A method, system, terminal equipment, and storage medium for turbine command control in frequency regulation unit coordination mode.

Abstract

This invention discloses a turbine command control method, system, terminal equipment, and storage medium for unit coordination under frequency regulation conditions, belonging to the field of thermal power unit control technology. The method generates a coordination basis feedforward quantity by processing the load command through function transformation and inertial filtering, combined with intelligent switching of AGC signals; it filters and compares the frequency regulation command, performs a bidirectional function transformation on the main steam pressure signal, and multiplies it with the pressure deviation to obtain a pressure coupling quantity, then switches the output pressure correction quantity based on the comparison result; it adds and synthesizes the signals from multiple branches, calculates the difference with the generator power, and performs a function transformation to obtain the power deviation characteristic quantity; it inputs the deviation, setpoint, and feedforward quantity into a PID module for closed-loop calculation, and switches the output turbine command in combination with intelligent control signals. This invention overcomes the conflict between the DEH and CCS loops, suppresses overshoot, achieves bumpless switching, and significantly improves the frequency regulation response speed and control accuracy.

Description

Technical Field

[0001] This invention belongs to the field of thermal power unit control technology, specifically relating to a turbine command control method, system, terminal equipment, and storage medium for unit coordination under frequency regulation conditions. Background Technology

[0002] With the large-scale grid connection of new energy sources such as wind power and photovoltaics, the power grid exhibits characteristics of high proportion of renewable energy and high power electronics, significantly reducing system rotational inertia and continuously weakening frequency regulation capabilities. This places more stringent demands on the primary frequency regulation, rapid tracking of AGC commands, and other deep peak shaving and ancillary service capabilities of thermal power units. Traditional coordinated control systems (CCS) for thermal power units are mostly designed based on steady-state operating conditions, achieving load and main steam pressure balance control through boiler following, turbine following, or coordinated direct regulation. Their control logic focuses on operational stability, resulting in a slow response speed, making it difficult to adapt to the millisecond to second-level rapid frequency regulation requirements of the power grid.

[0003] Under the new frequency regulation conditions, the unit load command fluctuates frequently, the adjustment range is large, and the adjustment direction is frequently switched. The traditional turbine command generation method has obvious shortcomings: the traditional control does not effectively coordinate the DEH fast loop and the CCS steady-state loop, and the frequency regulation command and coordination command are prone to superposition and conflict, which further aggravates parameter oscillation. Summary of the Invention

[0004] In order to overcome the shortcomings of the prior art, the present invention aims to provide a turbine command control method, system, terminal equipment and storage medium for unit coordination under frequency regulation conditions.

[0005] To achieve the above objectives, the present invention employs the following technical solution: In a first aspect, the present invention provides a turbine command control method for unit coordination under frequency regulation conditions, comprising the following steps: S1: Obtain the unit load command signal before primary frequency regulation, and obtain the load inertial component by inertial filtering, and obtain the load feedforward component by function transformation; calculate the difference between the unit load command signal before primary frequency regulation and the target load setpoint, and then perform function transformation, combined with the AGC already engaged signal for intelligent switching, to generate the basic feedforward quantity of the coordination mode. S2: Acquire a primary frequency regulation load command signal, process it through a first-order inertial filter to obtain the frequency regulation load inertial component, and simultaneously obtain a frequency regulation comparison trigger signal through comparison processing; perform a bidirectional function transformation on the main steam pressure signal to obtain a first pressure function value and a second pressure function value, and multiply the main steam pressure deviation signal by the second pressure function value after function transformation to obtain the pressure coupling amount; then perform operating condition judgment and branch switching according to the frequency regulation comparison trigger signal, and output the frequency regulation pressure correction amount; S3: The coordination method base feedforward quantity, the frequency regulation load inertia component, the first pressure function value and the frequency regulation pressure correction quantity are added together by multiple branches and then added to the load inertia component twice to obtain the total load demand signal; the total load demand signal is subtracted from the generator power value and transformed by a function to obtain the power deviation characteristic quantity; S4: The power deviation characteristic, the preset constant setting value, and the load feedforward component are respectively input as process value, set value, and feedforward quantity to the PID control module for closed-loop calculation to obtain the PID control output value; combined with the intelligent control input signal, the final channel switching is performed to output the turbine command under intelligent CCS mode.

[0006] Furthermore, step S1 specifically includes: The unit load command signal before primary frequency regulation is input to the first function module and the first first-order inertial module respectively, and function calculation and first-order inertial time calculation are performed to obtain the output value of the first function module and the output value of the first first-order inertial module. The unit load command signal before primary frequency regulation and the target load setpoint are input to the first subtraction module for difference calculation to obtain the output value of the first subtraction module; the output value of the first subtraction module is input to the fifth function module for function transformation to obtain the output value of the fifth function module. The AGC activated signal, the output value of the fifth function module, and the output value of the first constant module are respectively input to the enable trigger terminal, the Y terminal, and the N terminal of the first switching module. When the AGC activated signal output is the first threshold, the first switching module switches to the Y terminal to output the output value of the fifth function module. When the output is the second threshold, the first switching module switches to the N terminal to output the output value of the first constant module, thereby obtaining the basic feedforward quantity of the coordination mode.

