Thermal power generating unit dynamic coupling compensation coordination control system

Abstract

The invention discloses a thermal power generating unit dynamic coupling compensation coordination control system, which belongs to the technical field of thermal power generating units, and comprises a dynamic coupling compensation module, a self-adaptive sliding pressure optimization module and a coordination control execution module, the dynamic coupling compensation module is used for receiving a load instruction sent by a preset control terminal and generating a dynamic compensation signal; the self-adaptive sliding pressure optimization module is used for correcting a preset initial sliding pressure curve in real time based on the time-varying characteristics of the actual operation parameters of the thermal power generating unit, superposing the current load demand of the thermal power generating unit and the heat storage capacity change of the boiler in the initial sliding pressure curve, and dynamically generating an optimal operation initial pressure target value; and the coordination control execution module is used for integrating the dynamic compensation signal and the optimal operation initial pressure target value into a unified control instruction. The dynamic coupling compensation module, the self-adaptive sliding pressure optimization module and the coordination control execution module are arranged, so that the manual intervention requirement is remarkably reduced.

Description

Technical Field

[0001] The present invention relates to the technical field of thermal power generation units, and in particular to a dynamic coupling compensatory coordinated control system for thermal power generation units. Background Art

[0002] The existing coordinated control system (CCS) of thermal power units receives load instructions and controls the boiler side (fuel, air volume) and the turbine side (throttle opening) respectively to maintain the main steam pressure stability and track the load.

[0003] At present, the steam turbines in thermal power plants are generally installed with the sliding pressure operating curve provided by the turbine manufacturer to set the turbine's initial operating pressure. However, this curve is derived under design conditions and cannot describe the dynamic characteristics of the system when operating under variable conditions. Moreover, this curve is only related to the load and does not consider the impact of other factors on the initial operating pressure.

[0004] The existing technology has the following problems: 1. Under low-load (30% to 50% of rated load) deep peak-shaving conditions, the dynamic coupling between the boiler and the steam turbine is strong, and the traditional PID control has significant lag, resulting in large fluctuations in main steam pressure, slow load response, and heavy reliance on manual intervention; 2. The initial sliding pressure curve provided by the manufacturer cannot adapt to changes in actual operating conditions, which causes fluctuations when the unit responds to load commands.

[0005] Therefore, there is an urgent need to provide a dynamic coupling compensatory coordinated control system for thermal power units to solve the above problems. Summary of the Invention

[0006] The technical problem to be solved by the present invention is to overcome the defects of the above-mentioned prior art and provide a dynamic coupling compensatory coordinated control system for a thermal power unit.

[0007] In order to solve the above technical problems, the present invention adopts a technical solution: providing a dynamic coupling compensation coordinated control system for a thermal power unit, comprising: a dynamic coupling compensation module, an adaptive sliding pressure optimization module and a coordinated control execution module; A dynamic coupling compensation module receives a load instruction from a preset control terminal and, based on the load instruction, collects in real time the main steam flow rate on the boiler side of the thermal power unit, the throttle valve opening on the turbine side, and a set of key load data parameters of the thermal power unit through a preset collection unit, and automatically generates a dynamic compensation signal based on the set of key load data parameters; The adaptive sliding pressure optimization module, based on the time-varying characteristics of the actual operating parameters of the thermal power unit, modifies the preset initial sliding pressure curve in real time, and superimposes the current load demand of the thermal power unit and the change in the boiler's heat storage capacity on the initial sliding pressure curve to dynamically generate the optimal operating initial pressure target value; A coordinated control execution module is used to integrate the dynamic compensation signal and the optimal operating initial pressure target value into a unified control instruction, and at the same time set a pressure change rate constraint unit. When the pressure fluctuation of the pipeline where the main steam flow on the boiler side of the thermal power unit is located exceeds a preset threshold, the preset compensation enhancement mechanism is activated: a pressure compensation instruction is generated based on the amplitude and change direction of the pressure fluctuation of the pipeline where the main steam flow on the boiler side of the thermal power unit is located; the pressure compensation instruction is superimposed on the unified control instruction to form a compensated instruction, and the compensated instruction is synchronized to a preset terminal to control the main steam flow on the boiler side of the thermal power unit and the throttle opening on the turbine side, and track the key parameter set of the load data of the thermal power unit.

[0008] The present invention is further configured as follows: the acquisition of the key parameter set of load data in the dynamic coupling compensation module includes the following steps: S1, the collection unit synchronously collects the main steam flow rate on the boiler side of the thermal power unit, the throttle valve opening on the turbine side, and the load value in the key parameter set of the load data of the thermal power unit in real time when the load instruction is issued; S2. When the rate of change of the load value exceeds a set threshold, the collection unit collects the fluctuation extreme value of the main steam flow on the boiler side and the time difference between the turbine throttle action every second. If the current rate of change of the load value is within the threshold range, the collection unit continuously collects the peak-to-trough interval length and the stable recovery time of the main steam flow on the boiler side; S3. Dynamically weighted fusion is performed on the data collected by the collection unit according to the change direction of the load value: in the load value rising stage, the fluctuation extreme value of the main steam flow on the boiler side of the thermal power unit and the action time difference of the turbine throttle opening are given a high weight to generate a load rise delay parameter that characterizes the boiler response lag characteristic quantity; in the load value falling stage, the peak and trough interval length of the main steam flow are given a high weight to generate a load fall inertia parameter that characterizes the pressure decay characteristic quantity; at the same time, a dynamic stability correction factor is constructed in combination with the stable recovery time, and finally a set of key parameters of the load data is output.

