Unit variable rate control method and system based on main air pressure prediction

Abstract

The invention discloses a unit variable rate control method and system based on main air pressure prediction. The method comprises the steps that the current load of a unit, the rated power of the unit, equipment operation safety parameters and coal quality characteristic parameters are obtained; determining a load section based on the current load of the unit and the rated power of the unit, and dividing a differentiation interval based on the load section and the AGC operation mode; constructing a broken line function algorithm model, taking a deep adjustment mode identifier as input, setting first reference variable load rates of different differentiation intervals, inputting the coal quality characteristic parameters to obtain a second reference variable load rate, obtaining a first deviation value according to a preset multi-dimensional safety threshold value, and obtaining a second deviation value according to a preset multi-dimensional safety threshold value; the first deviation value is the deviation between a main steam pressure actual value and a main steam pressure set value, and the first deviation value is used as a constraint condition, so that the technical problem that the conventional AGC control cannot adapt to different working conditions of different load sections and an AGC mode due to the adoption of a fixed variable load rate, and the adjustment rate is difficult to effectively improve is solved.

Description

Technical Field

[0001] This invention relates to the field of power system automation control technology, and in particular to a unit variable rate control method and system based on main gas pressure prediction. Background Technology

[0002] With the global trend towards cleaner energy structures, new energy power generation technologies such as wind power and photovoltaics have been developed and grid-connected on a large scale. These new energy power generation technologies are significantly affected by natural conditions, exhibiting inherent intermittency and volatility, leading to a continuous widening of the peak-to-valley load difference in the power grid and exacerbating frequency fluctuations. Simultaneously, the replacement of traditional thermal power by new energy sources has reduced the rotational inertia of the power system, decreased frequency stability, and dramatically increased the demand for frequency and peak regulation resources. Against this backdrop, the role of thermal power units has transformed from a traditional basic power supply to a peak-shaving, frequency-regulating, and stabilizing power source, requiring frequent participation in deep peak-shaving operations. Load fluctuation frequencies have upgraded from daily regulation to hourly or even minute-level adjustments, with units operating in a constant state of frequent load changes and transient processes. This places higher demands on the regulation performance of the AGC (Automatic Generation Control) systems of thermal power units.

[0003] Currently, in the field of AGC control for thermal power units, the existing technical solution is a combination of feedforward and PID control technology. This technology is a classic basic solution adapted to grid load commands. Its core is to balance load response speed and operating parameter stability through a combination of coarse adjustment by the feedforward channel and fine adjustment by the PID feedback channel. The specific working process is as follows: after the grid issues an AGC load command, the feedforward channel immediately calculates the initial fuel quantity and feedwater flow commands based on a static model, quickly pushing the unit load towards the target value; simultaneously, the PID channel monitors the main steam pressure and the deviation between the actual load and the set value in real time, calculates the correction amount through the PID algorithm, and fine-tunes the feedforward command. The final control command is the superposition of the feedforward coarse adjustment command and the PID correction command, driving the boiler and turbine actuators to operate. However, the above-mentioned existing technical solutions and traditional AGC control methods have problems, specifically as follows: In existing technologies, AGC control mostly adopts a fixed variable load rate. This static parameter setting mode is difficult to adapt to the operating conditions of different load segments and operating modes. At high load segments, a fixed low-speed regulation leads to a slow response of the unit to grid load commands, resulting in a low regulation rate index, a core performance indicator of AGC, and affecting the revenue from frequency regulation ancillary services. At low load segments, a fixed high-speed regulation easily causes large fluctuations in main steam pressure, threatening equipment safety. Changes in coal type can cause significant differences in boiler response characteristics, resulting in large fluctuations in the boiler's pure delay time. Existing technologies lack a rate control mechanism that is deeply linked to equipment safety status. Excessive load change rate can lead to excessive thermal stress in key components such as turbine cylinders and rotors, seriously affecting equipment lifespan. Furthermore, maintaining a fixed rate regulation under conditions such as prolonged continuous load changes, excessive main steam pressure, and abnormal drum water levels easily leads to equipment failure risks.

[0004] Therefore, a variable rate control method and system for generator units based on main gas pressure prediction is needed to solve the technical problem that traditional AGC control, which uses a fixed variable load rate, cannot adapt to the different operating conditions of different load segments and AGC modes, and thus cannot effectively improve the regulation rate. Summary of the Invention

[0005] This application provides a unit variable rate control method and system based on main gas pressure prediction, which solves the technical problem that the traditional AGC control using a fixed variable load rate cannot adapt to the different working conditions of different load segments and AGC modes in the prior art, and achieves a balance between AGC regulation performance and equipment operation safety under all working conditions.

[0006] In a first aspect, embodiments of this application provide a unit variable rate control method based on main gas pressure prediction, comprising the following steps: S1. Obtain the current load of the unit, the rated power of the unit, the equipment operating safety parameters, and the coal quality characteristic parameters; S2. Determine the load segment based on the current load and rated power of the unit, and divide the differentiated intervals based on the load segment and the AGC operation mode. The load segment is the unit load interval divided according to the proportion of the rated power of the unit. S3. Construct a piecewise linear function algorithm model, take the deep adjustment mode identifier as input, set the first benchmark load rate for different differentiated intervals, input the coal quality characteristic parameters to obtain the second benchmark load rate, the AGC operation mode is the operation mode in which the unit receives load adjustment instructions, and the deep adjustment mode identifier is the identifier information of the unit in deep peak shaving operation mode. S4. Based on the preset multi-dimensional safety threshold, obtain the first deviation value, which is the deviation between the actual value of the main steam pressure and the set value of the main steam pressure. Use the first deviation value as a constraint condition and use the piecewise linear function algorithm model to perform a safety speed limit correction on the second reference variable load rate to obtain the safety reference rate. S5. Based on the safety baseline rate, plan the load adjustment path. The load adjustment process includes a rapid response stage, a regular adjustment stage, and a rapid convergence stage. The main steam pressure prediction result is obtained by calling the main steam pressure prediction model. Based on the main steam pressure prediction result, a differentiated rate strategy is obtained, and load adjustment is performed to achieve the load target value of the AGC command.

[0007] Furthermore, the equipment operation safety parameters include turbine wall temperature, steam drum water level, and continuous load variation duration, and the coal quality characteristic parameters are the boiler pure delay time corresponding to the actual coal type; After obtaining the current load, rated power, equipment operating safety parameters, and coal quality characteristics of the unit, preprocessing is required. This preprocessing includes: removing abnormal data exceeding a preset reasonable range; and smoothing the actual values ​​of turbine wall temperature, steam drum water level, and main steam pressure using a moving average algorithm. The smoothing formula is as follows: Where X represents the actual value of turbine wall temperature, steam drum water level or main steam pressure, k is the current sampling time, and n is a preset sliding window size positive integer.

[0008] Furthermore, the load segment is specifically divided into a first load interval, a second load interval, and a third load interval. The first load interval is between the first and second percentages of the unit's current load relative to its rated power. The second load interval is between the second and third percentages of the unit's current load relative to its rated power. The third load interval is where the unit's current load is at least the third percentage of its rated power, and the first percentage is less than the second percentage, and the second percentage is less than the third percentage. The AGC operation mode includes a first mode and a second mode. The first mode is the operation mode in which the unit receives real-time load adjustment instructions from the power grid and responds quickly. The second mode is the operation mode in which the unit operates smoothly according to a preset load curve. The differentiated zones are the first load interval under the first mode, the second load interval under the first mode, the third load interval under the first mode, and the full load interval under the second mode. Each differentiated interval corresponds to a unique load segment and AGC operation mode combination.