[0007] Furthermore, step S2 specifically includes: The frequency modulation load command signal is input to the second first-order inertial module and the first comparison module respectively to perform first-order inertial time calculation and comparison calculation, and obtain the output value of the second first-order inertial module and the output value of the first comparison module. The main steam pressure signal is input to the second and third function modules respectively for function transformation to obtain the output values ​​of the second and third function modules; the main steam pressure deviation signal is input to the fourth function module for function transformation to obtain the output value of the fourth function module; the output values ​​of the third and fourth function modules are input to the first multiplication module for multiplication calculation to obtain the output value of the first multiplication module. The output values ​​of the first comparison module, the second switching module, and the first multiplication module are respectively input to the enable trigger terminal, Y terminal, and N terminal of the second switching module. When the output value of the first comparison module is the first threshold, the second switching module switches to the Y terminal to output its own output value. When the output value is the second threshold, the second switching module switches to the N terminal to output the output value of the first multiplication module, thereby obtaining the frequency modulation pressure correction amount.

[0008] Furthermore, step S3 specifically includes: The basic feedforward quantity of the coordination method, the output value of the second first-order inertial module, the output value of the second function module, and the frequency modulation pressure correction quantity are input to the first summing module for summing calculation to obtain the output value of the first summing module; The output value of the first first-order inertial module and the output value of the first adder module are input into the second adder module for a second addition calculation to obtain the output value of the second adder module; The generator power value and the output value of the second addition module are input to the second subtraction module for difference calculation to obtain the output value of the second subtraction module; the output value of the second subtraction module is input to the sixth function module for function transformation to obtain the power deviation characteristic quantity.

[0009] Furthermore, step S4 specifically includes: The power deviation characteristic, the output value of the second constant module, and the output value of the first function module are respectively input to the PV terminal, STPT terminal, and FF terminal of the first PID module. The PID adjustment calculation is performed with the output value of the second constant module as the set value, the output value of the sixth function module as the process value, and the output value of the first function module as the feedforward value, so as to obtain the output value of the first PID module. The intelligent control input signal, the new turbine flow command value, and the output value of the first PID module are respectively input to the enable trigger terminal, Y terminal, and N terminal of the third switching module. When the intelligent control input signal output is the first threshold, the third switching module switches to the Y terminal to output the new turbine flow command value. When the output is the second threshold, the third switching module switches to the N terminal to output the output value of the first PID module, which serves as the turbine command output under the intelligent CCS mode.

[0010] Secondly, the present invention provides a turbine command control system for unit coordination under frequency regulation conditions, comprising: The signal acquisition unit is used to acquire the unit load command signal before primary frequency regulation, generator power value, target load set value, primary frequency regulation load command signal, main steam pressure signal, main steam pressure deviation signal, AGC engaged signal, intelligent control engaged signal, and new turbine flow command value. The instruction preprocessing and AGC switching unit is communicatively connected to the signal acquisition unit. It is used to perform function transformation and first-order inertial filtering on the unit load instruction signal before primary frequency regulation to obtain load feedforward component and load inertial component. At the same time, it calculates the difference between the unit load instruction signal before primary frequency regulation and the target load setpoint, performs function transformation, and combines it with the AGC already engaged signal to perform intelligent switching and generate AGC coordination basic instruction. The frequency modulation processing and pressure decoupling unit is communicatively connected to the signal acquisition unit. It is used to perform first-order inertial filtering and comparison processing on the primary frequency modulation load command signal to obtain the frequency modulation load inertial component and the frequency modulation comparison trigger signal. It performs bidirectional function transformation on the main steam pressure signal, and then multiplies the main steam pressure deviation signal after function transformation with one of the function transformation values ​​of the main steam pressure signal to obtain the pressure coupling amount. It also combines the frequency modulation comparison trigger signal to perform operating condition judgment and branch switching, and outputs the frequency modulation pressure correction amount. The signal synthesis and power deviation calculation unit is communicatively connected to the instruction preprocessing and AGC switching unit, the frequency modulation processing and pressure decoupling unit, and the signal acquisition unit, respectively. It is used to synthesize the AGC coordination basic instruction, the frequency modulation load inertia component, the other function transformation value of the main steam pressure, and the frequency modulation pressure correction amount by adding multiple branches, and then adding it twice with the load inertia component. After subtracting it from the generator power value and performing function transformation, the power deviation characteristic quantity is obtained. The PID regulation and command output unit is communicatively connected to the signal synthesis and power deviation calculation unit and the signal acquisition unit, respectively. It is used to input the power deviation characteristic, preset constant set value and load feedforward component as process value, set value and feedforward quantity to the PID module for regulation calculation, and then combine the intelligent control input signal to perform final channel switching, synthesize and output the turbine command under intelligent CCS mode.