[0009] The present invention is further configured as follows: the specific steps of outputting the key parameter set of load data in step S3 are as follows: S31. When the load instruction is in the normal load stage, a linear mapping relationship between the fluctuation extreme value of the main steam flow rate on the boiler side of the thermal power unit and the peak-to-trough interval length is established, and a normal characteristic parameter is output; when the load instruction is in the deep peak-shaving stage, the correlation strength between the load rise delay parameter and the stable recovery time is strengthened, and the action time difference of the turbine throttle valve opening on the boiler side of the thermal power unit is correlated with the load drop inertia parameter, and a deep peak-shaving characteristic parameter is output; S32. Extract the fluctuation propagation rate of the main steam flow rate on the boiler side of the thermal power unit based on the conventional characteristic parameters and mark it as a conventional stability factor; and generate a peak-shaving coupling influence factor by coupling the load rise delay parameter and the load fall inertia parameter based on the deep peak-shaving characteristic parameters; S33. Integrate the conventional stability factor and the peak-shaving coupling influence factor, combine them with the working condition type label of the current load instruction, generate a dynamic stability correction factor with a working condition identification, and finally output a set of key load data parameters including a load rise delay parameter, a load fall inertia parameter and a dynamic stability correction factor.

[0010] The present invention is further configured as follows: the time-varying characteristics of the actual operating parameters of the thermal power unit in the adaptive sliding pressure optimization module include main steam temperature, feed water flow rate and ambient temperature.

[0011] The present invention is further configured as follows: the steps of generating the dynamic compensation signal in the dynamic coupling compensation module are as follows: Q1. Perform timestamp alignment on the key parameter set of the load data, extract the boiler response lag characteristic from the load rise delay parameter that matches the timestamp, synchronously analyze the pressure decay characteristic from the load fall inertia parameter that matches the timestamp, and calibrate the effective range of the dynamic stability correction factor. Q2. Based on the operating condition marked by the calibrated dynamic stability correction factor, when the load command is in the normal load stage, the normal stability factor is driven to generate a boiler fuel compensation base amount; when the load command is in the deep peak load stage, the peak load coupling influence factor is combined to generate a turbine throttle compensation base amount; Q3. Based on the boiler response lag characteristic, the boiler fuel compensation base amount is superimposed on the pressure decay characteristic to generate a boiler fuel dynamic compensation value; based on the pressure decay characteristic, the turbine throttle compensation base amount is associated with the boiler response lag characteristic to generate a turbine throttle dynamic compensation value; Q4. Perform a two-way supply-demand balance verification on the boiler fuel dynamic compensation value and the turbine throttle dynamic compensation value. When the deviation rate between the two exceeds a preset tolerance threshold, start the preset cross-feedback adjustment, and finally output a dynamic compensation signal that suppresses coupled oscillation.

[0012] The present invention is further configured as follows: the specific content of generating the optimal operating initial pressure target value in the adaptive sliding pressure optimization module is: W1. Based on the actual change trends of the main steam temperature, feed water flow rate, and ambient temperature parameters during actual operation of the thermal power unit, extract the correlation and influence characteristics of each parameter on the initial sliding pressure curve, and calculate the theoretical reference pressure offset of the initial sliding pressure curve at different load points; W2. Dynamically couple the theoretical reference pressure offset with the change in the current boiler heat storage capacity of the thermal power unit, and superimpose the actual rate of change of the load demand to generate a pressure adjustment gradient value. Based on the degree of matching between the pressure adjustment gradient value and the theoretical reference pressure offset, an initial operating pressure target value is generated; W3. Compare the change range of the initial operating pressure target value with the preset historical correction value. When the change range exceeds the set margin, activate the preset correction coefficient update mechanism, use the current initial operating pressure instant correction value in the correction coefficient update mechanism as the new benchmark of the historical correction value, and output the optimal initial operating pressure target value.

[0013] The present invention is further configured as follows: the coordinated control execution module integrates the dynamic compensation signal and the optimal operation initial pressure target value into a unified control instruction, and the specific steps are as follows: H1. Establishing a basic instruction carrier framework in the coordinated control execution module, generating a basic instruction carrier within the basic instruction carrier framework based on the optimal initial operating pressure target value, and configuring a dynamic docking space for the dynamic compensation signal on the basic instruction carrier; H2. Injecting the boiler fuel dynamic compensation value and the turbine throttle dynamic compensation value in the dynamic compensation signal into the dynamic docking space respectively, and simultaneously calling the pressure adjustment coefficient in the basic instruction carrier that matches the working condition of the current load instruction, performing a weighted balancing operation on the injected boiler fuel dynamic compensation value and the turbine throttle dynamic compensation value to generate a pre-verified instruction combination; H3. A coordinated convergence calculation is performed on the boiler fuel control target and the turbine throttle control target in the command combination through a preset command fusion algorithm. When the dynamic coordinated deviation between the boiler fuel control quantity change rate and the turbine throttle opening change rate is within a preset allowable range, a unified control command is output.

