Wind driven generator control method and system adapting to high-power disturbance at random wind speed

Abstract

The invention provides a wind driven generator control method and system adapting to high-power disturbance at random wind speed, and relates to the technical field of wind power generation control. Calculating a first power instruction by combining the frequency variation, the unit adjustment power coefficient and the output power at the previous moment; calculating a second power instruction based on the rotor speed and the optimal gain; and selecting the smaller one of the two as the current active power instruction output. According to the method, by dynamically limiting the output power not to exceed the maximum available mechanical power at the current rotating speed, the technical problems that an existing wind driven generator frequency modulation control method is poor in adaptability and low in safety are solved, and the frequency modulation adaptability and operation safety of a wind power generation system under the complex wind condition are effectively improved.

Description

TECHNICAL FIELD

[0001] The present application relates to the technical field of wind power generation control, in particular to a wind power generator control method and system suitable for large power disturbance under random wind speed. BACKGROUND

[0002] With the increasing proportion of wind power generation in the power system, wind turbine participation in grid frequency regulation (i.e., frequency modulation) has become an important means to maintain the stability of the power system. Wind turbine usually provides fast frequency response through rotor kinetic energy release or pitch angle adjustment. In the scenario of large power disturbance, such as sudden load surge or generator tripping in the grid, the system frequency will drop rapidly, and at this time the wind turbine needs to release a large amount of power to support the grid frequency.

[0003] In the prior art, wind turbine mainly participates in frequency modulation through overspeed control and pitch angle control. Overspeed control releases rotor kinetic energy by temporarily reducing the speed to convert mechanical energy into electrical energy, and pitch angle control changes the aerodynamic power by adjusting the blade angle. The above control methods need to act quickly when the grid frequency drops to provide sufficient power support. However, when the grid experiences large power disturbance, the traditional control strategy is prone to cause the rotor speed of the wind turbine to be excessively reduced, exceeding the safe operating range, and thus causing rotor stall phenomenon. Once the rotor stalls, the wind turbine will not be able to continue to provide power support, but will aggravate the secondary drop of the grid frequency due to its own power drop.

[0004] Therefore, it is urgent to propose a new wind turbine control method that can maximize the frequency modulation capability without triggering rotor stall and has strong robustness to wind speed fluctuations. SUMMARY

[0005] The present application relates to the technical field of wind power generation control, in particular to a wind power generator control method and system suitable for large power disturbance under random wind speed.

[0006] In a first aspect, an embodiment of the present application provides a wind generator control method suitable for large power disturbance under random wind speed, which is applied to a control system of a wind generator, and the method comprises: when a frequency variation determined based on a current time system frequency and a previous time system frequency is greater than zero, obtaining a rotor speed, an optimal gain, and a unit regulation power coefficient and a previous time output power of the wind generator; calculating a first power based on the frequency variation, the previous time output power and the unit regulation power coefficient of the wind generator; calculating a second power based on the rotor speed and the optimal gain; comparing the first power and the second power, and outputting a smaller value as a current active power instruction to a power regulation unit of the wind generator, so as to limit the output power of the wind generator in the frequency modulation process to not exceed the maximum available mechanical power under the current rotor speed.

[0007] In some optional implementations, the method further comprises: when the frequency variation is not greater than zero, terminating the current control logic or maintaining the current active power instruction unchanged; and only when the frequency variation is greater than zero in a plurality of consecutive sampling periods, performing the steps of the method in the first aspect.

[0008] In some optional implementations, the first power is a difference between the previous time output power and a product of the unit regulation power coefficient and the frequency variation, and the second power is a product of the optimal gain and the rotor speed cubed; wherein the optimal gain is a constant or a segmented function pre-calibrated according to aerodynamic characteristics of the wind generator, and is used to map the rotor speed cubed to a theoretical maximum captured power.

[0009] In some optional implementations, the method further comprises: obtaining wind speed data by a wind measuring device installed on the wind generator, and determining wind speed prediction information based on the wind speed data; and the manner of obtaining the unit regulation power coefficient comprises: determining an initial unit regulation power coefficient based on rated parameters of the wind generator and grid frequency modulation requirements; and dynamically adjusting the initial unit regulation power coefficient by an adaptive algorithm based on real-time wind speed data or the output power of the wind generator.