[0011] Thirdly, the present invention provides a turbine command control device for unit coordination mode under frequency regulation conditions, comprising: The signal input interface is used to receive the unit load command before primary frequency regulation signal, generator power value, target load set value, primary frequency regulation load command signal, main steam pressure signal, main steam pressure deviation signal, AGC engaged signal, intelligent control engaged signal, and new turbine flow command value. And the first function module, the first first-order inertia module, the first subtraction module, the second first-order inertia module, the first comparison module, the second function module, the third function module, the fourth function module, the fifth function module, the first multiplication module, the first constant module, the first switching module, the second switching module, the first addition module, the second addition module, the second subtraction module, the sixth function module, the second constant module, the first PID module, and the third switching module; in, The unit load command signal output from the signal input interface before primary frequency regulation is respectively connected to the first function module, the first first-order inertial module, and the first subtraction module; the target load setpoint is connected to the first subtraction module. The output of the first subtraction module is connected to the fifth function module; the AGC activated signal, the output of the fifth function module, and the first constant module are respectively connected to the enable trigger terminal, the Y terminal, and the N terminal of the first switching module. The primary frequency regulation load command signal is respectively input to the second first-order inertial module and the first comparison module; the main steam pressure signal is respectively input to the second function module and the third function module; the main steam pressure deviation signal is input to the fourth function module; the output terminals of the third function module and the fourth function module are both connected to the first multiplication module; the output terminals of the first comparison module, the second switching module, and the first multiplication module are respectively connected to the enable trigger terminal, the Y terminal, and the N terminal of the second switching module. The output terminals of the first switching module, the second first-order inertial module, the second function module, and the second switching module are all connected to the first summing module; the output terminals of the first first-order inertial module and the first summing module are all connected to the second summing module; the generator power value and the output terminal of the second summing module are all connected to the second subtraction module; the output terminal of the second subtraction module is connected to the sixth function module; the output terminals of the sixth function module, the second constant module, and the first function module are respectively connected to the PV terminal, STPT terminal, and FF terminal of the first PID module. The intelligent control input signal, the new turbine flow command value, and the output of the first PID module are respectively connected to the enable trigger terminal, Y terminal, and N terminal of the third switching module; the output of the third switching module is connected to the turbine command under intelligent CCS mode.

[0012] Fourthly, the present invention provides a terminal device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements the steps of the turbine command control method for unit coordination under frequency regulation conditions as described above.

[0013] Fifthly, the present invention also provides a computer-readable storage medium having a computer program stored thereon, wherein the computer program, when executed by a processor, implements the steps of the turbine command control method for unit coordination under frequency regulation conditions as described in any of the preceding claims.

[0014] Compared with the prior art, the present invention has the following beneficial effects: This invention effectively overcomes the technical bottleneck of traditional coordinated control systems under frequent, rapid, and deep frequency modulation conditions by constructing parallel processing and dynamic switching logic for multi-branch signals. In the command preprocessing stage, first-order inertial filtering and function transformation are used to extract load dynamic characteristics, and intelligent switching is performed in conjunction with the AGC already engaged signal to generate the basic feedforward quantity for the coordinated mode, which significantly improves the initial tracking response speed of the turbine command. In the frequency regulation and pressure decoupling stage, the main steam pressure is transformed by a bidirectional function, and the pressure coupling quantity is obtained by multiplying the transformed pressure deviation signal with the pressure function value. This is combined with the frequency regulation comparison trigger signal to switch branches, effectively suppressing the regulation overshoot phenomenon, decoupling the interaction interference between power and pressure, and avoiding the superposition conflict between the DEH fast loop and the CCS steady-state loop. In the signal synthesis stage, the basic feedforward quantity, frequency regulation component, and pressure correction quantity are added to multiple branches, and the difference is calculated and function transformed with the generator power in real time to accurately construct the total load demand signal, which greatly improves the system's sensitivity to capturing actual power deviation and its dynamic tracking capability. In the command output stage, PID closed-loop regulation combining process value, set value, and feedforward quantity is adopted, and the final channel switching is performed based on the intelligent control engagement signal, ensuring smooth transition and disturbance-free output of commands in intelligent / conventional control modes. Overall, this invention comprehensively improves the stability, control accuracy, and long-term safety of unit operation while taking into account the grid's need for rapid frequency regulation response. Attached Figure Description

[0015] Figure 1 A flowchart illustrating a turbine command control method for unit coordination under frequency regulation conditions provided by the present invention; Figure 2 A schematic diagram of the main engine power change curve during the unit start-up and load increase process of a turbine command control method for unit coordination under frequency regulation conditions provided by the present invention. Figure 3 This is a flowchart illustrating a turbine command control system for unit coordination under frequency regulation conditions, provided by the present invention.

[0016] Figure 4 This invention provides a schematic flowchart of a turbine command control device for unit coordination under frequency regulation conditions.