[0014] The present invention is further configured as follows: the specific working content of the compensation reinforcement mechanism in the coordinated control execution module is: F1. When the pressure change rate constraint unit detects that the main steam pressure fluctuation on the boiler side of the thermal power unit exceeds a preset threshold, the compensation enhancement mechanism is activated to generate a pressure compensation instruction according to the amplitude and change direction of the main steam pressure fluctuation on the boiler side of the thermal power unit; F2. Superimposing the pressure compensation instruction onto the unified control instruction output by the coordinated control execution module to form a compensated instruction, and synchronizing the compensated instruction to a preset terminal in real time through a preset communication protocol; F3, the terminal drives the combustion regulation system on the boiler side of the thermal power unit to change the main steam flow rate based on the fuel instruction component on the boiler side in the compensated instruction, and controls the rate of change of the turbine throttle valve opening based on the turbine throttle valve instruction component in the compensated instruction; F4. The terminal monitors the main steam pressure change curve and actual load data of the boiler side of the thermal power unit in real time. When it is detected that the main steam pressure fluctuation amplitude on the boiler side of the thermal power unit is within the preset target fluctuation range for three consecutive sampling periods and the actual load tracking deviation rate is lower than the permitted threshold, the compensation enhancement mechanism control is released and the basic control mode of the coordinated control execution module is switched.

[0015] The beneficial effects of the present invention are as follows: 1. This invention uses a dynamic coupling compensation module to intelligently decouple and compensate for the dynamic coupling between the boiler and turbine. Combined with the coordinated control execution module's real-time closed-loop collaborative control mechanism, this significantly reduces the hysteresis effects of traditional PID control under deep peak-shaving conditions, allowing the main steam pressure fluctuation amplitude to quickly converge to the target range. Furthermore, a command fusion algorithm based on the error phase space strengthens the response synchronization of the boiler-turbine dual system, significantly improving the unit's load command tracking capability under low-load peak-shaving conditions and significantly reducing the need for manual intervention. 2. The present invention analyzes the dynamic impact characteristics of the main steam temperature, feed water flow rate and ambient temperature on the sliding pressure curve in real time, and intelligently reconstructs the pressure operating baseline values ​​at different load points. Combined with the dynamic threshold trigger mechanism of the pressure change rate constraint unit, the initial sliding pressure curve can autonomously adapt to changes in actual operating conditions, effectively eliminating the pressure fluctuation problem when the unit responds to load instructions, and improving the system stability under load peaking conditions. BRIEF DESCRIPTION OF THE DRAWINGS

[0016] Figure 1 It is a system structure block diagram of the present invention; Figure 2 This is a flow chart for collecting load data of the present invention; Figure 3 A flow chart of the steps for generating a dynamic compensation signal according to the present invention; Figure 4 The flowchart of the steps for generating the optimal initial operating pressure target value of the present invention is shown. DETAILED DESCRIPTION

[0017] The preferred embodiments of the present invention are described in detail below with reference to the accompanying drawings so that the advantages and features of the present invention can be more easily understood by those skilled in the art, thereby making a clearer and more precise definition of the protection scope of the present invention.

[0018] See also Figures 1-4A dynamic coupling compensation coordinated control system for a thermal power unit includes: a dynamic coupling compensation module, an adaptive sliding pressure optimization module, and a coordinated control execution module, wherein communication connections are established between the dynamic coupling compensation module, the adaptive sliding pressure optimization module, and the coordinated control execution module; The dynamic coupling compensation module receives the load instruction from the preset control terminal and collects the main steam flow on the boiler side of the thermal power unit, the throttle opening on the turbine side, and the key parameter set of the load data of the thermal power unit in real time through the preset collection unit according to the load instruction, and automatically generates a dynamic compensation signal based on the key parameter set of the load data; The collection of the key parameter set of load data in the dynamic coupling compensation module includes the following steps: S1. The collection unit synchronously collects the main steam flow rate on the boiler side of the thermal power unit, the throttle valve opening on the turbine side, and the load value in the key parameter set of the load data of the thermal power unit in real time when the load instruction is issued; Within the millisecond time window of receiving the load command signal, the acquisition unit synchronously triggers three parallel acquisition channels: the first channel intercepts the 4-20mA analog signal of the main steam flow transmitter from the boiler system in the thermal power unit in real time at a sampling interval of 10ms, and outputs the digital flow value through the AD conversion module; the second channel is directly connected to the turbine control cabinet through hard wiring, collects the actual opening voltage signal fed back by the turbine throttle displacement sensor and converts it into a percentage opening value; the third channel reads the load value of the generator power meter in real time from the thermal power unit system through the communication protocol; S2. When the load value change rate exceeds the set threshold, the collection unit collects the fluctuation extreme value of the main steam flow on the boiler side and the time difference between the turbine throttle action every second. If the current load value change rate is within the threshold range, the collection unit continuously collects the peak and trough intervals of the main steam flow on the boiler side and the time required for stable recovery. Among them, "within the threshold range" specifically refers to the load value change rate being in the range of 2% to 10% / min (excluding the endpoint value), at which time the system is in a quasi-steady-state operating condition; S3. Dynamically weight and fuse the data collected by the acquisition unit according to the direction of change of the load value: in the load value rising stage, the fluctuation extreme value of the main steam flow on the boiler side of the thermal power unit and the action time difference of the turbine throttle opening are given a high weight to generate a load rise delay parameter that represents the boiler response lag characteristic quantity; in the load value falling stage, the peak and trough interval length of the main steam flow are given a high weight to generate a load drop inertia parameter that represents the pressure attenuation characteristic quantity; at the same time, a dynamic stability correction factor is constructed in combination with the stable recovery time, and finally a set of key parameters of the load data is output.