[0009] Furthermore, the method for setting the first reference variable load rate includes: S31. In the first mode, the first reference load change rate of the third load range is the fourth preset ratio of the rated power. In the first mode, the first reference load change rate of the second load range is the fifth preset ratio of the rated power. In the first mode, the first reference load change rate of the first load range is the sixth preset ratio of the rated power. The first reference load change rate in the second mode full load range is the seventh preset ratio of the rated power. And satisfy > > > The seventh preset ratio The rate of adjustment for the boiler drum must not be lower than the standard regulation rate specified by the power grid. S32. When the deep adjustment mode is identified as deep peak shaving condition, the first reference load rate of each differentiated interval is set according to the eighth preset ratio. The reduced rate, i.e., the first base variable load rate after the reduction, is r′=r×(1- ), where r is the first baseline load change rate of the corresponding interval before the adjustment. This is a preset scaling factor.

[0010] Furthermore, the second benchmark variable load rate is obtained through coal quality adaptive correction, the correction method including: S33. The preset boiler pure delay time corresponding to the designed coal type is: The actual boiler pure delay time corresponding to the coal type is The first benchmark variable load rate for each differentiated interval is By correcting the formula The formula is dynamically adjusted and corrected as follows: ,in, This is the second reference variable load rate.

[0011] Furthermore, the preset multi-dimensional security thresholds include: S41. Main steam pressure allowable deviation threshold ΔP, wall temperature upper limit threshold The allowable deviation threshold ΔH for steam drum water level and the threshold for the longest continuous variable load. The safety speed limit correction needs to be combined with the equipment's operating safety parameters, including: S42. If the duration of continuous load variation reaches the threshold for the longest continuous load variation period. The first correction factor is used. Perform rate correction; S43. Under reduced load conditions, if the actual value of the main steam pressure exceeds the sum of the main steam pressure setpoint and the allowable deviation threshold ΔP of the main steam pressure, the second correction coefficient shall be applied. If the first deviation exceeds the allowable deviation threshold ΔP for the main steam pressure, a third correction factor is applied. Perform rate correction; S44. If the turbine wall temperature reaches the upper limit threshold... The fourth correction factor is adopted. Perform rate correction; S45. If the steam drum water level exceeds the allowable deviation threshold ΔH, the fifth correction factor shall be applied. Perform rate correction; The safe reference rate is: and safe reference rate The minimum preset rate ratio is not lower than the rated power.

[0012] Furthermore, the first correction coefficient Second correction factor Third correction factor Fourth correction factor and the fifth correction factor All are preset positive numbers less than 1, and satisfy the following conditions: < < < = .

[0013] Furthermore, the rapid response phase includes: S51. Calculate the second deviation value ,in The target load value for the AGC command. This represents the current load of the generating unit. S52. If the second deviation value Not less than the preset deviation threshold, by the first multiple Safety reference rate Perform load adjustment until the load change reaches the preset change amount; S53. If the main steam pressure change rate exceeds the preset change rate threshold, adjust the adjustment rate to a second multiple. Safety reference rate ; S54. If the second deviation value If the deviation is less than the preset deviation threshold, it directly enters the fast convergence phase. ,and , All are preset positive numbers.

[0014] Furthermore, the routine adjustment phase includes: S55. After completing the rapid response phase, record the unit load at the end of this phase. The third deviation value is calculated as follows: ; S56. At a safe reference rate Continuous load regulation is performed, and the formula for calculating load changes during the regulation process is as follows: ,in For any given time, the unit load, Adjust the duration for this phase. For the sign function, increment by 1 for load increase and decrement by 1 for load decrease; S57. Collect equipment operating safety parameters and actual main steam pressure values, repeat the safety speed limit correction process, and update the safety reference rate. And replace the current adjustment rate; S58. When the third deviation value When the deviation is less than or equal to the preset convergence deviation threshold, the current adjustment phase ends and the fast convergence phase begins.

[0015] Furthermore, the rapid convergence phase includes: S59. Record the unit load after the routine adjustment phase ends. Calculate the fourth deviation value ; S510. The main steam pressure prediction model is constructed based on the actual value of the main steam pressure, the first deviation value, and the load adjustment trend. The main steam pressure prediction model is called to obtain the main steam pressure prediction result, and the convergence rate is adjusted based on the main steam pressure prediction result. ,include: S511. If the actual value of the main steam pressure is greater than the set value of the main steam pressure, set... If the actual value of the main steam pressure is less than or equal to the set value of the main steam pressure, the setting... ; S512. If the actual value of the main steam pressure is less than the set value of the main steam pressure, the setting... If the actual value of the main steam pressure is greater than or equal to the set value of the main steam pressure, then set... ,in > ,and , All are positive numbers not less than 1; S513. Convergence rate as a whole Perform convergence adjustment, adjustment duration Adjusting the afterload ; S514. If the difference between the adjusted load and the target load value of the AGC command is less than the preset accuracy threshold, the adjustment ends.

[0016] Secondly, a unit variable rate control system based on main gas pressure prediction includes: The data acquisition module is configured to acquire the unit's current load, rated power, equipment operating safety parameters, and coal quality characteristic parameters; The interval division module is configured to determine the load segment based on the current load of the unit and the rated power of the unit, and to divide the differentiated intervals based on the load segment and the AGC operation mode. The load segment is the unit load interval divided according to the proportion of the rated power of the unit. The benchmark rate construction module is configured to construct a piecewise linear function algorithm model, take the deep adjustment mode identifier as input, set the first benchmark variable load rate for different differentiated intervals, and input the coal quality characteristic parameters to obtain the second benchmark variable load rate. The AGC operation mode is the operation mode in which the unit receives load adjustment instructions, and the deep adjustment mode identifier is the identifier information of the unit in deep peak shaving operation. The safety rate correction module is configured to obtain a first deviation value based on a preset multi-dimensional safety threshold. The first deviation value is the deviation between the actual value of the main steam pressure and the set value of the main steam pressure. The first deviation value is used as a constraint condition, and the second reference variable load rate is corrected for safety speed limit using the piecewise linear function algorithm model to obtain the safety reference rate. The phased adjustment module is configured to plan a load adjustment path based on the safety baseline rate. The load adjustment process includes a rapid response phase, a regular adjustment phase, and a rapid convergence phase. The main steam pressure prediction result is obtained by calling the main steam pressure prediction model. Based on the main steam pressure prediction result, a differentiated rate strategy is obtained, and load adjustment is performed to achieve the load target value of the AGC command.

[0017] Thirdly, the present invention provides a computer-readable storage medium storing a plurality of instructions adapted for loading and execution by a processor of a terminal device of the unit variable rate control method based on main gas pressure prediction.

[0018] Fourthly, the present invention provides a terminal device, including a processor and a computer-readable storage medium, wherein the processor is used to implement various instructions; the computer-readable storage medium is used to store multiple instructions, the instructions being adapted to be loaded by the processor and executed by the processor for the unit variable rate control method based on main gas pressure prediction.

[0019] One or more technical solutions provided in the embodiments of this application have at least the following technical effects or advantages: 1. By adopting differentiated intervals based on load segment and AGC mode, configuring a gradient first benchmark variable load rate for each interval, and combining the deep adjustment mode to indicate the reduction of the execution rate, the technical problem that the fixed variable load rate in the existing technology cannot adapt to different operating conditions, resulting in slow response in the high load segment and parameter fluctuation in the low load segment is effectively solved. Thus, the AGC regulation rate index and operation stability of the unit under all operating conditions are accurately balanced, and the technical effect of improving the frequency regulation ancillary service benefits is improved.

[0020] 2. By adopting the technical means of introducing coal quality characteristic parameters and constructing a coal quality adaptive correction formula to dynamically adjust the benchmark variable load rate, the technical problem that fixed control parameters in the existing technology cannot adapt to coal quality fluctuations, resulting in mismatch of boiler response characteristics and reduced adjustment accuracy is effectively solved. Thus, the real-time adaptation of the rate to the actual response characteristics of the boiler is achieved, avoiding the technical effect of response lag or overshoot risk.