[0017] Wherein: 001 - Unit load command signal before primary frequency regulation; 002 - Generator power value; 003 - Target load setpoint; 004 - Primary frequency regulation load command signal; 005 - Main steam pressure signal; 006 - Main steam pressure deviation signal; 007 - First function module; 008 - First first-order inertia module; 009 - First subtraction module; 010 - Second first-order inertia module; 011 - First comparison module; 012 - Second function module; 013 - Third function module; 014 - Fourth function module; 015 - Fifth function module; Function module; 016-First multiplication module; 017-AGC activated signal; 018-First constant module; 019-First switching module; 020-Second switching module; 021-First addition module; 022-Second addition module; 023-Second subtraction module; 024-Sixth function module; 025-Second constant module; 026-First PID module; 027-Intelligent control activated signal; 028-New turbine flow command value; 029-Third switching module; 030-Turbine command under intelligent CCS mode. Detailed Implementation

[0018] To enable those skilled in the art to better understand the present invention, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of the present invention.

[0019] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this invention are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of the invention described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover a non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0020] The present invention will now be described in further detail with reference to the accompanying drawings: Example 1 Combination Figure 1 and Figure 2 As shown, this embodiment provides a turbine command control method for unit coordination under frequency regulation conditions, including the following four steps: S1: Obtain the unit load command signal before primary frequency regulation, and obtain the load inertial component by inertial filtering, and obtain the load feedforward component by function transformation; calculate the difference between the unit load command signal before primary frequency regulation and the target load setpoint, and then perform function transformation, combined with the AGC already engaged signal for intelligent switching, to generate the basic feedforward quantity of the coordination mode. Specifically, the unit load command signal 001 before primary frequency regulation is input to the first function module 007 and the first first-order inertial module 008, respectively. The first function module 007 performs function calculations to obtain the load feedforward component, and the first first-order inertial module 008 performs first-order inertial time calculations to obtain the load inertial component. The unit load command signal 001 before primary frequency regulation and the target load setpoint 003 are input to the first subtraction module 009 for difference calculation to obtain the output value of the first subtraction module 009. The output value of the first subtraction module 009 is then input to the fifth function module 015. A function transformation is performed to obtain the output value of the fifth function module 015. The AGC activated signal 017, the output value of the fifth function module 015, and the output value of the first constant module 018 are respectively connected to the enable trigger terminal, Y terminal, and N terminal of the first switching module 019. When the output of the AGC activated signal 017 is the first threshold, the first switching module 019 switches to the Y terminal and outputs the output value of the fifth function module 015. When the output is the second threshold, the first switching module 019 switches to the N terminal and outputs the value of the first constant module 018, thus obtaining the basic feedforward quantity of the coordination method.

[0021] S2: Acquire a primary frequency regulation load command signal, process it through a first-order inertial filter to obtain the frequency regulation load inertial component, and simultaneously obtain a frequency regulation comparison trigger signal through comparison processing; perform a bidirectional function transformation on the main steam pressure signal to obtain a first pressure function value and a second pressure function value, and multiply the main steam pressure deviation signal by the second pressure function value after function transformation to obtain the pressure coupling amount; then perform operating condition judgment and branch switching according to the frequency regulation comparison trigger signal, and output the frequency regulation pressure correction amount; Specifically, the primary frequency regulation load command signal 004 is input to the second first-order inertial module 010 and the first comparison module 011, respectively. The second first-order inertial module 010 performs first-order inertial time calculation to obtain the frequency regulation load inertial component, and the first comparison module 011 performs comparison calculation to obtain the frequency regulation comparison trigger signal. The main steam pressure signal 005 is input to the second function module 012 and the third function module 013 for function transformation to obtain the first pressure function value and the second pressure function value. The main steam pressure deviation signal 006 is input to the fourth function module 014 for function transformation to obtain the output value of the fourth function module 014. The third function module 014... The output value of module 13 (i.e., the second pressure function value) and the output value of module 014 of module 014 are input to the first multiplication module 016 for multiplication calculation to obtain the pressure coupling amount; the output values ​​of the first comparison module 011, the second switching module 020, and the first multiplication module 016 are respectively connected to the enable trigger terminal, the Y terminal, and the N terminal of the second switching module 020; when the output value of the first comparison module 011 is the first threshold, the second switching module 020 switches to the Y terminal and outputs its own output value; when the output value is the second threshold, the second switching module 020 switches to the N terminal and outputs the output value of the first multiplication module 016 to obtain the frequency modulation pressure correction amount.

[0022] The inertial time constant of the first first-order inertial module 008 and the second first-order inertial module 010 is configured in the range of 0 to 60, with the unit being seconds (s).