[0019] The specific steps for constructing the dynamic stability correction factor and outputting the set of key load data parameters in step S3 are as follows: The stable recovery time value collected in step S2 is obtained and normalized, and different weighting strategies are selected according to the change direction of the current load value: when the load instruction increases, the stable recovery time is time-series coupled with the load increase delay parameter to extract the correlation characteristics of the stable recovery time with the main steam flow fluctuation peak attenuation rate to generate the first type of stability influencing factor; when the load value decreases, the stable recovery time is correlated with the peak-to-valley interval decay rate in the load decrease inertia parameter to extract the linear inertia characteristics of the pressure fluctuation duration to generate the second type of stability influencing factor; based on the real-time operating condition label of the thermal power unit, the first type of stability influencing factor or the second type of stability influencing factor is activated, and the slow-changing fluctuation characteristics within the load value change rate threshold range are integrated to generate the characteristic vector of the dynamic stability correction factor. Finally, the load increase delay parameter, the load decrease inertia parameter and the dynamic stability correction factor with the operating condition label are integrated to form a key parameter set with characteristic weights.

[0020] The specific steps of outputting the key parameter set of load data in step S3 are as follows: S31. When the load instruction is in the normal load stage, a linear mapping relationship is established between the fluctuation extreme value of the main steam flow rate on the boiler side of the thermal power unit and the peak-to-trough interval length, and a normal characteristic parameter is output; when the load instruction is in the deep peak-shaving stage, the correlation strength between the load rise delay parameter and the stable recovery time is strengthened, and the action time difference of the turbine throttle opening on the boiler side of the thermal power unit is correlated with the load drop inertia parameter, and a deep peak-shaving characteristic parameter is output; The specific steps of establishing a linear mapping relationship and outputting conventional feature parameters in step S31 are as follows: Extract the peak and valley data points of the continuous fluctuation cycle from the extreme values ​​of the main steam flow fluctuation collected in step S2, and associate the peak-valley interval duration record sequence of the corresponding timestamps; construct a fluctuation intensity description vector based on the amplitude difference characteristics of the peak and valley data points, and convert the peak-valley interval duration record sequence into a period feature vector; establish a linear co-evolution rule base of the fluctuation intensity description vector and the period feature vector, and extract the matching correlation coefficient between the fluctuation intensity change rate and the interval duration decay rate in the rule base; generate a dynamic linear mapping rule based on the sample segment with a matching correlation coefficient greater than a preset standard, and apply the rule to the real-time collected fluctuation extreme value sequence to calculate and output the integrated value label of the conventional feature parameter; S32. Extract the fluctuation propagation rate of the main steam flow rate on the boiler side of the thermal power unit based on the conventional characteristic parameters and mark it as a conventional stability factor; couple the load rise delay parameter and the load fall inertia parameter based on the deep peak regulation characteristic parameters to generate a peak regulation coupling influence factor; S33. Integrate the conventional stability factor and the peak-shaving coupling influencing factor, combine them with the working condition type label of the current load instruction, generate a dynamic stability correction factor with a working condition identification, and finally output a set of key load data parameters including load rise delay parameters, load fall inertia parameters and dynamic stability correction factors.

[0021] The time-varying characteristics of the actual operating parameters of the thermal power unit in the adaptive sliding pressure optimization module include main steam temperature, feed water flow and ambient temperature.