[0021] 3. By adopting a multi-dimensional safety threshold that integrates the allowable deviation of main steam pressure, the upper limit of wall temperature, the allowable deviation of steam drum water level, and the maximum continuous load variation time, and combining it with equipment operating safety parameters, the technology uses differentiated correction coefficients to perform multiple safety speed limit corrections. Therefore, it effectively solves the technical problem in the existing technology where the speed control and equipment safety monitoring are disconnected, which can easily lead to safety risks such as excessive thermal stress in the turbine, large fluctuations in main steam pressure, and abnormal steam drum water level. This achieves the dual guarantee of equipment safety and regulation performance, reducing equipment wear and extending the service life of the unit.

[0022] 4. By adopting a technical approach that divides the load regulation process into three stages—rapid response, conventional regulation, and rapid convergence—and configuring differentiated rate strategies for each stage based on the main steam pressure prediction results, the technical problem of not being able to simultaneously consider AGC response time, regulation rate, and control accuracy in existing technologies is effectively solved, thereby achieving the technical effect of improving the unit's frequency regulation efficiency. Attached Figure Description

[0023] Figure 1 This is a flowchart of the unit variable rate control method based on main gas pressure prediction in Embodiment 1 of this application; Figure 2 This is the final optimized unit load command diagram in Embodiment 1 of this application; Figure 3 This is a module diagram of Embodiment 2 of this application. Detailed Implementation

[0024] This application aims to address the core technical problems of traditional thermal power unit AGC control, which uses a fixed variable load rate under the background of large-scale grid connection of new energy sources. These problems include the inability to adapt to different load segments and AGC operating modes, a lack of adaptive capability to coal quality fluctuations, a disconnect between equipment safety monitoring and rate control, and difficulty in meeting grid assessment requirements. This application constructs a technical solution involving multi-range reference rate setting, coal quality adaptive correction, multiple safety speed limits, and three-stage intelligent regulation. This achieves precise adaptation and dynamic optimization of the unit's variable load rate, ensuring equipment operation safety while significantly improving AGC regulation performance, fully meeting the transformation needs of thermal power peak shaving and frequency regulation.

[0025] The core technical solution of this application is based on differentiated load range division. Load segments are determined according to the ratio of the unit's current load to its rated power. Combined with AGC (Automatic Guided Vehicle) operation modes—namely, the first and second modes—uniquely corresponding differentiated load ranges are defined. A piecewise linear function algorithm model is used to configure a gradient-based first benchmark load rate for each range, and the rate is adjusted downwards according to the deep-adjustment mode identifier, thus adapting to the adjustment needs of different operating conditions from the source. Simultaneously, an adaptive correction mechanism is constructed by introducing coal quality characteristic parameters to dynamically adjust the benchmark load rate to match the actual response characteristics of the boiler, solving the adjustment deviation problem caused by coal quality fluctuations.

[0026] To achieve both safety and performance assurance, this application designs a multi-level speed limit correction mechanism that integrates multi-dimensional safety thresholds and equipment operating safety parameters. It deeply links safety constraints such as continuous load variation duration, main steam pressure deviation, turbine wall temperature, and drum water level with rate control. Through differentiated correction coefficients, targeted speed limits are applied to high-risk operating conditions to avoid equipment damage and safety risks caused by excessively high load change rates. Based on this, the load regulation process is divided into three stages: rapid response, conventional regulation, and rapid convergence. Differentiated rate strategies are configured for each stage based on main steam pressure prediction results, balancing the requirements of AGC response time, regulation rate, and control accuracy.

[0027] Through the synergistic implementation of the above technical solutions, this application effectively overcomes the limitations of traditional fixed-rate control, achieves a precise balance between AGC regulation rate indicators and operational stability under all operating conditions, improves the unit's adaptability to coal quality fluctuations, and reduces equipment operation risks and losses.

[0028] To better understand the above technical solutions, the following will provide a detailed explanation of the technical solutions in conjunction with the accompanying drawings and specific implementation methods.

[0029] Example 1 Reference Figure 1 A variable rate control method for generator units based on main gas pressure prediction includes the following steps: S1. Obtain the current load of the unit, the rated power of the unit, the equipment operating safety parameters, and the coal quality characteristic parameters; The equipment operation safety parameters include turbine wall temperature, steam drum water level and continuous load variation duration, and the coal quality characteristic parameters are the boiler pure delay time corresponding to the actual coal type. After obtaining the current load, rated power, equipment operating safety parameters, and coal quality characteristics of the unit, preprocessing is required. This preprocessing includes: removing abnormal data that exceeds a preset reasonable range. The 3σ criterion is used for outlier removal. Specifically, the mean μ and standard deviation σ of each parameter are calculated first, and data that exceeds the range of [μ-3σ, μ+3σ] are identified as outliers and removed. The reasonable fluctuation range of the actual main steam pressure can be set with reference to the power grid operation specifications, and the reasonable range of the turbine wall temperature and steam drum water level needs to be determined in conjunction with the unit design parameters.

[0030] The actual values ​​of turbine wall temperature, steam drum water level, and main steam pressure are smoothed using a moving average algorithm. The smoothing formula is as follows: Where X represents the actual value of turbine wall temperature, steam drum water level or main steam pressure, k is the current sampling time, and n is a preset sliding window size positive integer. This preprocessing step can effectively filter out the interference caused by instantaneous fluctuations, making the parameter change trend more consistent with the actual operating state of the unit, and providing reliable data support for subsequent reference rate construction and safety correction.

[0031] S2. Determine the load segment based on the current load and rated power of the unit, and divide the differentiated intervals based on the load segment and the AGC operation mode. The load segment is the unit load interval divided according to the proportion of the rated power of the unit. The load segment is specifically divided into a first load interval, a second load interval, and a third load interval. The first load interval is between the first and second percentages of the unit's current load relative to its rated power. The second load interval is between the second and third percentages of the unit's current load relative to its rated power. The third load interval is where the unit's current load is at least the third percentage of its rated power, and the first percentage is less than the second percentage, and the second percentage is less than the third percentage. The AGC operation mode includes a first mode and a second mode. The first mode is the operation mode in which the unit receives real-time load adjustment instructions from the power grid and responds quickly. The second mode is the operation mode in which the unit operates smoothly according to a preset load curve. The differentiated zones are the first load interval under the first mode, the second load interval under the first mode, the third load interval under the first mode, and the full load interval under the second mode. Each differentiated interval corresponds to a unique load segment and AGC operation mode combination.

[0032] The load segment division is based on the ratio of the unit's current load to its rated power, aiming to accommodate the differences in the unit's regulation capacity under different load ranges. Specifically, the division is as follows: the first ratio is preferably 30%, the second ratio is preferably 40%, and the third ratio is preferably 50%. Correspondingly, the first load range is between 30% and 40% of the unit's current load as rated power, the second load range is between 40% and 50%, and the third load range is above 50%. Taking a 330MW rated power unit as an example, the first load range corresponds to 99MW to 132MW, the second load range corresponds to 132MW to 165MW, and the third load range corresponds to above 165MW. This division method highly aligns with the actual operational requirements of deep peak-shaving conditions.

[0033] In the AGC operation mode, the first mode corresponds to the R mode, i.e., the real-time response mode. In this mode, the unit needs to quickly respond to the real-time load adjustment commands issued by the grid and adapt to the grid frequency regulation requirements. The second mode corresponds to the O mode, i.e., the planned operation mode. In this mode, the unit operates smoothly according to the preset load curve, and the adjustment demand is relatively mild. The division of the differentiated intervals is based on the load segment and the AGC operation mode, forming four uniquely corresponding differentiated intervals: the first load interval in the R mode, the second load interval in the R mode, the third load interval in the R mode, and the full load interval in the O mode.

