix Figure 1 This is a schematic diagram of the overall process of an embodiment of the present invention.

[0024] Appendix Figure 2 This is a configuration logic diagram for triggering experimental disturbances in an embodiment of the present invention.

[0025] Appendix Figure 3 This is an enlarged schematic diagram of the LEADLAG module in an embodiment of the present invention.

[0026] Appendix Figure 4 This is a configuration logic diagram that forms the theoretical and practical basis for frequency modulation calculations in the embodiments of the present invention.

[0027] Appendix Figure 5 This is a configuration logic diagram for evaluating the response lag time results in an embodiment of the present invention.

[0028] Appendix Figure 6 This is a configuration logic diagram for evaluating the output response ratio in an embodiment of the present invention.

[0029] Appendix Figure 7 This is a configuration logic diagram for evaluating the power contribution ratio results in an embodiment of the present invention.

[0030] Appendix Figure 8 This is the configuration logic diagram for the delayed time non-compliance alarm in an embodiment of the present invention.

[0031] Appendix Figure 9 This is a configuration logic diagram for an output response failure alarm in an embodiment of the present invention.

[0032] Appendix Figure 10 The configuration logic diagram for the power contribution failure alarm in this embodiment of the invention. Detailed Implementation

[0033] The present invention is not limited to the following embodiments, and the specific implementation can be determined according to the technical solution of the present invention and the actual situation.

[0034] In this invention, for ease of description, the relative positional relationships of each component are described according to the layout of the accompanying drawings. For example, the positional relationships of front, back, top, bottom, left, right, etc., are determined according to the layout direction of the accompanying drawings.

[0035] The present invention will be further described below with reference to embodiments and accompanying drawings:

[0036] Example 1: As shown in the attached document Figures 1 to 10 As shown, the power plant configuration method for primary frequency regulation disturbance testing and evaluation is implemented through software logic optimization of the power plant control system. The control system scan cycle should not exceed 100 milliseconds. The control flow of this method is illustrated in conjunction with the attached diagrams. The diagrams are drawn based on the legend symbols and drafting rules specified in the American Society of Scientific Manufacturers (SAMA) Instrumentation and Control System Functional Diagram (PMC) 22.1 standard. In this diagram, the deviation of the grid frequency or prime mover speed equals the nominal value minus the actual value. The power plant configuration method for primary frequency regulation disturbance testing and evaluation includes the following steps:

[0037] Step 1: Build the configuration logic for triggering the test disturbance in the power plant control system. In Step 1, the actual grid frequency or turbine speed deviation needs to be replaced with the simulated grid frequency or turbine speed deviation when the disturbance is triggered, such as... Figure 2As shown. The KeyBoard algorithm outputs a switching pulse when it receives commands from PK1 to PK4 sent by the operator station. When the power plant operator clicks PK1 on-site to trigger a 1-second pulse or the trigger pulse signal from the remote scheduling interface triggers a longer "pulse time", it marks the start of the disturbance test and sequentially triggers multiple analog quantity switching selection algorithms TRANSFER. The first TRANSFER is triggered without hysteresis. When not triggered, the module outputs 0. If the trigger FLAG is TRUE (meaning true value or 1, and FALSE means false value or 0), the module outputs the Y-terminal value "initial disturbance value" within time T1. Then, it passes through 4 hysteresis-based algorithms LEADLAG. The algorithm transfer function is G(s) = 1 / (1+Ts), where T is the parameter introduced by the LEADLAG pin Lag, which can be input by the operator as the inertial time parameter. The subsequent analog signal switching selection algorithm TRANSFER requires a "hysteresis time" to trigger subsequent fluctuations in the grid frequency or turbine speed. The actual grid frequency signal can be fitted by setting the "attenuation amount" and "inertia time." Most grid frequency variation patterns can be fitted using four perturbation changes. If more subsequent perturbations are needed, the aforementioned TRANSFER and LEADLAG modules can be combined to generate the basic perturbation signal. Figure 2 All the enlarged diagrams of the LEADLAG modules are shown below. Figure 3 As shown. The operator can control the RS trigger to select the action direction by clicking the KeyBoard algorithm PK2 and PK3 buttons. When PK2 is clicked, triggering a 1-second pulse, the RS trigger output is 1, and the subsequent analog quantity switching selection algorithm TRANSFER outputs -1, then the simulated signal at the start of the test is a low-frequency power reduction disturbance; when PK3 is clicked, the RS trigger output is 0, and the TRANSFER output is 1, then the signal is a high-frequency power increase disturbance. The TRANSFER output, the "amplitude coefficient" controlling the overall disturbance, and the disturbance base signal are multiplied to obtain the simulated grid frequency or turbine speed deviation. When the test start signal is TRUE, Figure 2 The output of the bottom TRANSFER module is switched from the actual grid frequency or turbine speed deviation to the simulated grid frequency or turbine speed deviation signal.