[0023] S3: The coordination method base feedforward quantity, the frequency regulation load inertia component, the first pressure function value and the frequency regulation pressure correction quantity are added together by multiple branches and then added to the load inertia component twice to obtain the total load demand signal; the total load demand signal is subtracted from the generator power value and transformed by a function to obtain the power deviation characteristic quantity; Specifically, the output values ​​of the first switching module 019 (i.e., the basic feedforward quantity of the coordination mode), the output value of the second first-order inertia module 010 (i.e., the frequency regulation load inertia component), the output value of the second function module 012 (i.e., the first pressure function value), and the output value of the second switching module 020 (i.e., the frequency regulation pressure correction quantity) are input to the first addition module 021 for addition calculation to obtain the output value of the first addition module 021; the output value of the first first-order inertia module 008 (i.e., the load inertia component) and the output value of the first addition module 021 are input to the second addition module 022 for secondary addition calculation to obtain the total load demand signal; the generator power value 002 and the total load demand signal are input to the second subtraction module 023 for difference calculation to obtain the output value of the second subtraction module 023; the output value of the second subtraction module 023 is input to the sixth function module 024 for function transformation to obtain the power deviation characteristic quantity.

[0024] S4: The power deviation characteristic, the preset constant setting value, and the load feedforward component are respectively input as process value, set value, and feedforward quantity to the PID control module for closed-loop calculation to obtain the PID control output value; combined with the intelligent control input signal, the final channel switching is performed to output the turbine command under intelligent CCS mode.

[0025] Specifically, the output values ​​of the sixth function module 024, the second constant module 025, and the first function module 007 are respectively connected to the PV terminal, STPT terminal, and FF terminal of the first PID module 026. The first PID module 026 performs PID regulation calculations using the second constant module 025 as the set value, the output value of the sixth function module 024 as the process value, and the output value of the first function module 007 as the feedforward value, to obtain the output value of the first PID module 026. The intelligent control activation signal 027, the new turbine flow command value 028, and the output value of the first PID module 026 are respectively connected to the enable trigger terminal, Y terminal, and N terminal of the third switching module 029. When the intelligent control activation signal 027 outputs the first threshold, the third switching module 029 switches to the Y terminal and outputs the new turbine flow command value 028. When the output is the second threshold, the third switching module 029 switches to the N terminal and outputs the output value of the first PID module 026, which serves as the turbine command 030 output under the intelligent CCS mode.

[0026] In this embodiment, the first threshold is set to 1 and the second threshold is set to 0.

[0027] When applying the method provided in this embodiment, phased optimization control is achieved during the unit operation control process: such as Figure 2 As shown, during the low-load phase (0~450s), the load is gradually increased using a small-step, multi-platform approach, strictly controlling the unit's thermal stress to ensure equipment safety, while also adapting to the boiler combustion and steam-water system stability requirements during startup. During the medium-to-high load phase (450~900s), the load increase rate is gradually increased, ultimately achieving rapid ramp-up at high load. This satisfies the rapid power response requirements of the power grid's AGC / frequency regulation while avoiding the problems of insufficient boiler-side performance and significant parameter overshoot in traditional linear control. Through the dynamic coordination of the DEH fast loop and the CCS steady-state loop, frequency regulation command overlap conflicts are effectively eliminated, ensuring seamless command switching and stable main parameters across all operating conditions.

[0028] Example 2 Combination Figure 3 As shown, this embodiment provides a turbine command control system for unit coordination under frequency regulation conditions, including: The signal acquisition unit is used to acquire the unit load command signal before primary frequency regulation, generator power value, target load set value, primary frequency regulation load command signal, main steam pressure signal, main steam pressure deviation signal, AGC engaged signal, intelligent control engaged signal, and new turbine flow command value. The instruction preprocessing and AGC switching unit is communicatively connected to the signal acquisition unit. It is used to perform function transformation and first-order inertial filtering on the unit load instruction signal before primary frequency regulation to obtain load feedforward component and load inertial component. At the same time, it calculates the difference between the unit load instruction signal before primary frequency regulation and the target load setpoint, performs function transformation, and combines it with the AGC already engaged signal to perform intelligent switching and generate AGC coordination basic instruction. The frequency modulation processing and pressure decoupling unit is communicatively connected to the signal acquisition unit. It is used to perform first-order inertial filtering and comparison processing on the primary frequency modulation load command signal to obtain the frequency modulation load inertial component and the frequency modulation comparison trigger signal. It performs bidirectional function transformation on the main steam pressure signal, and then multiplies the main steam pressure deviation signal after function transformation with one of the function transformation values ​​of the main steam pressure signal to obtain the pressure coupling amount. It also combines the frequency modulation comparison trigger signal to perform operating condition judgment and branch switching, and outputs the frequency modulation pressure correction amount. The signal synthesis and power deviation calculation unit is communicatively connected to the instruction preprocessing and AGC switching unit, the frequency modulation processing and pressure decoupling unit, and the signal acquisition unit, respectively. It is used to synthesize the AGC coordination basic instruction, the frequency modulation load inertia component, the other function transformation value of the main steam pressure, and the frequency modulation pressure correction amount by adding multiple branches, and then adding it twice with the load inertia component. After subtracting it from the generator power value and performing function transformation, the power deviation characteristic quantity is obtained. The PID regulation and command output unit is communicatively connected to the signal synthesis and power deviation calculation unit and the signal acquisition unit, respectively. It is used to input the power deviation characteristic, preset constant set value and load feedforward component as process value, set value and feedforward quantity to the PID module for regulation calculation, and then combine the intelligent control input signal to perform final channel switching, synthesize and output the turbine command under intelligent CCS mode.