[0034] The core purpose of this differentiated interval division is to configure appropriate benchmark rates for the adjustment needs of different operating scenarios: In R mode, priority should be given to ensuring the adjustment rate meets the grid frequency regulation assessment, so a gradient rate is configured according to the load segment from high to low; in O mode, priority should be given to ensuring operational stability, so a relatively gentle uniform rate is configured. Each interval corresponds to clear operating conditions and adjustment targets, laying the foundation for the accurate setting of subsequent benchmark rates. When the deep adjustment mode is identified as a deep peak shaving condition, the first benchmark load change rate of each differentiated interval is reduced by a preset ratio, preferably 20%~30%, to adapt to the increased difficulty in maintaining unit control parameters under deep peak shaving conditions and to avoid safety risks caused by excessively high rates.

[0035] S3. Construct a piecewise linear function algorithm model, take the deep adjustment mode identifier as input, set the first benchmark load rate for different differentiated intervals, input the coal quality characteristic parameters to obtain the second benchmark load rate, the AGC operation mode is the operation mode in which the unit receives load adjustment instructions, and the deep adjustment mode identifier is the identifier information of the unit in deep peak shaving operation mode. A piecewise linear function algorithm model is constructed, which adopts a piecewise linear mapping architecture. Its core function is to establish a unique mapping relationship between differentiated intervals and the baseline variable load rate, ensuring smooth and abrupt rate adjustments during operating condition switching and avoiding oscillations in unit operating parameters caused by sudden rate changes. The model's input parameters include the deep adjustment mode identifier, AGC operating mode, and the unit's current load percentage information. The output is a baseline variable load rate adapted to the current operating condition. By pre-setting piecewise function coefficients, precise invocation and seamless switching of rates in different intervals are achieved, providing stable and reliable basic rate support for subsequent coal quality adaptive correction and safe speed limit correction, ensuring the continuity and accuracy of the entire control strategy.

[0036] The method for setting the first reference variable load rate includes: S31. In the first mode, the first reference load change rate of the third load range is the fourth preset ratio of the rated power. In the first mode, the first reference load change rate of the second load range is the fifth preset ratio of the rated power. In the first mode, the first reference load change rate of the first load range is the sixth preset ratio of the rated power. The first reference load change rate in the second mode full load range is the seventh preset ratio of the rated power. And satisfy > > > The seventh preset ratio The rate of adjustment for the boiler drum must not be lower than the standard regulation rate specified by the power grid. The first benchmark load change rate is set based on grid assessment standards, unit design regulation capacity, and operating characteristics under different conditions. Each preset ratio is configured in a tiered manner to form a rate system adapted to the operating conditions. Among these, the fourth preset ratio... The preferred ratio is 2.0%, the fifth preset ratio. The preferred ratio is 1.8%, the sixth preset ratio. The preferred ratio is 1.6%, the seventh preset ratio. The preferred value is 1.5%, and it must be strictly followed. > > > The gradient relationship. Setting it to 1.5% is in line with the standard regulation rate requirements for boiler drums stipulated by the power grid, ensuring that the minimum regulation rate of the unit is not lower than the assessment baseline; to The gradient design stems from the fact that the high-load section of the unit has high combustion efficiency and strong steam-water system stability, which can be adapted to a higher regulation rate to improve the AGC regulation rate index. The low-load section of the unit has weakened combustion stability and reduced parameter regulation margin, so the rate needs to be reduced to avoid safety risks such as main steam pressure fluctuations and combustion instability.

[0037] Taking a 330MW rated power unit as an example, the first benchmark load change rate for each zone is specifically as follows: For the third load zone (>50% rated power, i.e., >165MW) under the first mode... Corresponding to 6.6MW / min (330MW×2.0%), the second load range (40%-50% of rated power, i.e., 132MW-165MW) under the first mode. Corresponding to 5.94MW / min (330MW×1.8%), the first load range (30%-40% of rated power, i.e., 99MW-132MW) under the first mode. Corresponding to 5.28MW / min (330MW×1.6%), the second mode full load range This corresponds to 4.95 MW / min (330 MW × 1.5%). This parameter configuration has been verified through engineering practice, and can maximize the AGC regulation rate index while meeting equipment safety constraints, thus meeting the actual operational needs of thermal power peak shaving and frequency regulation.

[0038] S32. When the deep adjustment mode is identified as deep peak shaving condition, the first reference load rate of each differentiated interval is set according to the eighth preset ratio. The reduced rate, i.e., the first base variable load rate after the reduction, is r′=r×(1- ), where r is the first baseline load change rate of the corresponding interval before the adjustment. This is a preset scaling factor.

[0039] Eighth preset ratio The preferred value is 0.2-0.3 (i.e., 20%-30%), which is set based on the operating characteristics of deep peak shaving conditions. During deep peak shaving, the unit load is usually in a low load range below 30% of the rated power. The combustion stability and steam-water system balancing ability are significantly weaker than in conventional conditions, and the difficulty of maintaining the stability of core parameters such as main steam pressure and steam drum water level increases significantly. When the deep shaving mode is identified as a deep peak shaving condition, the first reference load change rate of each differentiated range is reduced according to the following formula: r′=r×(1− In the formula, r is the first baseline load rate of the corresponding interval before the reduction, and r′ is the first baseline load rate after the reduction. For example, when When the value is 0.2, the reduced rate in the third load range under the first mode is 5.28 MW / min (6.6 MW / min × 0.8), and the reduced rate in the full load range under the second mode is 3.96 MW / min (4.95 MW / min × 0.8). This reduction mechanism can effectively reduce the rate risk under deep peak shaving conditions, avoid problems such as large fluctuations in main steam pressure, unstable combustion, or even flameout caused by excessively high rates, while still maintaining a regulation capacity that is not lower than the grid assessment requirements, thus achieving a balance between safety and performance under deep peak shaving conditions.

[0040] The second benchmark variable load rate is obtained through coal quality adaptive correction, and the correction method includes: S33. The preset boiler pure delay time corresponding to the designed coal type is: The actual boiler pure delay time corresponding to the coal type is The first benchmark variable load rate for each differentiated interval is By correcting the formula The formula is dynamically adjusted and corrected as follows: ,in, This is the second reference variable load rate.

[0041] The core purpose of the second-benchmark variable load rate adaptive correction for coal quality is to eliminate the impact of coal quality fluctuations on the adjustment accuracy, so that the benchmark rate matches the actual response characteristics of the boiler in real time. This includes the boiler's pure delay time corresponding to the design coal type. For the rated parameters specified in the unit design documents, the preferred method is... =60 seconds; actual boiler pure delay time corresponding to the actual coal type. The fuel quantity adjustment command is dynamically acquired by monitoring the boiler combustion response process in real time. Specifically, it is implemented by issuing a fixed-amplitude fuel quantity adjustment command to the boiler every 5 minutes at a preset cycle, and recording the time interval from the issuance of the command to the occurrence of a significant change in the main steam pressure. This time interval is the boiler pure delay time corresponding to the actual coal type. This ensures timely and accurate detection of differences in boiler response characteristics caused by changes in coal quality.

[0042] The correction formula employs a linear proportional adjustment mechanism, specifically: In the formula, This represents the first baseline variable load rate for each differentiated interval, including the rate r' after adjustment under deep adjustment mode. This represents the second baseline variable load rate after adaptive correction for coal quality. The design principle of this formula is that the boiler's pure delay time is negatively correlated with the coal combustion efficiency, and the actual pure delay time... The longer the time, the lower the coal combustion efficiency and the slower the boiler response. At this time, it is necessary to reduce the reference load rate simultaneously to avoid the adjustment command from becoming disconnected from the actual boiler response due to the excessively fast rate, which may lead to problems such as increased main steam pressure deviation and adjustment overshoot.