[0038] Step 2: Generate a set of primary frequency regulation test parameters based on the power grid conditions. In Step 2, different parameter fitting settings can be used to generate disturbance signals simulating the power grid frequency based on the characteristics of power grid accidents. Figure 2In this context, "Pulse Time tp" represents the total duration of the disturbance, with a value range of 30 to 80 seconds, selected based on the actual grid disturbance verification requirements. "Initial Disturbance Value F0" represents the percentage by which the first peak of the disturbance exceeds the dead zone. If the disturbance is a grid frequency deviation, this value defaults to ±0.0167; if it is a turbine speed difference, it defaults to ±1. A positive value indicates the grid frequency or speed is lower than the nominal value, while a negative value indicates it is higher than the nominal value. The values ​​for "Inertia Time 1" (tl1), "Inertia Time 2" (tl2), "Inertia Time 3" (tl3), and "Inertia Time 4" are also specified. tl4 is the inertia time of the disturbance. The larger the value, the longer the rise time and the greater the inertia. The value can be fitted according to the actual disturbance of the power grid, and the value range is from 0.05 to 5 seconds. "Hysteresis time 1" td1, "Hysteresis time 2" td2, and "Hysteresis time 3" td3 are the intervals for triggering the attenuation, and the value range is from 0.5 to 10 seconds. "Attenuation amount 1" a1, "Attenuation amount 2" a2, and "Attenuation amount 3" a3 are the proportions of the next attenuation amount, and the value range is from 1 to -1. "Amplitude coefficient" A can set the overall disturbance amplitude, and the value range is from 2 to 15.

[0039] For example, the parameter set for a frequency fault in a certain sending-end power grid is as follows: "Pulse Time" tp = 60 seconds, "Initial Disturbance Value" F0 = -0.0167, "Inertia Time 1" tl1 = 0.3 seconds, "Inertia Time 2" tl2 = 0.56 seconds, "Inertia Time 3" tl3 = 0.53 seconds, "Inertia Time 4" tl4 = 0.53 seconds, "Hysteresis Time 1" td1 = 1.5 seconds, "Hysteresis Time 2" td2 = 4.1 seconds, "Hysteresis Time 3" td3 = 4 seconds, "Attenuation 1" a1 = -0.75, "Attenuation 2" a2 = 0.22, "Attenuation 3" a3 = -0.06, "Amplitude Coefficient" A = 8.5.

[0040] For example, the parameter set of a frequency fault in a receiving-end power grid is as follows: tp = 50 seconds, F0 = 0.0167, tl1 = 0.3 seconds, tl2 = 0.51 seconds, tl3 = 0.48 seconds, tl4 = 0.62 seconds, td1 = 1.1 seconds, td2 = 2.1 seconds, td3 = 2.2 seconds, a1 = -0.32, a2 ​​= 0.45, a3 = 0.69, A = 6.3.

[0041] Step 3: Establish the basic configuration logic for theoretical and practical frequency modulation calculations. For example... Figure 3As shown. The configuration introduces a power grid frequency or turbine speed deviation signal. If the signal is a power grid frequency deviation, the linear converter algorithm K should be set to a gain of 60 times; if it is a turbine speed deviation, the K gain is set to 1. Subsequent values ​​are processed by the high / low judgment algorithm HL. When the value exceeds ±2, its output is TRUE, i.e., a "frequency out of dead zone" state is generated. This state is ANDed with the test start state. If the AND value is TRUE, a 2-second pulse signal is triggered on the S pin of the RS flip-flop, setting the RS flip-flop output to "calculation start" and starting the calculation of relevant performance indicators. The reset condition for the R pin of the RS flip-flop is either a NOT gate (frequency out of dead zone) or a 2-second pulse after a 60-second delay of the RS flip-flop output. The 2-second NOT gate pulse output of "calculation start" serves as a "calculation reset" signal, which can reset the calculation result after the calculation is completed and wait for the calculation of the next disturbance result. When the "calculation start" state is TRUE, Figure 3 The left-side analog signal switching algorithm, TRANSFER, switches the output from 0 to the output of f(x), where f(x) is the dead-zone removal function, expressed as:

[0042]

[0043] The TRANSFER output is linearly gained by a gain K, where gain K = target power plant rated power / (3000 × speed skewness or droop rate), yielding the "theoretical frequency regulation power value". For example, if the power plant's rated power is 350MW and the speed skewness is 5%, then K = 350 / (3000 × 5%) = 2.3333. When the "Calculation Start" status is TRUE, Figure 3 The right-side analog switching selection algorithm TRANSFER output locks the "actual active power of the unit" output value of the previous cycle before the start of the calculation. After the calculation starts, the actual active power of the unit is subtracted from the actual active power of the unit at the moment the test starts to obtain the "actual frequency regulation power value".

[0044] Step 4: Build the configuration logic for evaluating the primary frequency modulation response lag time. In Step 4, the primary frequency modulation response lag time is the time required from the introduction of the disturbance to the controlled variable changing to 10% of the disturbance. For example... Figure 4As shown, the absolute value of the "theoretical frequency modulation power value" generated in the third step is calculated. After passing through a gain K of 0.1, it is converted into a 10% disturbance, which is used as the alarm high limit value HISP of the high limit alarm module H. The high limit alarm module H is used to determine whether the 10% disturbance is greater than the absolute value of the "actual frequency modulation power value" generated in the third step. If the condition of being greater than is met or (OR) the product of "theoretical frequency modulation power value" and "actual frequency modulation power value" is less than 0, and (AND) the condition of "frequency has exceeded dead zone" generated in the third step is met, it indicates whether the unit response lag time should be calculated. The output of the control analog quantity switching selection algorithm TRANSFER is switched between 0 and 1 and input to the integral algorithm module. The integration time is set to 1 second. When the above AND condition is not met, the integral algorithm stops integrating. At this time, the output of the integral module can be represented as the result of the primary frequency modulation response lag time. When "Frequency out of dead zone" is TRUE, the bottom TRANSFER output switches from 0 to the output of the integration module. When the frequency enters the dead zone, it switches to 0. The integration algorithm module clears the integration through the tracking line, and the bottom TRANSFER output is the frequency modulation response lag time.

[0045] Step 5: Build the configuration logic for evaluating the frequency modulation output response ratio. Calculate the absolute value of the "actual frequency modulation power value" generated in step 3. Introduce a switching block that outputs 0 when "Calculation Reset" is TRUE; otherwise, use the switching block output value and the maximum value of the absolute value from the previous cycle as the output to the general election module. The general election module then selects the larger of the absolute value and TRANSFER as the output for the current cycle, obtaining the maximum change in actual frequency modulation. Similarly, the right side represents the maximum change in theoretical frequency modulation power value. To prevent overflow errors when the divisor is close to 0, a general election module is added that compares the calculated value with 0.1 and selects the larger one for output, dividing the actual frequency modulation theoretical power value change by the frequency modulation power value change. The product of the theoretical frequency-modulated power value on the far right and the actual active power of the unit is evaluated using the high / low judgment algorithm HL. If the product is greater than 0, the output is TRUE; if it is less than 0, the output is FASLE. This controls the TRANSFER to switch between 1 and -1. To prevent data anomalies caused by frequent switching changes in the early stages of frequency modulation, the result of the switching between 1 and -1 is processed by the first-order inertial module LEADLAG with a lag time of 3 seconds. The above division result is multiplied by the LEADLAG output, and after passing through a gain K of 100, it is converted into a percentage value to obtain the output response ratio evaluation result of the first frequency modulation disturbance test.