[0022] The steps for generating the dynamic compensation signal in the dynamic coupling compensation module are as follows: Q1. Perform timestamp alignment on the key parameter set of load data, extract the boiler response lag characteristic from the timestamp-matched load rise delay parameter, and simultaneously analyze the pressure decay characteristic from the timestamp-matched load fall inertia parameter. Also, calibrate the effective range of the dynamic stability correction factor. The specific operation of extracting the boiler response hysteresis characteristic in step Q1 is as follows: First, a millisecond-level timestamp alignment operation is performed on the key parameter set of load data, and a load increase delay parameter set with overlapping timestamps and in the load instruction increase stage is selected; the time difference between the moment when the extreme value of the main steam flow fluctuation on the boiler side reaches the peak and the actual opening response peak of the turbine throttle is analyzed from the parameter set, and the time difference is converted into a dynamic hysteresis feature vector through a time delay-hysteresis conversion model; at the same time, the number of mutation points of the main steam flow increase rate and the position of the acceleration inflection point of the throttle opening in the corresponding time window are extracted, and the number of mutation points and the position of the acceleration inflection point are associated to generate a response fault identification factor; the dynamic hysteresis feature vector and the response fault identification factor are integrated to output the boiler response hysteresis feature carrying the timestamp and hysteresis intensity; Q2. Based on the operating condition marked by the calibrated dynamic stability correction factor, when the load instruction is in the normal load stage, the conventional stability factor is driven to generate the boiler fuel compensation base amount. When the load instruction is in the deep peak load stage, the peak load coupling influence factor is combined to generate the turbine throttle compensation base amount. Q3. Based on the boiler response lag characteristic, the boiler fuel compensation base amount is superimposed on the pressure decay characteristic to generate a boiler fuel dynamic compensation value; based on the pressure decay characteristic, the turbine throttle compensation base amount is associated with the boiler response lag characteristic to generate a turbine throttle dynamic compensation value; The specific steps for generating the boiler fuel dynamic compensation value in step Q3 are as follows: inputting the boiler fuel compensation base amount and the pressure attenuation characteristic amount into the dynamic weight allocator, first analyzing the main steam pressure drop rate inflection point distribution and the valley residence time in the pressure attenuation characteristic amount, and calculating the pressure attenuation dynamic influence weight ratio based on the inflection point distribution density and the valley residence time; synchronously extracting the fuel supply rate increment benchmark contained in the boiler fuel compensation base amount, and establishing a time-delay matching correction factor of the fuel supply rate increment benchmark and the pressure attenuation dynamic influence weight ratio; dividing the pressure attenuation characteristic amount into a positive buffer segment and a negative inhibition segment through the time-delay matching correction factor, applying an exponential gain coefficient to the positive buffer segment and superimposing it on the fuel supply rate increment benchmark to generate a first compensation component, and applying an inertia damping coefficient to the negative inhibition segment to generate a second compensation component; finally, performing time-domain convolution fusion on the first compensation component and the second compensation component, and outputting the boiler fuel dynamic compensation value carrying the pressure attenuation adaptive weight.

[0023] Q4. Perform a two-way supply and demand balance verification on the dynamic compensation value of boiler fuel and the dynamic compensation value of turbine throttle. When the deviation rate between the two exceeds the preset tolerance threshold (the critical value of the dynamic supply and demand matching deviation between the boiler fuel compensation demand and the turbine throttle compensation demand), the preset cross-feedback adjustment is initiated, and finally a dynamic compensation signal that suppresses coupled oscillation is output.

[0024] Adaptive sliding pressure optimization module, based on the time-varying characteristics of the actual operating parameters of the thermal power unit, adjusts the preset initial sliding pressure curve in real time, and superimposes the current load demand of the thermal power unit and the change of boiler heat storage capacity on the initial sliding pressure curve to dynamically generate the optimal operating initial pressure target value; The specific content of generating the optimal operating initial pressure target value in the adaptive sliding pressure optimization module is as follows: W1. Based on the actual change trends of main steam temperature, feed water flow rate and ambient temperature parameters in actual operation of thermal power units, the correlation and influence characteristics of each parameter on the initial sliding pressure curve are extracted, and the theoretical reference pressure offset of the initial sliding pressure curve at different load points is calculated; The calculation method of the theoretical reference pressure offset is as follows: extract three types of characteristic parameters of the real-time operation of the thermal power unit, namely the main steam temperature change gradient, the feed water flow fluctuation period and the ambient temperature deviation amplitude from the reference value, and calculate the correlation influence coefficient of each parameter on the load point corresponding to the initial sliding pressure curve; map the main steam temperature change gradient characteristics to the turbine thermal efficiency correction model to output the first pressure offset factor, input the feed water flow fluctuation period into the boiler heat storage dynamic equation to output the second pressure offset factor, and load the ambient temperature deviation amplitude into the heat dissipation compensation algorithm to output the third pressure offset factor; perform spatiotemporal superposition integration on the first, second and third pressure offset factors through the three-factor synergistic field model to generate a pressure compensation spectrum distribution diagram of the initial sliding pressure curve under different load conditions; generate a theoretical reference pressure offset curve based on the connection of the compensation extreme value position of each load point in the spectrum distribution diagram, and finally output the load point-offset mapping set; W2. Dynamically couple the theoretical baseline pressure offset with the change in the current boiler heat storage capacity of the thermal power unit, and superimpose the actual rate of change in load demand to generate a pressure adjustment gradient value. Based on the degree of matching between the pressure adjustment gradient value and the theoretical baseline pressure offset, the initial operating pressure target value is generated. W3. Compare the change range of the initial operating pressure target value and the preset historical correction value. When the change range exceeds the set margin, activate the preset correction coefficient update mechanism, use the current initial operating pressure instant correction value in the correction coefficient update mechanism as the new benchmark of the historical correction value, and output the optimal initial operating pressure target value.

[0025] The coordinated control execution module is used to integrate the dynamic compensation signal and the optimal operating initial pressure target value into a unified control instruction, and at the same time set a pressure change rate constraint unit. When the pressure fluctuation of the pipeline where the main steam flow on the boiler side of the thermal power unit is located exceeds the preset threshold, the preset compensation enhancement mechanism is activated: a pressure compensation instruction is generated based on the amplitude and change direction of the pressure fluctuation of the pipeline where the main steam flow on the boiler side of the thermal power unit is located; the pressure compensation instruction is superimposed on the unified control instruction to form a compensated instruction, and the compensated instruction is synchronized to the preset terminal to control the main steam flow on the boiler side of the thermal power unit and the throttle opening on the turbine side, and track the key parameter set of the load data of the thermal power unit.