[0043] Taking the third load range of the first mode of a 330MW unit as an example, if the deep adjustment mode is identified as a non-deep peak shaving condition, the first benchmark load change rate is... =6.6MW / min, designed coal type =60 seconds, actual monitoring showed τ=120 seconds (deterioration in coal quality caused slow boiler response), therefore the corrected second reference load rate =6.6MW / min×(60 / 120)=3.3MW / min; If the actual monitoring shows τ=40 seconds (the improved coal quality leads to a faster boiler response), then =6.6MW / min×(60 / 40)=9.9MW / min. This dynamic correction achieves precise matching between the rate and the actual response characteristics of the boiler, ensuring the stability and accuracy of regulation under different coal quality conditions.

[0044] S4. Based on the preset multi-dimensional safety threshold, obtain the first deviation value, which is the deviation between the actual value of the main steam pressure and the set value of the main steam pressure. Use the first deviation value as a constraint condition and use the piecewise linear function algorithm model to perform a safety speed limit correction on the second reference variable load rate to obtain the safety reference rate. By deeply integrating multi-dimensional safety constraints with the benchmark load change rate, and through multiple safety rate limit corrections, the system avoids equipment safety risks caused by inappropriate rates, while ensuring that the corrected rate still meets the grid regulation requirements. The correction process is based on a logical extension of the piecewise linear function algorithm model. It uses the first deviation value and equipment operating safety parameters as constraints, and dynamically adjusts the second benchmark load change rate through differentiated correction coefficients, ultimately outputting a safe benchmark rate that balances safety and adaptability.

[0045] The preset multi-dimensional security thresholds include: S41. Main steam pressure allowable deviation threshold ΔP, wall temperature upper limit threshold The allowable deviation threshold ΔH for steam drum water level and the threshold for the longest continuous variable load. The aforementioned safety speed limit correction needs to be combined with the equipment's operating safety parameters. The preset multi-dimensional safety thresholds are all determined based on unit design parameters, grid operation specifications, and engineering practice experience to ensure the scientific and practical nature of the threshold settings. Among them, the allowable deviation threshold ΔP for main steam pressure is preferably 0.5 MPa. This value not only fits the normal fluctuation range of the main steam pressure in the boiler drum but also effectively avoids disturbances to the steam-water system caused by excessive deviation; the upper limit threshold for wall temperature... The optimal temperature is 535℃, set with reference to the heat resistance limits of key components such as the turbine cylinder and rotor, to avoid excessive thermal stress; the allowable deviation threshold ΔH for the steam drum water level is preferably ±50mm, which complies with the safety specifications for steam drum boiler water level control and prevents water shortage or overfilling accidents caused by abnormal water levels; the maximum continuous load variation time threshold is... The 30-minute timeframe was selected based on the fatigue life constraints of the unit's continuous variable load operation, thus avoiding equipment damage caused by long-term transient operation.

[0046] The above thresholds can be flexibly adjusted according to differences in unit rated power, boiler type, etc. For example, the allowable deviation threshold ΔP for main steam pressure of a 600MW unit can be set to 0.6MPa, and the upper limit threshold for wall temperature can be set to... Maintaining a constant temperature of 535℃ ensures that the threshold adapts to the operating characteristics of different units. The coordinated setting of multi-dimensional safety thresholds achieves comprehensive coverage of key safety dimensions such as main steam pressure, equipment temperature, steam-water system, and operating time, providing clear constraints for rate correction.

[0047] S42. If the duration of continuous load variation reaches the threshold for the longest continuous load variation period. The first correction factor is used. Perform rate correction; The duration of continuous load change is tracked in real time by a timer. The timer starts when the unit executes the load change command and resets to zero when the load reaches the target value of the AGC command or when the load change operation stops. The timer continues until it reaches the maximum continuous load change time threshold. This indicates that the unit is in a long-term transient operating state, and the risk of component fatigue wear is increased. At this time, the first correction factor is used. Perform rate correction. The preferred value is 0.8. This correction factor setting reduces the rate to minimize equipment wear without excessively suppressing regulation capabilities, ensuring the unit can still continuously respond to grid load commands. If the continuous load change duration does not reach... If so, the dimension correction will not be initiated, and the rate will remain unchanged.

[0048] S43. Under reduced load conditions, if the actual value of the main steam pressure exceeds the sum of the main steam pressure setpoint and the allowable deviation threshold ΔP of the main steam pressure, the second correction coefficient shall be applied. If the first deviation exceeds the allowable deviation threshold ΔP for the main steam pressure, a third correction factor is applied. Perform rate correction; Under reduced load conditions, the main steam pressure is prone to exceeding the limit, therefore a dual pressure speed limiting logic needs to be set. The first level of speed limiting: when the actual main steam pressure exceeds the sum of the main steam pressure setpoint and the allowable deviation threshold ΔP, it indicates that the pressure is approaching the danger threshold, representing the highest risk level, and a second correction factor is applied. Perform rate correction. The preferred value is 0.5, which significantly reduces the rate to suppress further pressure increases; the second speed limit: when the absolute value of the first deviation exceeds the allowable deviation threshold ΔP of the main steam pressure but does not meet the first speed limit condition, it indicates that the pressure deviation has exceeded the safe range, the risk level is medium, and a third correction coefficient is used. Perform rate correction. The preferred value is 0.6. This dual speed limiting logic can precisely adjust the rate according to the pressure risk level, avoiding large pressure fluctuations when the load is reduced.

[0049] S44. If the turbine wall temperature reaches the upper limit threshold... The fourth correction factor is adopted. Perform rate correction; The turbine wall temperature is collected in real time by temperature sensors distributed in key components such as the cylinder and rotor, and the maximum value monitored by each sensor is used as the criterion for judgment. When this maximum value reaches the upper limit threshold of the wall temperature... At 535℃, it indicates that the component is close to its heat resistance limit. Continuing to maintain the original rate of heat treatment may lead to excessive thermal stress. At this point, the fourth correction factor should be used. Perform rate correction. The preferred value is 0.7. This correction factor balances safe cooling with continuous regulation, ensuring the unit can still respond slowly to load commands while reducing the rate of cooling to decrease heat load input, thus avoiding fluctuations in other parameters caused by a sudden drop in rate. If the wall temperature does not reach... If not, then the dimension correction will not be initiated.

[0050] S45. If the steam drum water level exceeds the allowable deviation threshold ΔH, the fifth correction factor shall be applied. Perform rate correction; The steam drum water level is monitored in real time by a water level transmitter, and the deviation between the monitored value and the set steam drum water level is used as the basis for judgment. When this deviation exceeds the allowable deviation threshold ΔH (±50mm) for the steam drum water level, it indicates that the steam-water system balance has been disrupted, and there is a risk of water shortage or overfilling. In this case, the fifth correction factor is used. Perform rate correction. The preferred value is 0.8. If the water level deviation is within the range of ΔH, then this dimensional correction will not be initiated.

[0051] The safe reference rate is: and safe reference rate The minimum preset rate ratio is not lower than the rated power.

[0052] First correction coefficient Second correction factor Third correction factor Fourth correction factor and the fifth correction factor All are preset positive numbers less than 1, and satisfy the following conditions: < < < = .

[0053] In the formula, This means selecting the minimum value from all triggered correction factors as the final correction factor, ensuring the strictest speed limit is applied to the highest-risk operating conditions, and maximizing equipment safety. Each correction factor strictly meets... < < < = The relationship is 0.5 < 0.6 < 0.7 < 0.8 = 0.8. This relationship is based on the safety risk level settings for different working conditions: the risk of exceeding the upper limit of pressure during load reduction is the highest, and the speed limit is the strictest; the risk of wall temperature exceeding the limit is the second highest; the risk of continuous load change timeout is comparable to that of exceeding the limit of steam drum water level, and the speed limit is consistent.

[0054] Meanwhile, the safety reference rate The minimum preset rate ratio, which is not lower than the rated power, must be met. This ratio is preferably 1.0%. Taking a 330MW unit as an example, the minimum rate threshold is 3.3MW / min. This ensures that the corrected rate can still meet the minimum assessment requirements of the power grid for the boiler regulation rate and avoids the regulation capacity failing to meet the standard due to excessive speed limiting.