[0029] Through the coordinated operation of the aforementioned functional units, the system architecture of this embodiment can efficiently integrate fast frequency regulation command superposition, valve characteristic compensation, valve position flow correction, and CCS steady-state control logic. In actual unit frequency regulation operation, this system can automatically match the command path based on the AGC activation / deactivation status and intelligent control mode, effectively overcoming the superposition conflict between the DEH fast loop and the CCS steady-state loop, suppressing parameter oscillations, and achieving smooth transition and seamless switching of commands under different operating conditions. While ensuring the safety of unit equipment, it significantly improves the dynamic response quality and operational stability of the system under complex frequency regulation conditions.

[0030] Example 3 Combination Figure 4 As shown, this embodiment provides a turbine command control device for unit coordination under frequency regulation conditions, including: The signal input interface is used to receive the unit load command, primary frequency regulation pre-regulation signal 001, generator power value 002, target load setting value 003, primary frequency regulation load command signal 004, main steam pressure signal 005, main steam pressure deviation signal 006, AGC engaged signal 017, intelligent control engaged signal 027, and new turbine flow command value 028. And the first function module 007, the first first-order inertia module 008, the first subtraction module 009, the second first-order inertia module 010, the first comparison module 011, the second function module 012, the third function module 013, the fourth function module 014, the fifth function module 015, the first multiplication module 016, the first constant module 018, the first switching module 019, the second switching module 020, the first addition module 021, the second addition module 022, the second subtraction module 023, the sixth function module 024, the second constant module 025, the first PID module 026, and the third switching module 029; in, The unit load command signal 001 output by the signal input interface before primary frequency regulation is respectively connected to the first function module 007, the first first-order inertial module 008, and the first subtraction module 009; the target load setpoint 003 is connected to the first subtraction module 009. The output of the first subtraction module 009 is connected to the fifth function module 015; the AGC activated signal 017, the output of the fifth function module 015, and the first constant module 018 are respectively connected to the enable trigger terminal, the Y terminal, and the N terminal of the first switching module 019. The primary frequency regulation load command signal 004 is respectively connected to the second first-order inertial module 010 and the first comparison module 011; the main steam pressure signal 005 is respectively connected to the second function module 012 and the third function module 013; the main steam pressure deviation signal 006 is connected to the fourth function module 014; the output terminals of the third function module 013 and the fourth function module 014 are both connected to the first multiplication module 016; the output terminals of the first comparison module 011, the second switching module 020, and the first multiplication module 016 are respectively connected to the enable trigger terminal, the Y terminal, and the N terminal of the second switching module 020; The output terminals of the first switching module 019, the second first-order inertial module 010, the second function module 012, and the second switching module 020 are all connected to the first summing module 021; the output terminals of the first first-order inertial module 008 and the first summing module 021 are all connected to the second summing module 022; the generator power value 002 and the output terminals of the second summing module 022 are all connected to the second subtraction module 023; the output terminal of the second subtraction module 023 is connected to the sixth function module 024; the output terminals of the sixth function module 024, the second constant module 025, and the first function module 007 are respectively connected to the PV terminal, STPT terminal, and FF terminal of the first PID module 026; The intelligent control input signal 027, the new turbine flow command value 028, and the output terminal of the first PID module 026 are respectively connected to the enable trigger terminal, Y terminal, and N terminal of the third switching module 029; the output terminal of the third switching module 029 is connected to the turbine command 030 under intelligent CCS mode.

[0031] The device architecture adopted in this embodiment enables the coordinated operation of various control modules, which can efficiently complete the superposition of fast frequency modulation commands, valve characteristic compensation and valve position flow correction. It effectively achieves seamless switching with CCS commands and anti-conflict protection, which significantly improves the dynamic response quality and operational stability of the system under complex frequency modulation conditions while ensuring the safety of the unit equipment.

[0032] Example 4 This embodiment provides a terminal device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements the method steps as described in Embodiment 1.

[0033] Example 5 This embodiment provides a computer storage medium on which a computer program is stored, and when the computer program is executed by a processor, it implements the method steps as described in Embodiment 1.

[0034] The above content is only for illustrating the technical concept of the present invention and should not be construed as limiting the scope of protection of the present invention. Any modifications made to the technical solution based on the technical concept proposed in this invention shall fall within the scope of protection of the claims of this invention.