[0010] In some optional implementations, the manner of obtaining the optimal gain further comprises: determining a wind speed interval to which a predicted wind speed belongs according to the wind speed prediction information, and selecting a corresponding gain value from a plurality of preset optimal gain values; and the wind speed interval at least comprises a low wind speed interval, a rated wind speed interval and a high wind speed interval, each wind speed interval corresponding to a different optimal gain value.

[0011] In some optional implementations, the optimal gain is obtained by querying a preset optimal gain mapping table according to the current rotor speed, the optimal gain mapping table being established based on aerodynamic characteristic experimental data of the wind turbine and used to store a corresponding relationship between rotor speed and optimal gain.

[0012] In some optional implementations, the method further includes: when the first power value is greater than the second power value, determining the second power as the current active power, outputting the current active power to a power regulating unit of the wind turbine, and recording a duration; and if the duration in which the first power value is greater than the second power value exceeds a preset threshold, automatically reducing the value of the unit regulating power coefficient.

[0013] In the second aspect, an embodiment of the present application provides a wind turbine control system suitable for large power disturbance under random wind speed, which is used to execute the method of the first aspect, and the system includes: a judging module configured to obtain a rotor speed, an optimal gain, and a unit regulating power coefficient and a previous time output power of a wind turbine when a frequency variation determined based on a current time system frequency and a previous time system frequency is greater than zero; a calculating module configured to calculate a first power based on the frequency variation, the previous time output power and the unit regulating power coefficient of the wind turbine, and calculate a second power based on the rotor speed and the optimal gain; and a comparing module configured to compare the first power and the second power, and output a smaller value as a current active power instruction to a power regulating unit of the wind turbine, so as to limit the output power of the wind turbine in the frequency modulation process to not exceed the maximum available mechanical power under the current rotor speed.

[0014] In the third aspect, an embodiment of the present application provides an electronic device including a memory and a processor, the memory storing a computer program capable of running on the processor, and the processor implements the steps of the method of any one of the first aspect when executing the computer program.

[0015] In the fourth aspect, an embodiment of the present application provides a computer readable storage medium storing computer executable instructions, the computer executable instructions causing the processor to run the method of any one of the first aspect when being invoked and run by the processor.

[0016] The application provides a wind generator control method and system suitable for large-power disturbance under random wind speed. BRIEF DESCRIPTION OF DRAWINGS

[0017] In order to more clearly illustrate the technical solutions of the embodiments of the application, the following will briefly introduce the drawings needed to be used in the embodiments of the application. It should be understood that the following drawings only show some of the embodiments of the application, and therefore should not be regarded as a limitation to the scope. For those skilled in the art, other related drawings can also be obtained without creative labor on the basis of these drawings.

[0018] Figure 1 A flowchart of a wind generator control method suitable for large-power disturbance under random wind speed provided by the embodiment of the application is shown in the figure. Figure 2 A flowchart of another wind generator control method suitable for large-power disturbance under random wind speed provided by the embodiment of the application is shown in the figure. Figure 3 A structure diagram of a wind generator control system suitable for large-power disturbance under random wind speed provided by the embodiment of the application is shown in the figure. Figure 4 A structure diagram of an electronic device provided by the embodiment of the application is shown in the figure. DETAILED DESCRIPTION

[0019] In order to make the purpose, technical solutions and advantages of the embodiments of the application more clear, the technical solutions of the application will be described clearly and completely in combination with the embodiments. Obviously, the described embodiments are only some of the embodiments of the application, but not all the embodiments. Based on the embodiments in the application, all other embodiments obtained by those skilled in the art without creative labor are within the protection scope of the application.