[0055] Taking a 330MW unit as an example, if the second reference load change rate =5.28MW / min, the duration of continuous load change triggered during operation reaches The correction factors for the two correction conditions are 30 minutes and excessive water level in the steam drum. =0.8、 =0.8, no other correction conditions were triggered ( , , If we consider it as 1), then min(0.8,1,1,1,0.8)=0.8, the safe reference rate. =5.28MW / min × 0.8 = 4.224MW / min. This rate is higher than the minimum threshold of 3.3MW / min, ensuring equipment safety while providing sufficient adjustment capability. If a load reduction pressure exceeding the upper limit is triggered simultaneously, =0.5), then min(0.8,0.5,1,1,0.8)=0.5, =5.28×0.5=2.64MW / min. At this point, it is necessary to determine whether it is lower than the minimum threshold. If it is lower, then execute at 3.3MW / min to ensure the balance between compliance and safety.

[0056] S5. Based on the safety baseline rate, plan the load adjustment path. The load adjustment process includes a rapid response stage, a regular adjustment stage, and a rapid convergence stage. The main steam pressure prediction result is obtained by calling the main steam pressure prediction model. Based on the main steam pressure prediction result, a differentiated rate strategy is obtained, and load adjustment is performed to achieve the load target value of the AGC command.

[0057] Reference Figure 2 The S5 step function is based on a safe baseline rate and achieves precise and efficient load regulation through a three-stage differentiated rate strategy, taking into account both grid assessment requirements and unit operational stability. During the regulation process, the main steam pressure prediction model provides predictive support for rate adjustments at each stage, ensuring that the rate strategy is accurately adapted to the main steam pressure change trend, ultimately enabling the unit load to quickly and stably reach the AGC command target value.

[0058] The rapid response phase includes: S51. Calculate the second deviation value ,in The target load value for the AGC command. The current load of the unit is used as the basis for calculation. The core purpose of this calculation is to quantify the difference between the current load and the target value, so as to provide a clear basis for the stage switching. When the difference is large, the response time needs to be shortened through the rapid response stage. When the difference is small, the convergence stage is directly entered to improve the regulation accuracy.

[0059] S52. If the second deviation value Not less than the preset deviation threshold, by the first multiple Safety reference rate Execute load regulation until the load change reaches the preset change amount; the preset deviation threshold is set based on the grid response time assessment requirements, and is preferably 10% of the unit's rated power; the preset change amount is preferably 5% of the unit's rated power, a first multiple. The preferred value is 1.5. Taking a 330MW unit as an example, the preset deviation threshold is 33MW, and the preset change is 16.5MW. When ≥33MW, use 1.5× The rate of adjustment is executed until the load change reaches 16.5MW. The purpose of this design is to meet the grid K3 response time index (time required for a 10% load change < 60 seconds) by rapidly adjusting at a rate exceeding the baseline when the load difference is large, thereby improving the AGC assessment score.

[0060] S53. If the main steam pressure change rate exceeds the preset change rate threshold, adjust the adjustment rate to a second multiple. Safety reference rate ; The rate of change of main steam pressure is calculated using the actual values ​​of main steam pressure at two consecutive sampling times. The calculation formula is as follows: In the formula, This represents the actual main steam pressure at the current sampling time. The value is the actual main steam pressure at the previous sampling time, and Δt is the sampling period, preferably 5 seconds.

[0061] The preset rate of change threshold is preferably 0.2 MPa / min, a second multiple thereof. Preferably 1.0. When When the pressure exceeds 0.2 MPa / min, it indicates that the main steam pressure fluctuates too rapidly, posing a risk of disturbance to the steam-water system. In this case, the regulating rate should be adjusted to 1.0 × By reducing the rate, further pressure fluctuations are suppressed, balancing response speed and operational stability.

[0062] S54. If the second deviation value If the deviation is less than the preset deviation threshold, it directly enters the fast convergence phase. ,and , All are preset positive numbers.

[0063] When the second deviation value If the load is less than the preset deviation threshold, it indicates that the current load is close to the target value, and the system can directly enter the rapid convergence phase without needing to go through the conventional adjustment phase. This design avoids unnecessary rate switching, reduces parameter oscillations during the adjustment process, improves load accuracy, and shortens the overall adjustment time. The relationship ensures that the rate priority in the rapid response phase is higher than the fluctuation suppression rate, taking into account both assessment requirements and safety constraints.

[0064] The routine adjustment phase includes: S55. After completing the rapid response phase, record the unit load at the end of this phase. The third deviation value is calculated as follows: This calculation is used to quantify the remaining load gap after a rapid response, providing a basis for determining rate maintenance and phase switching during the routine adjustment phase.

[0065] S56. At a safe reference rate Continuous load regulation is performed, and the formula for calculating load changes during the regulation process is as follows: ,in For any given time, the unit load, Adjust the duration for this phase. As a sign function, increasing the load by 1 and decreasing the load by 1 ensures that the load adjustment direction is consistent with the target value and that the rate remains stable at the safe reference rate. This is to avoid fluctuations in parameters such as main steam pressure and steam drum water level caused by rate fluctuations.

[0066] S57. Collect equipment operating safety parameters and actual main steam pressure values, repeat the safety speed limit correction process, and update the safety reference rate. The current regulating rate is replaced, and the actual values ​​of turbine wall temperature, drum water level, continuous load variation duration, and main steam pressure are re-acquired according to a preset cycle, preferably every 2 minutes. The multiple safety speed limit correction process of S4 is repeated to dynamically update the safety reference rate. It also replaces the current adjustment rate. This design constructs a dynamic closed-loop adjustment mechanism to ensure that the rate during the normal adjustment phase always adapts to changes in the equipment's safety status and operating parameters, avoiding safety risks or decreased adjustment accuracy caused by fluctuations in operating conditions.

[0067] S58. When the third deviation value When the deviation is less than or equal to the preset convergence deviation threshold, the current adjustment phase ends and the fast convergence phase begins.

[0068] The preset convergence deviation threshold is set based on the adjustment accuracy requirements, and is preferably 3% of the unit's rated power. Taking a 330MW unit as an example, this threshold is 9.9MW. When the load is ≤9.9MW, it indicates that the load is close to the target value, the normal adjustment phase ends, and the system enters the rapid convergence phase. This switching condition ensures the response efficiency of the normal phase while reserving a reasonable load range for precise adjustment in the convergence phase, avoiding premature entry into the convergence phase and resulting in excessively long adjustment time.

[0069] The rapid convergence phase includes: S59. Record the unit load after the routine adjustment phase ends. Calculate the fourth deviation value This deviation value provides a quantitative basis for the adjustment range during the rapid convergence phase, ensuring that the convergence rate is accurately matched with the difference between the remaining load and the convergence rate.

[0070] S510. The main steam pressure prediction model is constructed based on the actual value of the main steam pressure, the first deviation value, and the load adjustment trend. The main steam pressure prediction model is called to obtain the main steam pressure prediction result, and the convergence rate is adjusted based on the main steam pressure prediction result. The main steam pressure prediction model is constructed using a linear regression algorithm. Input parameters include the preprocessed actual main steam pressure value, the first deviation value, and the load adjustment trend. The output is the main steam pressure prediction result for the next 1-3 minutes. The model training process is based on historical unit operating data, and the model parameters are optimized using the least squares method. The model's function is to predict the main steam pressure change trend during load adjustment, providing a forward-looking basis for convergence rate adjustment, including: S511. If the actual value of the main steam pressure is greater than the set value of the main steam pressure, set... If the actual value of the main steam pressure is less than or equal to the set value of the main steam pressure, the setting... ; S512. If the actual value of the main steam pressure is less than the set value of the main steam pressure, the setting... If the actual value of the main steam pressure is greater than or equal to the set value of the main steam pressure, then set... ,in > ,and , All are positive numbers not less than 1; among them, The preferred value is 1.3. The preferred value is 1.0, which ensures rapid convergence under surplus operating conditions and stable regulation under critical operating conditions.