[0046] Step 6: Configure the logic for evaluating the power contribution ratio of a single frequency modulation (FM) test. The "theoretical FM power value" is input to the integration algorithm module, with an integration time of 1 second. When the calculation begins, the TRANSFER output switches from 0 to the integration algorithm output; when the calculation ends, it switches back to 0. The integration algorithm module then clears the integral value via a tracking line. To prevent overflow errors when the divisor is close to 0, the lower TRANSFER output is set to 0 if the value is within ±0.1, and the integration algorithm output value is used if the value is outside ±0.1, resulting in the "theoretical FM integrated power value." The "actual FM power value" is also input to the integration algorithm module, with an integration time of 1 second. When the calculation begins, the TRANSFER output switches from 0 to the integration algorithm output, resulting in the "actual FM integrated power value." Finally, the "actual FM integrated power value" is divided by the "theoretical FM integrated power value," and then converted to a percentage value with a gain K of 100, yielding the power contribution ratio evaluation result of the single FM disturbance test.

[0047] Step 7: Configure the frequency regulation performance risk alarm logic. The delay time between "Calculation Start" and (AND) is checked by the high-limit alarm module H to see if it exceeds 2 seconds. After a 0.1-second inverse delay, a 4-second pulse (AND) is applied to the pulse not indicated by "Calculation Start". The result is output to the 10-second pulse module. That is, when the delay time of the frequency regulation test disturbance response is unqualified, the "Lag Time Unqualified Alarm" status will be TRUE 10 seconds after the test ends. Similarly, the output response ratio and power contribution ratio are checked to see if they are less than 80. When the output response or power contribution of the frequency regulation test disturbance is unqualified, the corresponding alarm status will be TRUE 10 seconds after the test ends, reminding operation and maintenance personnel to make timely parameter adjustments and logic optimizations.

[0048] Step 8 involves triggering a primary frequency regulation disturbance locally at the power plant or remotely via an interface on the grid side. Specifically, Step 8 includes the following steps: First, confirm that the optimized configuration of the power plant control system software logic can achieve steps 1 to 7, thus establishing a configuration framework for the primary frequency regulation test and evaluation. Second, select parameters for potential grid frequency disturbance events in the region from the parameter set obtained in Step 2 and input them into the configuration logic of Step 1. Third, use the KeyBoard algorithm PK2 and PK3 in the configuration logic of Step 1 to confirm the action direction. Finally, use the KeyBoard algorithm to click PK1 or remotely trigger the primary frequency regulation test disturbance via the grid. After the test, this method can output values ​​representing the primary frequency regulation performance of the unit. If unqualified performance occurs, an alarm is output. For the corresponding performance alarm, the power plant promptly optimizes the primary frequency regulation control logic and parameters. The power plant can periodically select different output magnitudes, adjustment methods, control modes, and equipment status changes to execute this step sequence, periodically updating the grid frequency fitting parameter set under grid accident scenarios, and comprehensively simulating and verifying the power plant's performance in supporting grid frequency regulation.

[0049] This invention utilizes a power plant's primary frequency regulation power control system to build a frequency signal generation configuration logic based on the characteristics of power grid frequency disturbances. Unlike other evaluation platforms, this saves on system investment and provides local feedback to maintenance personnel, facilitating timely detection of potential problems. This invention provides a method for simulating primary frequency regulation tests and evaluations under simulated fault conditions using the power plant's own control system, addressing the disturbance characteristics of different power grid frequency accidents. First, the processing performance of the relevant control systems of the power plant involved in primary frequency regulation can meet the requirements for this method. Configuration development is performed on the original system, significantly reducing additional system costs. By collecting historical power grid frequency accident or simulated power grid frequency data, the characteristics of the regional power grid frequency can be used as the object to fit and generate a primary frequency regulation test parameter set, simulating trigger signals for different power grid frequency events. Second, primary frequency regulation disturbance commands can be triggered independently on the power source side, while a remote trigger command interface is reserved to realize test operations of the power grid remote monitoring system. Different power source operating conditions and different parameter sets can be selected to conduct simulated power grid disturbance primary frequency regulation tests, achieving the goal of comprehensively verifying the power plant's primary frequency regulation performance. Finally, the active power variation pattern during primary frequency regulation disturbances is evaluated, and representative primary frequency regulation performance results in response lag time, power contribution ratio, and output response ratio are provided. For results that are unqualified, an alarm is triggered in the control system to remind power plant operation and maintenance personnel to promptly carry out performance optimization and maintenance work. Fitting the disturbance characteristic parameters of frequency accidents during power grid simulations or regional power grid accidents is a prerequisite for the experiment of this invention. A matching primary frequency regulation test parameter set is generated. This invention provides a method for primary frequency regulation testing and evaluation under simulated accident conditions using the power plant's own control system. The embodiments of this invention perform configuration development on the original system, significantly reducing additional system costs. It can trigger disturbance signals for different simulated power grid frequency events. Primary frequency regulation disturbance commands can be triggered independently on the power source side, or a remote trigger command interface can be reserved to realize test operations of the power grid remote monitoring system. Simulated power grid disturbance primary frequency regulation tests with different parameter sets can be carried out under different power source operating conditions. The flexible parameter set configuration and convenient operation comprehensively verify the primary frequency regulation performance of the power plant. The evaluation method provides highly representative primary frequency regulation performance results in terms of response lag time, power contribution ratio, and output response ratio. If the results are unqualified, the control system will be triggered to alarm, reminding the power plant operation and maintenance personnel to carry out performance optimization and maintenance work in a timely manner.