[0026] The coordinated control execution module integrates the dynamic compensation signal and the optimal initial pressure target value into a unified control instruction. The specific steps are as follows: H1. Establish a basic instruction carrier framework in the coordinated control execution module, and generate a basic instruction carrier within the basic instruction carrier framework based on the optimal initial operating pressure target value. Then, configure a dynamic docking space for the dynamic compensation signal on the basic instruction carrier. H2. Inject the boiler fuel dynamic compensation value and the turbine throttle dynamic compensation value in the dynamic compensation signal into the dynamic docking space respectively. Simultaneously, call the pressure adjustment coefficient in the basic instruction carrier that matches the working condition of the current load instruction. Perform a weighted balancing operation on the injected boiler fuel dynamic compensation value and the turbine throttle dynamic compensation value to generate a pre-verified instruction combination. H3. The boiler fuel control target and the turbine throttle control target in the command combination are coordinated and converged by the preset command fusion algorithm. When the dynamic coordinated deviation between the boiler fuel control quantity change rate and the turbine throttle opening change rate is within the preset allowable range, a unified control command is output.

[0027] The preset instruction fusion algorithm is used to calculate the coordinated convergence of the boiler fuel control target and the turbine regulating valve control target in the instruction combination, specifically: An error phase space is established between the trajectory of the boiler fuel control quantity change rate and the trajectory of the turbine throttle valve opening change rate, and the gradient offset angle of the boiler fuel control target sequence and the oscillation attenuation rate of the turbine throttle valve control target sequence in the instruction assembly are extracted; a dual-track target collaborative traversal operation is performed in the error phase space: the gradient offset angle is mapped as the input vector of the phase difference correction channel, and the oscillation attenuation rate is input into the damping margin balance channel at the same time; a nonlinear covariance minimization calculation is performed on the input vector and the output value of the damping margin balance channel through the dynamic coupling factor. When the fluctuation amplitude of the gradient offset angle is within the preset allowable range for three consecutive calculation cycles and the fluctuation frequency of the oscillation attenuation rate drops to the preset stable frequency band, it is determined that the boiler fuel control target and the turbine throttle valve control target have reached a coordinated convergence state.

[0028] Among them, the specific work content of the compensation reinforcement mechanism in the coordinated control execution module is: F1. When the pressure change rate constraint unit detects that the main steam pressure fluctuation on the boiler side of the thermal power unit exceeds a preset threshold, the compensation enhancement mechanism is activated to generate a pressure compensation instruction based on the amplitude and change direction of the main steam pressure fluctuation on the boiler side of the thermal power unit; F2. Superimpose the pressure compensation instruction on the unified control instruction output by the coordinated control execution module to form a compensated instruction, and synchronize the compensated instruction to the preset terminal in real time through a preset communication protocol; F3, the terminal drives the combustion control system on the boiler side of the thermal power unit to change the main steam flow based on the fuel command component on the boiler side in the compensated command, and controls the rate of change of the turbine throttle valve opening based on the turbine throttle valve command component in the compensated command; F4. The terminal monitors the main steam pressure change curve and actual load data of the boiler side of the thermal power unit in real time. When it detects that the main steam pressure fluctuation amplitude of the boiler side of the thermal power unit is within the preset target fluctuation range for three consecutive sampling periods and the actual load tracking deviation rate is lower than the permitted threshold, the compensation enhancement mechanism control is released and the control is switched to the basic control mode of the coordinated control execution module.

[0029] Example 1: Deep peak-shaving operation of a 300MW subcritical unit Under deep peak load regulation conditions for a 300 MW subcritical unit, the load command decreased from 180 MW to 120 MW at a rate of 12% / min. After detecting that the rate of change exceeded a threshold, the acquisition unit collected the main steam flow fluctuation extremes (peak value 8.5 MPa, valley value 7.2 MPa) and the throttle action time difference (2.8 seconds) every second. Simultaneously, load reduction inertia parameters were generated in the S3 phase. The adaptive sliding pressure module calculated a pressure offset of +0.6 MPa at the 40% load point using a three-factor collaborative model based on the feedwater flow fluctuation period (28 seconds) and the sudden change in ambient temperature (15°C to 5°C). In the Q3 phase, the dynamic coupling compensation module segmented the pressure decay characteristic into a positive buffer segment (the first 10 seconds) and applied a 1.3x exponential gain to generate a dynamic compensation value for the boiler fuel. The coordinated control execution module stabilized the gradient offset angle within the permitted range of ±0.5 rad through H3 error phase space calculations. Finally, the compensation enhancement mechanism detected that the main steam pressure fluctuation remained within the target range of ±0.4 MPa for three consecutive cycles. Enhanced control was released when the load tracking deviation rate of 0.8% fell below the 1.5% threshold.

[0030] Example 2: Load ramping condition of 600MW supercritical unit A 600MW supercritical unit responds to the AGC instruction and increases its power from 480MW to 540MW at a rate of 9% / min. In the S2 stage, the peak-to-valley interval of the main steam flow (peak value 950t / h, valley value 820t / h, cycle 42 seconds) and the stable recovery time (18 seconds) are collected. In S32, the recovery time of the instruction rise response section is converted into a 1.25-time time efficiency weight coefficient and superimposed on the conventional stability factor; the sliding pressure optimization module generates a 60% load point based on the main steam temperature gradient (2℃ / s) through the thermal efficiency correction model. The pressure offset is -0.3MPa; in the Q4 stage, the supply and demand of the boiler fuel dynamic compensation value (+12.8t / h) and the steam turbine throttle compensation value (+9.6%) are verified, and when the deviation rate of 1.7% exceeds the 1.5% tolerance threshold, cross-feedback adjustment is initiated; the H3 command fusion algorithm reduces the oscillation attenuation rate fluctuation frequency to a stable frequency band of 0.05Hz in the error phase space. After coordinated convergence, the pressure change rate constraint unit monitors the pressure fluctuation amplitude and maintains the target range of ±0.35MPa for three consecutive cycles, and the load tracking accuracy reaches 98.6%.