Claims

1. A turbine command control method for unit coordination under frequency regulation conditions, characterized in that: Includes the following steps: S1: Obtain the unit load command signal before primary frequency regulation, and obtain the load inertial component by inertial filtering, and obtain the load feedforward component by function transformation; calculate the difference between the unit load command signal before primary frequency regulation and the target load setpoint, and then perform function transformation, combined with the AGC already engaged signal for intelligent switching, to generate the basic feedforward quantity of the coordination mode. S2: Acquire a primary frequency regulation load command signal, process it through a first-order inertial filter to obtain the frequency regulation load inertial component, and simultaneously obtain a frequency regulation comparison trigger signal through comparison processing; perform a bidirectional function transformation on the main steam pressure signal to obtain a first pressure function value and a second pressure function value, and multiply the main steam pressure deviation signal by the second pressure function value after function transformation to obtain the pressure coupling amount; then perform operating condition judgment and branch switching according to the frequency regulation comparison trigger signal, and output the frequency regulation pressure correction amount; S3: The coordination method base feedforward quantity, the frequency regulation load inertia component, the first pressure function value and the frequency regulation pressure correction quantity are added together by multiple branches and then added to the load inertia component twice to obtain the total load demand signal; the total load demand signal is subtracted from the generator power value and transformed by a function to obtain the power deviation characteristic quantity; S4: The power deviation characteristic, the preset constant setting value, and the load feedforward component are respectively input as process value, set value, and feedforward quantity to the PID control module for closed-loop calculation to obtain the PID control output value; combined with the intelligent control input signal, the final channel switching is performed to output the turbine command under intelligent CCS mode.

2. The turbine command control method for unit coordination under frequency regulation conditions according to claim 1, characterized in that: Step S1 specifically includes: The unit load command signal before primary frequency regulation is input to the first function module and the first first-order inertial module respectively, and function calculation and first-order inertial time calculation are performed to obtain the output value of the first function module and the output value of the first first-order inertial module. The unit load command signal before primary frequency regulation and the target load setpoint are input to the first subtraction module for difference calculation to obtain the output value of the first subtraction module; the output value of the first subtraction module is input to the fifth function module for function transformation to obtain the output value of the fifth function module. The AGC activated signal, the output value of the fifth function module, and the output value of the first constant module are respectively input to the enable trigger terminal, the Y terminal, and the N terminal of the first switching module. When the AGC activated signal output is the first threshold, the first switching module switches to the Y terminal to output the output value of the fifth function module. When the output is the second threshold, the first switching module switches to the N terminal to output the output value of the first constant module, thereby obtaining the basic feedforward quantity of the coordination mode.

3. The turbine command control method for unit coordination under frequency regulation conditions according to claim 2, characterized in that: Step S2 specifically includes: The frequency modulation load command signal is input to the second first-order inertial module and the first comparison module respectively to perform first-order inertial time calculation and comparison calculation, and obtain the output value of the second first-order inertial module and the output value of the first comparison module. The main steam pressure signal is input to the second and third function modules respectively for function transformation to obtain the output values ​​of the second and third function modules; the main steam pressure deviation signal is input to the fourth function module for function transformation to obtain the output value of the fourth function module; the output values ​​of the third and fourth function modules are input to the first multiplication module for multiplication calculation to obtain the output value of the first multiplication module. The output values ​​of the first comparison module, the second switching module, and the first multiplication module are respectively input to the enable trigger terminal, Y terminal, and N terminal of the second switching module. When the output value of the first comparison module is the first threshold, the second switching module switches to the Y terminal to output its own output value. When the output value is the second threshold, the second switching module switches to the N terminal to output the output value of the first multiplication module, thereby obtaining the frequency modulation pressure correction amount.

4. The turbine command control method for unit coordination under frequency regulation conditions according to claim 3, characterized in that: Step S3 specifically includes: The basic feedforward quantity of the coordination method, the output value of the second first-order inertial module, the output value of the second function module, and the frequency modulation pressure correction quantity are input to the first summing module for summing calculation to obtain the output value of the first summing module; The output value of the first first-order inertial module and the output value of the first adder module are input into the second adder module for a second addition calculation to obtain the output value of the second adder module; The generator power value and the output value of the second addition module are input to the second subtraction module for difference calculation to obtain the output value of the second subtraction module; the output value of the second subtraction module is input to the sixth function module for function transformation to obtain the power deviation characteristic quantity.

5. The turbine command control method for unit coordination under frequency regulation conditions according to claim 4, characterized in that: Step S4 specifically includes: The power deviation characteristic, the output value of the second constant module, and the output value of the first function module are respectively input to the PV terminal, STPT terminal, and FF terminal of the first PID module. The PID adjustment calculation is performed with the output value of the second constant module as the set value, the output value of the sixth function module as the process value, and the output value of the first function module as the feedforward value, so as to obtain the output value of the first PID module. The intelligent control input signal, the new turbine flow command value, and the output value of the first PID module are respectively input to the enable trigger terminal, Y terminal, and N terminal of the third switching module. When the intelligent control input signal output is the first threshold, the third switching module switches to the Y terminal to output the new turbine flow command value. When the output is the second threshold, the third switching module switches to the N terminal to output the output value of the first PID module, which serves as the turbine command output under the intelligent CCS mode.