[0020] In existing technologies, wind turbines generally employ frequency regulation control strategies based on frequency deviation or frequency change rate. These methods primarily control the active power output of the wind turbine through fixed power regulation coefficients or simple power limits. However, when dealing with large power disturbances in the power grid, such methods often struggle to balance frequency regulation effectiveness with the wind turbine's own operational safety. Especially under random wind speed conditions, if the wind turbine excessively releases rotor kinetic energy, it can easily lead to a sharp drop in rotor speed, potentially causing rotor stall. When a wind turbine experiences rotor stall, its output power fluctuates drastically, not only failing to provide continuous frequency regulation support but also potentially causing a secondary frequency drop in the power grid, exacerbating system instability risks. Furthermore, traditional power limiting methods have poor adaptability to wind speed changes, and their control effect is often less than ideal in scenarios with large wind speed fluctuations. In other words, the main problem with existing technologies is that under random wind speed conditions, when a large power disturbance occurs in the power grid, traditional wind turbine frequency regulation methods cannot avoid the risk of rotor stall and are prone to causing a secondary frequency drop, thus limiting the full realization of the wind turbine's frequency regulation potential.

[0021] Based on this, the present invention provides a wind turbine control method and control system that are highly adaptable and safe. This method can promptly identify frequency regulation needs during the frequency rise phase and dynamically set the upper limit of power output based on the real-time operating status, avoiding rotor stall caused by over-discharge, thereby improving grid frequency stability.

[0022] To facilitate understanding of this embodiment, a detailed description of a wind turbine control method adapted to high-power disturbances under random wind speeds, as disclosed in this embodiment of the invention, will be provided first. (See [link to relevant documentation]). Figure 1 The diagram shows a flow chart of a wind turbine control method adapted to high-power disturbances under random wind speeds. This method is applied to the control system of a wind turbine and can be executed by electronic equipment. It mainly includes the following steps S102 to S106: Step S102: When the frequency change determined based on the current system frequency and the previous system frequency is greater than zero, obtain the rotor speed, optimal gain, and the unit regulation power coefficient and output power of the wind turbine generator.

[0023] The system frequency can be the grid frequency of the regional or main power system to which the wind turbine is connected, which is usually 50 Hz, and is a key real-time parameter reflecting whether the power generation and power consumption of the entire power system are balanced; the change trend thereof can be used to determine whether there is an active power shortage in the system, thereby triggering the wind turbine to participate in primary frequency modulation response. Specifically, when the system frequency decreases (i.e., the frequency change is less than zero), it indicates that the power generation in the system is insufficient, and the unit output needs to be increased; and when the frequency rises (i.e., the frequency change is greater than zero), it indicates that there is excess power generation in the system, and the unit may need to be operated at a reduced load. In the embodiment, the power limiting mechanism is started only in the frequency rise stage, so as to prevent the wind turbine from releasing inertia or over responding under high wind speed conditions, thereby ensuring the safe operation of the unit.

[0024] After the control system of the wind turbine obtains the current system frequency f and the previous system frequency f0, the frequency change can be obtained by calculating the difference between the two, i.e., the current system frequency f is subtracted from the previous system frequency f0 to obtain Δf (Δf = f - f0).

[0025] The frequency change greater than zero (Δf > 0) indicates that the system frequency has changed from a downward trend to an upward trend, which can be used to identify the frequency recovery stage of the power system after experiencing a large power disturbance, and trigger the protective limitation of the release of the rotor kinetic energy of the wind turbine.

[0026] In one embodiment, before calculating the frequency change Δf, the current system frequency f and the previous system frequency f0 can be filtered to eliminate false positives caused by measurement noise.

[0027] In another embodiment, if the frequency change is not greater than zero (Δf ≤ 0), it indicates that the system frequency is still in a downward trend, and the current control logic is terminated or the current active power instruction is maintained unchanged; and only when the frequency change is greater than zero (Δf > 0) in a plurality of consecutive sampling periods, the subsequent power instruction adjustment logic is started, so as to exclude false actions caused by high-frequency noise interference, thereby improving the control stability. The sampling period can be a fixed or adaptive time interval of 10 ms to 100 ms.

[0028] Step S104, calculating a first power based on the frequency change, the previous output power of the wind turbine, and the unit regulation power coefficient; and calculating a second power based on the rotor speed and the optimal gain.