[0031] The above descriptions are merely embodiments of the present invention and are not intended to limit the patent scope of the present invention. Any equivalent structure or equivalent process transformation made using the contents of the present invention's description and drawings, or directly or indirectly applied in other related technical fields, are also included in the patent protection scope of the present invention.

Claims

1. A dynamic coupling compensatory coordinated control system for a thermal power unit, characterized by: include: Dynamic coupling compensation module, adaptive sliding pressure optimization module and coordinated control execution module; A dynamic coupling compensation module receives a load instruction from a preset control terminal and, based on the load instruction, collects in real time the main steam flow rate on the boiler side of the thermal power unit, the throttle valve opening on the turbine side, and a set of key load data parameters of the thermal power unit through a preset collection unit, and automatically generates a dynamic compensation signal based on the set of key load data parameters; The adaptive sliding pressure optimization module, based on the time-varying characteristics of the actual operating parameters of the thermal power unit, modifies the preset initial sliding pressure curve in real time, and superimposes the current load demand of the thermal power unit and the change in the boiler's heat storage capacity on the initial sliding pressure curve to dynamically generate the optimal operating initial pressure target value; A coordinated control execution module is used to integrate the dynamic compensation signal and the optimal operating initial pressure target value into a unified control instruction, and at the same time set a pressure change rate constraint unit. When the pressure fluctuation of the pipeline where the main steam flow on the boiler side of the thermal power unit is located exceeds a preset threshold, the preset compensation enhancement mechanism is activated: a pressure compensation instruction is generated based on the amplitude and change direction of the pressure fluctuation of the pipeline where the main steam flow on the boiler side of the thermal power unit is located; the pressure compensation instruction is superimposed on the unified control instruction to form a compensated instruction, and the compensated instruction is synchronized to a preset terminal to control the main steam flow on the boiler side of the thermal power unit and the throttle opening on the turbine side, and track the key parameter set of the load data of the thermal power unit.

2. A thermal power unit dynamic coupling compensatory coordinated control system according to claim 1, characterized in that: The acquisition of the key parameter set of load data in the dynamic coupling compensation module includes the following steps: S1, the collection unit synchronously collects the main steam flow rate on the boiler side of the thermal power unit, the throttle valve opening on the turbine side, and the load value in the key parameter set of the load data of the thermal power unit in real time when the load instruction is issued; S2. When the rate of change of the load value exceeds a set threshold, the collection unit collects the fluctuation extreme value of the main steam flow on the boiler side and the time difference between the turbine throttle action every second. If the current rate of change of the load value is within the threshold range, the collection unit continuously collects the peak-to-trough interval length and the stable recovery time of the main steam flow on the boiler side; S3. Dynamically weighted fusion is performed on the data collected by the collection unit according to the change direction of the load value: in the load value rising stage, the fluctuation extreme value of the main steam flow on the boiler side of the thermal power unit and the action time difference of the turbine throttle opening are given a high weight to generate a load rise delay parameter that characterizes the boiler response lag characteristic quantity; in the load value falling stage, the peak and trough interval length of the main steam flow are given a high weight to generate a load fall inertia parameter that characterizes the pressure decay characteristic quantity; at the same time, a dynamic stability correction factor is constructed in combination with the stable recovery time, and finally a set of key parameters of the load data is output.

3. A thermal power unit dynamic coupling compensatory coordinated control system according to claim 2, characterized in that: The specific steps of outputting the key parameter set of load data in step S3 are as follows: S31, establishing a linear mapping relationship between the fluctuation extreme value of the main steam flow rate on the boiler side of the thermal power unit and the peak-to-trough interval length when the load instruction is in the normal load stage, and outputting normal characteristic parameters; When the load instruction is in the deep peak regulation stage, the correlation strength between the load rise delay parameter and the stable recovery time is strengthened, and at the same time, the action time difference of the turbine throttle valve opening on the boiler side of the thermal power unit is correlated with the load drop inertia parameter to output the deep peak regulation characteristic parameter; S32. Extract the fluctuation propagation rate of the main steam flow rate on the boiler side of the thermal power unit based on the conventional characteristic parameters and mark it as a conventional stability factor; and generate a peak-shaving coupling influence factor by coupling the load rise delay parameter and the load fall inertia parameter based on the deep peak-shaving characteristic parameters; S33. Integrate the conventional stability factor and the peak-shaving coupling influence factor, combine them with the working condition type label of the current load instruction, generate a dynamic stability correction factor with a working condition identification, and finally output a set of key load data parameters including a load rise delay parameter, a load fall inertia parameter and a dynamic stability correction factor.