[0071] S513. Convergence rate as a whole Perform convergence adjustment, adjustment duration Adjusting the afterload ; S514. If the difference between the adjusted load and the load target value of the AGC command is less than the preset accuracy threshold, the adjustment ends. If it exceeds the threshold, return to S510 to re-call the main steam pressure prediction model and adjust. The convergence adjustment is then repeated until the accuracy requirements are met. This closed-loop verification mechanism ensures the accuracy of load regulation and meets the power grid AGC control assessment standards.

[0072] Secondly, referring to Figure 3 A variable-rate control system for a generator unit based on main gas pressure prediction, comprising: The data acquisition module is configured to acquire the unit's current load, rated power, equipment operating safety parameters, and coal quality characteristic parameters; The interval division module is configured to determine the load segment based on the current load of the unit and the rated power of the unit, and to divide the differentiated intervals based on the load segment and the AGC operation mode. The load segment is the unit load interval divided according to the proportion of the rated power of the unit. The benchmark rate construction module is configured to construct a piecewise linear function algorithm model, take the deep adjustment mode identifier as input, set the first benchmark variable load rate for different differentiated intervals, and input the coal quality characteristic parameters to obtain the second benchmark variable load rate. The AGC operation mode is the operation mode in which the unit receives load adjustment instructions, and the deep adjustment mode identifier is the identifier information of the unit in deep peak shaving operation. The safety rate correction module is configured to obtain a first deviation value based on a preset multi-dimensional safety threshold. The first deviation value is the deviation between the actual value of the main steam pressure and the set value of the main steam pressure. The first deviation value is used as a constraint condition, and the second reference variable load rate is corrected for safety speed limit using the piecewise linear function algorithm model to obtain the safety reference rate. The phased adjustment module is configured to plan a load adjustment path based on the safety baseline rate. The load adjustment process includes a rapid response phase, a regular adjustment phase, and a rapid convergence phase. The main steam pressure prediction result is obtained by calling the main steam pressure prediction model. Based on the main steam pressure prediction result, a differentiated rate strategy is obtained, and load adjustment is performed to achieve the load target value of the AGC command.

[0073] The technical solutions described in the embodiments of this application have at least the following technical effects or advantages: The unit variable rate control technology solution based on main steam pressure prediction provided in this application has formed a systematic technical advantage through multi-dimensional innovative design, solving the technical problems of traditional AGC control: First, it constructs a differentiated interval rate system based on load segment and AGC operation mode, combined with the dynamic downward adjustment mechanism of deep adjustment mode, changing the limitations of fixed rate, realizing precise adaptation of adjustment performance and operation stability under different operating conditions, and improving the core adjustment rate index of AGC; Second, it introduces adaptive correction logic of coal quality characteristic parameters, enabling the reference rate to match the changes in boiler response characteristics in real time, enhancing the adaptability to coal quality fluctuations, and avoiding adjustment lag or over-adjustment caused by coal type differences. Third, by integrating multi-dimensional safety thresholds with equipment operating status and constructing a multi-safety speed limiting mechanism through differentiated correction coefficients, the linkage between rate control and equipment safety is achieved, reducing safety risks such as excessive thermal stress and main steam pressure fluctuations, and extending the unit's service life. Fourth, by adopting a three-stage intelligent regulation strategy, combined with the forward-looking support of the main steam pressure prediction model, the system takes into account the multiple assessment requirements of the power grid for response time, regulation rate, and control accuracy, thereby improving the AGC assessment pass rate and ancillary service compensation benefits. Fifth, through a dynamic closed-loop optimization mechanism, the system updates the safety benchmark rate in real time and iteratively optimizes the initial parameters, ensuring the continuous adaptability of the control strategy to dynamic changes in operating conditions.

[0074] Example 2 This embodiment provides a unit variable rate control system based on main gas pressure prediction, including: The data acquisition module is configured to acquire the unit's current load, rated power, equipment operating safety parameters, and coal quality characteristic parameters; The interval division module is configured to determine the load segment based on the current load of the unit and the rated power of the unit, and to divide the differentiated intervals based on the load segment and the AGC operation mode. The load segment is the unit load interval divided according to the proportion of the rated power of the unit. The benchmark rate construction module is configured to construct a piecewise linear function algorithm model, take the deep adjustment mode identifier as input, set the first benchmark variable load rate for different differentiated intervals, and input the coal quality characteristic parameters to obtain the second benchmark variable load rate. The AGC operation mode is the operation mode in which the unit receives load adjustment instructions, and the deep adjustment mode identifier is the identifier information of the unit in deep peak shaving operation. The safety rate correction module is configured to obtain a first deviation value based on a preset multi-dimensional safety threshold. The first deviation value is the deviation between the actual value of the main steam pressure and the set value of the main steam pressure. The first deviation value is used as a constraint condition, and the second reference variable load rate is corrected for safety speed limit using the piecewise linear function algorithm model to obtain the safety reference rate. The phased adjustment module is configured to plan a load adjustment path based on the safety baseline rate. The load adjustment process includes a rapid response phase, a regular adjustment phase, and a rapid convergence phase. The main steam pressure prediction result is obtained by calling the main steam pressure prediction model. Based on the main steam pressure prediction result, a differentiated rate strategy is obtained, and load adjustment is performed to achieve the load target value of the AGC command.

[0075] A computer-readable storage medium storing a plurality of instructions adapted for loading and execution by a processor of a terminal device of the aforementioned unit variable rate control method based on main gas pressure prediction.

[0076] A terminal device includes a processor and a computer-readable storage medium, the processor being used to implement various instructions; the computer-readable storage medium being used to store multiple instructions adapted to be loaded and executed by the processor as described in the unit variable rate control method based on main gas pressure prediction.

[0077] Those skilled in the art will understand that embodiments of the present invention can be provided as methods, systems, or computer program products. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention can take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0078] This invention is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart illustrations and / or block diagrams. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0079] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0080] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0081] Although preferred embodiments of the invention have been described, those skilled in the art, upon learning the basic inventive concept, can make other changes and modifications to these embodiments. Therefore, the appended claims are intended to be interpreted as including both the preferred embodiments and all changes and modifications falling within the scope of the invention.

[0082] Obviously, those skilled in the art can make various modifications and variations to this invention without departing from the scope of the invention. The spirit and scope of the invention are as follows: Thus, if these modifications and variations of the invention fall within the scope of the claims of the invention and their equivalents, the invention is also intended to include these modifications and variations.

Claims

1. A variable-rate control method for a generator unit based on main gas pressure prediction, characterized in that, include: Obtain the unit's current load, rated power, equipment operating safety parameters, and coal quality characteristics; The load segment is determined based on the current load and rated power of the unit. Differentiated intervals are then divided based on the load segment and the AGC operation mode. The load segment is a unit load interval divided according to the proportion of the unit's rated power. A piecewise linear function algorithm model is constructed, with the deep adjustment mode identifier as input, a first benchmark load change rate is set for different differentiated intervals, and the coal quality characteristic parameters are input to obtain a second benchmark load change rate. The AGC operation mode is the operation mode in which the unit receives load adjustment instructions, and the deep adjustment mode identifier is the identifier information of the unit in deep peak shaving operation. Based on the preset multi-dimensional safety threshold, a first deviation value is obtained. The first deviation value is the deviation between the actual value of the main steam pressure and the set value of the main steam pressure. The first deviation value is used as a constraint condition. The second benchmark variable load rate is corrected for safety speed limit using the piecewise linear function algorithm model to obtain the safety benchmark rate. The load adjustment path is planned based on the safety baseline rate. The load adjustment process includes a rapid response phase, a regular adjustment phase, and a rapid convergence phase. The main steam pressure prediction result is obtained by calling the main steam pressure prediction model. A differentiated rate strategy is obtained based on the main steam pressure prediction result, and the load adjustment is executed to achieve the load target value of the AGC command.