[0050] Example 2: As shown in the attached document Figures 1 to 10As shown, the power plant configuration method for primary frequency regulation disturbance testing and evaluation establishes configuration logic and configures parameter sets. It can provide parameter set data for different power grid accidents or power grid simulation results, inputting the data into the configuration logic to implement disturbance tests simulating accident or power grid characteristics, thus realistically verifying the primary frequency regulation performance of the power plant. After the signal disturbance is generated and applied to the primary frequency regulation control of the power plant, the response performance can be evaluated by the power plant control system, enabling performance verification under different operating conditions and different power grid frequency characteristic parameter sets. The established configuration logic reserves a remote trigger command interface to realize test operations of the power grid remote monitoring system. Based on the primary frequency regulation response of the power plant, evaluation results that effectively characterize the unit's primary frequency regulation performance, such as response lag time, output response ratio, and power contribution ratio, are generated. When the evaluation results are unqualified, an alarm is promptly issued to the operators, allowing for timely investigation of related hidden problems under different operating conditions and accidents, thus improving the power plant's proactive support capability in responding to power grid frequency accidents. To compensate for the limitation that the power grid can only evaluate primary frequency regulation after a large frequency difference event, a matching primary frequency regulation test parameter set is generated based on the disturbance characteristics of different power grid frequency accidents in previous and simulated events. Without requiring additional external testing equipment, a logic module for generating and triggering simulated grid frequency disturbance signals and calculating and evaluating primary frequency regulation performance can be built into the existing primary frequency regulation control configuration. This allows for the generation of simulated grid frequency disturbance signals at the power plant, enabling the early detection of primary frequency regulation performance issues before third-party performance acceptance testing or before grid frequency events occur. A remote trigger command interface is also provided to facilitate testing operations by the grid remote monitoring system, allowing for routine simulation of high and low frequency grid disturbance tests. The built evaluation logic can verify the results of representative primary frequency regulation performance parameters such as response lag time, power contribution ratio, and output response ratio. Further performance parameter evaluations can be developed based on this. The evaluation logic can trigger alarms in the control system for unqualified results, reminding power plant maintenance personnel to promptly perform performance optimization and maintenance.

[0051] This invention integrates existing power plant resources and makes full use of the control system that enables primary frequency regulation. It builds a frequency signal generation configuration logic based on the characteristics of power grid frequency disturbances. This not only enables local power plant testing but also provides a remote power grid testing interface. This allows for the verification of the power plant's frequency deviation response performance under different operating conditions and accidents, timely identification of potential problems, and improved proactive support capabilities of the power plant in responding to power grid frequency accidents.

[0052] The above technical features constitute the embodiments of the present invention, which have strong adaptability and implementation effect. Unnecessary technical features can be added or removed according to actual needs to meet the needs of different situations.