4. A thermal power unit dynamic coupling compensatory coordinated control system according to claim 3, characterized in that: The time-varying characteristics of the actual operating parameters of the thermal power unit in the adaptive sliding pressure optimization module include main steam temperature, feed water flow rate and ambient temperature.

5. A thermal power unit dynamic coupling compensatory coordinated control system according to claim 4, characterized in that: The steps for generating the dynamic compensation signal in the dynamic coupling compensation module are as follows: Q1. Perform timestamp alignment on the key parameter set of the load data, extract the boiler response lag characteristic from the load rise delay parameter that matches the timestamp, synchronously analyze the pressure decay characteristic from the load fall inertia parameter that matches the timestamp, and calibrate the effective range of the dynamic stability correction factor. Q2. Based on the operating condition marked by the calibrated dynamic stability correction factor, when the load command is in the normal load stage, the normal stability factor is driven to generate a boiler fuel compensation base amount; when the load command is in the deep peak load stage, the peak load coupling influence factor is combined to generate a turbine throttle compensation base amount; Q3. Based on the boiler response lag characteristic, the boiler fuel compensation base amount is superimposed on the pressure decay characteristic to generate a boiler fuel dynamic compensation value; based on the pressure decay characteristic, the turbine throttle compensation base amount is associated with the boiler response lag characteristic to generate a turbine throttle dynamic compensation value; Q4. Perform a two-way supply-demand balance verification on the boiler fuel dynamic compensation value and the turbine throttle dynamic compensation value. When the deviation rate between the two exceeds a preset tolerance threshold, start the preset cross-feedback adjustment, and finally output a dynamic compensation signal that suppresses coupled oscillation.

6. A thermal power unit dynamic coupling compensatory coordinated control system according to claim 5, characterized in that: The specific content of generating the optimal operating initial pressure target value in the adaptive sliding pressure optimization module is: W1. Based on the actual change trends of the main steam temperature, feed water flow rate, and ambient temperature parameters during actual operation of the thermal power unit, extract the correlation and influence characteristics of each parameter on the initial sliding pressure curve, and calculate the theoretical reference pressure offset of the initial sliding pressure curve at different load points; W2. Dynamically couple the theoretical reference pressure offset with the change in the current boiler heat storage capacity of the thermal power unit, and superimpose the actual rate of change of the load demand to generate a pressure adjustment gradient value. Based on the degree of matching between the pressure adjustment gradient value and the theoretical reference pressure offset, an initial operating pressure target value is generated; W3. Compare the change range of the initial operating pressure target value with the preset historical correction value. When the change range exceeds the set margin, activate the preset correction coefficient update mechanism, use the current initial operating pressure instant correction value in the correction coefficient update mechanism as the new benchmark of the historical correction value, and output the optimal initial operating pressure target value.

7. A thermal power unit dynamic coupling compensatory coordinated control system according to claim 6, characterized in that: The coordinated control execution module integrates the dynamic compensation signal and the optimal operation initial pressure target value into a unified control instruction, and the specific steps are as follows: H1. Establishing a basic instruction carrier framework in the coordinated control execution module, generating a basic instruction carrier within the basic instruction carrier framework based on the optimal initial operating pressure target value, and configuring a dynamic docking space for the dynamic compensation signal on the basic instruction carrier; H2. Injecting the boiler fuel dynamic compensation value and the turbine throttle dynamic compensation value in the dynamic compensation signal into the dynamic docking space respectively, and simultaneously calling the pressure adjustment coefficient in the basic instruction carrier that matches the working condition of the current load instruction, performing a weighted balancing operation on the injected boiler fuel dynamic compensation value and the turbine throttle dynamic compensation value to generate a pre-verified instruction combination; H3. A coordinated convergence calculation is performed on the boiler fuel control target and the turbine throttle control target in the command combination through a preset command fusion algorithm. When the dynamic coordinated deviation between the boiler fuel control quantity change rate and the turbine throttle opening change rate is within a preset allowable range, a unified control command is output.

8. A thermal power unit dynamic coupling compensatory coordinated control system according to claim 7, characterized in that: The specific working content of the compensation reinforcement mechanism in the coordinated control execution module is: F1. When the pressure change rate constraint unit detects that the main steam pressure fluctuation on the boiler side of the thermal power unit exceeds a preset threshold, the compensation enhancement mechanism is activated to generate a pressure compensation instruction according to the amplitude and change direction of the main steam pressure fluctuation on the boiler side of the thermal power unit; F2. Superimposing the pressure compensation instruction onto the unified control instruction output by the coordinated control execution module to form a compensated instruction, and synchronizing the compensated instruction to a preset terminal in real time through a preset communication protocol; F3, the terminal drives the combustion regulation system on the boiler side of the thermal power unit to change the main steam flow rate based on the fuel instruction component on the boiler side in the compensated instruction, and controls the rate of change of the turbine throttle valve opening based on the turbine throttle valve instruction component in the compensated instruction; F4. The terminal monitors the main steam pressure change curve and actual load data of the boiler side of the thermal power unit in real time. When it is detected that the main steam pressure fluctuation amplitude on the boiler side of the thermal power unit is within the preset target fluctuation range for three consecutive sampling periods and the actual load tracking deviation rate is lower than the permitted threshold, the compensation enhancement mechanism control is released and the basic control mode of the coordinated control execution module is switched.

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