6. A turbine command control system for unit coordination under frequency regulation conditions, characterized in that, include: The signal acquisition unit is used to acquire the unit load command signal before primary frequency regulation, generator power value, target load set value, primary frequency regulation load command signal, main steam pressure signal, main steam pressure deviation signal, AGC engaged signal, intelligent control engaged signal, and new turbine flow command value. The instruction preprocessing and AGC switching unit is communicatively connected to the signal acquisition unit. It is used to perform function transformation and first-order inertial filtering on the unit load instruction signal before primary frequency regulation to obtain load feedforward component and load inertial component. At the same time, it calculates the difference between the unit load instruction signal before primary frequency regulation and the target load setpoint, performs function transformation, and combines it with the AGC already engaged signal to perform intelligent switching and generate AGC coordination basic instruction. The frequency modulation processing and pressure decoupling unit is communicatively connected to the signal acquisition unit. It is used to perform first-order inertial filtering and comparison processing on the primary frequency modulation load command signal to obtain the frequency modulation load inertial component and the frequency modulation comparison trigger signal. It performs bidirectional function transformation on the main steam pressure signal, and then multiplies the main steam pressure deviation signal after function transformation with one of the function transformation values ​​of the main steam pressure signal to obtain the pressure coupling amount. It also combines the frequency modulation comparison trigger signal to perform operating condition judgment and branch switching, and outputs the frequency modulation pressure correction amount. The signal synthesis and power deviation calculation unit is communicatively connected to the instruction preprocessing and AGC switching unit, the frequency modulation processing and pressure decoupling unit, and the signal acquisition unit, respectively. It is used to synthesize the AGC coordination basic instruction, the frequency modulation load inertia component, the other function transformation value of the main steam pressure, and the frequency modulation pressure correction amount by adding multiple branches, and then adding it twice with the load inertia component. After subtracting it from the generator power value and performing function transformation, the power deviation characteristic quantity is obtained. The PID regulation and command output unit is communicatively connected to the signal synthesis and power deviation calculation unit and the signal acquisition unit, respectively. It is used to input the power deviation characteristic, preset constant set value and load feedforward component as process value, set value and feedforward quantity to the PID module for regulation calculation, and then combine the intelligent control input signal to perform final channel switching, synthesize and output the turbine command under intelligent CCS mode.

7. A turbine command control device for unit coordination under frequency regulation conditions, characterized in that, include: The signal input interface is used to receive the unit load command before primary frequency regulation signal, generator power value, target load set value, primary frequency regulation load command signal, main steam pressure signal, main steam pressure deviation signal, AGC engaged signal, intelligent control engaged signal, and new turbine flow command value. And the first function module, the first first-order inertia module, the first subtraction module, the second first-order inertia module, the first comparison module, the second function module, the third function module, the fourth function module, the fifth function module, the first multiplication module, the first constant module, the first switching module, the second switching module, the first addition module, the second addition module, the second subtraction module, the sixth function module, the second constant module, the first PID module, and the third switching module; in, The unit load command signal output from the signal input interface before primary frequency regulation is respectively connected to the first function module, the first first-order inertial module, and the first subtraction module; the target load setpoint is connected to the first subtraction module. The output of the first subtraction module is connected to the fifth function module; the AGC activated signal, the output of the fifth function module, and the first constant module are respectively connected to the enable trigger terminal, the Y terminal, and the N terminal of the first switching module. The primary frequency regulation load command signal is respectively connected to the second first-order inertial module and the first comparison module; the main steam pressure signal is respectively connected to the second function module and the third function module; the main steam pressure deviation signal is connected to the fourth function module; the output terminals of the third function module and the fourth function module are both connected to the first multiplication module; the output terminals of the first comparison module, the second switching module, and the first multiplication module are respectively connected to the enable trigger terminal, the Y terminal, and the N terminal of the second switching module. The output terminals of the first switching module, the second first-order inertial module, the second function module, and the second switching module are all connected to the first summing module; the output terminals of the first first-order inertial module and the first summing module are all connected to the second summing module; the generator power value and the output terminal of the second summing module are all connected to the second subtraction module; the output terminal of the second subtraction module is connected to the sixth function module; the output terminals of the sixth function module, the second constant module, and the first function module are respectively connected to the PV terminal, STPT terminal, and FF terminal of the first PID module. The intelligent control input signal, the new turbine flow command value, and the output of the first PID module are respectively connected to the enable trigger terminal, Y terminal, and N terminal of the third switching module; the output of the third switching module is connected to the turbine command under intelligent CCS mode.

8. A terminal device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the steps of the turbine command control method for unit coordination under frequency regulation conditions as described in any one of claims 1-5.

9. A computer-readable storage medium having a computer program stored thereon, characterized in that, When the computer program is executed by the processor, it implements the steps of the turbine command control method for unit coordination under frequency regulation conditions as described in any one of claims 1-5.

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