Claims

1. A power plant configuration method for primary frequency regulation disturbance testing and evaluation, characterized in that... Includes the following steps: Step 1: Configure the logic for triggering the test disturbance in the power plant control system: Replace the actual grid frequency or turbine speed deviation with the simulated grid frequency or turbine speed deviation when the disturbance is triggered; when the power plant operator clicks PK1 to trigger a 1-second pulse or the trigger pulse signal from the remote dispatch interface, the "pulse time" is triggered, marking the start of the disturbance test, and multiple analog quantity switching selection algorithms TRANSFER are triggered sequentially. The first TRANSFER is triggered without hysteresis. If the trigger FLAG is TRUE, the "initial disturbance value" is output, followed by four hysteresis-based algorithms L... The EADLAG algorithm transfer function is G(s) = 1 / (1+Ts), where T is the inertia time parameter. The subsequent TRANSFER triggering requires a "hysteresis time". The actual grid frequency signal is fitted by setting the "attenuation amount" and "inertia time". The simulated grid frequency or turbine speed deviation is obtained by multiplying the TRANSFER output, the "amplitude coefficient" of the overall disturbance, and the disturbance base signal. When the test start signal is TRUE, the output switches from the actual grid frequency or turbine speed deviation to the simulated grid frequency or turbine speed deviation signal. Step 2: Generate a set of parameters for a primary frequency regulation test based on the power grid conditions: By setting "pulse time" tp, "initial disturbance value" F0, "inertia time 1" tl1, "inertia time 2" tl2, "inertia time 3" tl3, "inertia time 4" tl4, "hysteresis time 1" td1, "hysteresis time 2" td2, "hysteresis time 3" td3, "attenuation 1" a1, "attenuation 2" a2, "attenuation 3" a3 and "amplitude coefficient" A, a disturbance signal simulating the power grid frequency is generated based on the characteristics of power grid accidents. Step 3: Establish the basic configuration logic for theoretical and practical frequency modulation calculations; Step 4: Build the configuration logic for evaluating the frequency modulation response lag time results; Step 5: Build the configuration logic for evaluating the output response ratio of a single frequency modulation operation; Step 6: Build the configuration logic for evaluating the power contribution ratio of a single frequency modulation (FM) cycle: Integrate the "theoretical FM power value" and the "actual FM power value" respectively to obtain the theoretical FM integrated power value and the actual FM integrated power value. Divide the actual FM integrated power value by the theoretical FM integrated power value, convert it to a percentage after gaining 100, and obtain the power contribution ratio evaluation result. Step 7: Build the primary frequency regulation performance risk alarm configuration logic: When the response lag time is greater than 2 seconds, or the output response ratio is less than 80%, or the power contribution ratio is less than 80%, output the alarm status after the test to remind the operation and maintenance personnel to carry out primary frequency regulation control logic and parameter optimization. Step 8: Trigger the primary frequency regulation disturbance locally at the power plant or remotely via the grid interface: Confirm that the configuration can achieve steps 1 to 7; select parameters from the parameter set obtained in step 2 and input them into the configuration logic in step 1; confirm the action direction using KeyBoard algorithms PK2 and PK3; trigger the primary frequency regulation test disturbance by clicking PK1 using the KeyBoard algorithm or by remotely providing the disturbance through the grid, and output the relevant index values ​​characterizing the primary frequency regulation performance of the unit; if unqualified performance occurs, output an alarm, and the power plant should promptly optimize the primary frequency regulation control logic and parameters.

2. The power plant configuration method for primary frequency regulation disturbance testing and evaluation according to claim 1, characterized in that, The power plant periodically selects different output levels, adjustment methods, control modes, and equipment status changes to execute this step operation, and periodically updates the power grid frequency fitting parameter set under the scenario of power grid accidents, and comprehensively simulates and verifies the power plant's performance in supporting power grid frequency regulation.

3. The power plant configuration method for primary frequency regulation disturbance testing and evaluation according to claim 1, characterized in that, Build configuration logic, configure parameter sets, provide parameter set data for different power grid accidents or power grid simulation results, input the parameter set data into the configuration logic to implement disturbance tests that simulate accident or power grid characteristics, and realistically verify the primary frequency regulation performance of the power station.

4. The power plant configuration method for primary frequency regulation disturbance testing and evaluation according to claim 1, characterized in that, After the signal disturbance is generated and applied to the primary frequency regulation control of the power plant, the response performance is evaluated by the power plant control system, thus realizing performance verification under different operating conditions and different sets of power grid frequency characteristic parameters.

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