2. The unit variable rate control method based on main gas pressure prediction according to claim 1, characterized in that, The load segment is specifically divided into a first load interval, a second load interval, and a third load interval. The first load interval is between the first and second percentages of the unit's current load relative to its rated power. The second load interval is between the second and third percentages of the unit's current load relative to its rated power. The third load interval is where the unit's current load is at least the third percentage of its rated power, and the first percentage is less than the second percentage, and the second percentage is less than the third percentage. The AGC operation mode includes a first mode and a second mode. The first mode is the operation mode in which the unit receives real-time load adjustment commands from the power grid and responds quickly. The second mode is the mode in which the unit operates smoothly according to a preset load curve. The differentiated areas are the first load interval under the first mode, the second load interval under the first mode, the third load interval under the first mode, and the full load interval under the second mode.

3. The unit variable rate control method based on main gas pressure prediction according to claim 1, characterized in that, The method for setting the first reference variable load rate includes: In the first mode, the first reference load change rate of the third load range is the fourth preset ratio of the rated power. In the first mode, the first reference load change rate of the second load range is the fifth preset ratio of the rated power. In the first mode, the first reference load change rate of the first load range is the sixth preset ratio of the rated power. The first reference load change rate in the second mode full load range is the seventh preset ratio of the rated power. And satisfy > > > The seventh preset ratio The rate of adjustment for the boiler drum must not be lower than the standard regulation rate specified by the power grid. When the deep load adjustment mode is identified as a deep peak shaving condition, the first baseline load change rate for each differentiated interval is set according to the eighth preset ratio. The reduced rate, i.e., the first base variable load rate after the reduction, is r′=r×(1- ), where r is the first baseline load change rate of the corresponding interval before the adjustment. This is a preset scaling factor.

4. The unit variable rate control method based on main gas pressure prediction according to claim 3, characterized in that, The second benchmark variable load rate is obtained through coal quality adaptive correction, and the correction method includes: The preset design coal type corresponds to the boiler pure delay time as follows: The actual boiler pure delay time corresponding to the coal type is The first benchmark variable load rate for each differentiated interval is By correcting the formula The formula is dynamically adjusted and corrected as follows: ,in, This is the second reference variable load rate.

5. The unit variable rate control method based on main gas pressure prediction according to claim 4, characterized in that, The preset multi-dimensional safety thresholds include: the main steam pressure allowable deviation threshold ΔP, and the wall temperature upper limit threshold. The allowable deviation threshold ΔH for steam drum water level and the threshold for the longest continuous variable load. ; The safety speed limit correction needs to be combined with the equipment's operating safety parameters, including: If the duration of continuous load change reaches the threshold of the maximum duration of continuous load change. The first correction factor is used. Perform rate correction; Under reduced load conditions, if the actual value of the main steam pressure exceeds the sum of the main steam pressure setpoint and the allowable deviation threshold ΔP of the main steam pressure, a second correction factor is applied. If the first deviation exceeds the allowable deviation threshold ΔP for the main steam pressure, a third correction factor is applied. Perform rate correction; If the turbine wall temperature reaches the upper limit threshold... The fourth correction factor is adopted. Perform rate correction; If the steam drum water level exceeds the allowable deviation threshold ΔH, the fifth correction factor shall be used. Perform rate correction; The safe reference rate is: and safe reference rate The minimum preset rate ratio is not lower than the rated power.

6. The unit variable rate control method based on main gas pressure prediction according to claim 4, characterized in that, The rapid response phase includes: Calculate the second deviation value ,in The target load value for the AGC command. This represents the current load of the generating unit. If the second deviation value Not less than the preset deviation threshold, by the first multiple Safety reference rate Perform load adjustment until the load change reaches the preset change amount; If the main steam pressure change rate exceeds the preset change rate threshold, the adjustment rate will be adjusted to a second multiple. Safety reference rate ; If the second deviation value If the deviation is less than the preset deviation threshold, it directly enters the fast convergence phase. ,and , All are preset positive numbers.

7. The unit variable rate control method based on main gas pressure prediction according to claim 4, characterized in that, The routine adjustment phase includes: After completing the rapid response phase, record the unit load at the end of this phase. The third deviation value is calculated as follows: ; At a safe reference rate Continuous load regulation is performed, and the formula for calculating load changes during the regulation process is as follows: ,in For any given time, the unit load, Adjust the duration for this phase. For the sign function, increment by 1 for load increase and decrement by 1 for load decrease; Collect equipment operating safety parameters and actual main steam pressure values, repeat the safety speed limit correction process, and update the safety reference rate. And replace the current adjustment rate; When the third deviation value When the deviation is less than or equal to the preset convergence deviation threshold, the current adjustment phase ends and the fast convergence phase begins.

8. The unit variable rate control method based on main gas pressure prediction according to claim 4, characterized in that, The rapid convergence phase includes: Record the unit load after the routine adjustment phase ends. Calculate the fourth deviation value ; The main steam pressure prediction model is constructed based on the actual main steam pressure value, the first deviation value, and the load adjustment trend. The main steam pressure prediction model is called to obtain the main steam pressure prediction result, and the convergence rate is adjusted based on the main steam pressure prediction result. ,include: If the actual value of the main steam pressure is greater than the set value of the main steam pressure, then... If the actual value of the main steam pressure is less than or equal to the set value of the main steam pressure, the setting... ; If the actual value of the main steam pressure is less than the set value of the main steam pressure, then... If the actual value of the main steam pressure is greater than or equal to the set value of the main steam pressure, then set... ,in > ,and , All are positive numbers not less than 1; Convergence rate Perform convergence adjustment, adjustment duration Adjusting the afterload ; If the difference between the adjusted load and the target load value of the AGC command is less than the preset accuracy threshold, the adjustment ends.

9. A unit variable rate control system based on main gas pressure prediction, characterized in that, The unit variable rate control method based on main gas pressure prediction according to any one of claims 1-8 includes: The data acquisition module is configured to acquire the unit's current load, rated power, equipment operating safety parameters, and coal quality characteristic parameters; The interval division module is configured to determine the load segment based on the current load of the unit and the rated power of the unit, and to divide the differentiated intervals based on the load segment and the AGC operation mode. The load segment is the unit load interval divided according to the proportion of the rated power of the unit. The benchmark rate construction module is configured to construct a piecewise linear function algorithm model, take the deep adjustment mode identifier as input, set the first benchmark variable load rate for different differentiated intervals, and input the coal quality characteristic parameters to obtain the second benchmark variable load rate. The AGC operation mode is the operation mode in which the unit receives load adjustment instructions, and the deep adjustment mode identifier is the identifier information of the unit in deep peak shaving operation. The safety rate correction module is configured to obtain a first deviation value based on a preset multi-dimensional safety threshold. The first deviation value is the deviation between the actual value of the main steam pressure and the set value of the main steam pressure. The first deviation value is used as a constraint condition, and the second reference variable load rate is corrected for safety speed limit using the piecewise linear function algorithm model to obtain the safety reference rate. The phased adjustment module is configured to plan a load adjustment path based on the safety baseline rate. The load adjustment process includes a rapid response phase, a regular adjustment phase, and a rapid convergence phase. The main steam pressure prediction result is obtained by calling the main steam pressure prediction model. Based on the main steam pressure prediction result, a differentiated rate strategy is obtained, and load adjustment is performed to achieve the load target value of the AGC command.

10. A computer-readable storage medium storing a plurality of instructions, characterized in that, The instructions are adapted to be loaded and executed by the processor of the terminal device as described in claim 1, which is a variable rate control method for the unit based on main gas pressure prediction.

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