[0029] In one embodiment, the first power is the difference between the previous output power and the product of the unit regulation power coefficient and the frequency change, and the second power is the product of the optimal gain and the cube of the rotor speed.

[0030] The first power can be used to represent a power adjustment target value expected based on grid frequency regulation requirements, and the calculation formula is: P1=P0-K p △f; P1 is the first power, P0 is the output power of the wind turbine at the previous moment, K p is the unit regulation power coefficient of the wind turbine.

[0031] The second power can be used to represent the maximum sustainable extraction mechanical power of the wind turbine at the current rotor kinetic energy level, and the calculation formula is: P2=K opt w r 3 ; P2 is the second power, K opt is the optimal gain, w r is the rotor speed.

[0032] Wherein, the optimal gain K opt may be a constant or a segmented function pre-calibrated according to the aerodynamic characteristics of the wind turbine, for mapping the third power of the rotor speed to the theoretical maximum capture power.

[0033] For example, in an embodiment, the optimal gain can be obtained by: querying a preset optimal gain mapping table according to the current rotor speed to obtain the optimal gain; wherein the optimal gain mapping table can be established based on the aerodynamic characteristic experimental data of the wind turbine, and is used to store the correspondence between the rotor speed and the optimal gain.

[0034] Preferably, the optimal gain mapping table can be calibrated by wind tunnel experiment or simulation, and the rotor speed is mapped to the optimal gain value (for example, when the rotor speed is 10 rad / s, K opt =0.5). This way can directly use the speed parameter, and the response speed is fast, and the delay of wind speed measurement is avoided.

[0035] In an embodiment, the method can further include: obtaining wind speed data by a wind measuring device installed on the wind turbine, and determining wind speed prediction information based on the wind speed data.

[0036] Wherein, the wind speed prediction information can be obtained by a wind measuring device (such as a laser radar or an ultrasonic anemometer) installed on the wind turbine to obtain real-time wind speed data, and further utilize a time series prediction algorithm (such as ARIMA, LSTM neural network) to generate wind speed prediction information in a future period of time.

[0037] The wind speed prediction information can be used to predict the change of wind energy input of the current wind turbine in advance, so as to further dynamically adjust other control parameters (such as the unit regulation power coefficient Kp, the optimal gain K opt ) or set threshold values.

[0038] Furthermore, in one embodiment, the method of obtaining the unit regulation power coefficient may include: firstly determining the initial unit regulation power coefficient based on the rated parameters of the wind turbine and the grid frequency regulation requirements; and then dynamically adjusting the initial unit regulation power coefficient based on real-time wind speed data or the output power of the wind turbine through an adaptive algorithm.

[0039] For example, the aforementioned initial unit regulation power coefficient can be set according to the frequency dead zone, regulation droop rate and other indicators in the technical regulations issued by the power grid dispatching agency. For example, the value range is 0.5%~10% / Hz, and the specific value is related to the unit capacity, the short-circuit ratio at the grid connection point and the regional frequency regulation requirements.

[0040] The aforementioned adaptive algorithm can employ fuzzy control, model predictive control (MPC), or an online learning strategy based on neural networks. It utilizes wind speed sequences and historical power response data within a sliding time window to adjust the unit regulation power coefficient in real time, ensuring frequency modulation sensitivity while avoiding frequent limit-breaking actions. For example, when the actual power adjustment is detected to be close to the maximum available mechanical power boundary over multiple consecutive sampling periods, the unit regulation power coefficient Kp is automatically reduced to improve system stability margin.

[0041] Furthermore, in one embodiment, the method of obtaining the optimal gain may include: determining the wind speed range to which the predicted wind speed belongs based on wind speed prediction information, and selecting the corresponding gain value from a plurality of preset optimal gain values; the wind speed range includes at least a low wind speed range, a rated wind speed range, and a high wind speed range, and each wind speed range corresponds to a different optimal gain value.

[0042] The aforementioned wind speed range can be pre-defined based on the aerodynamic characteristics analysis and on-site operational data statistics of the wind turbine. For example, this wind speed range can include at least the following: a low wind speed range (below the rated wind speed and with the blade tip speed ratio close to the optimal value, and the power curve near its peak), corresponding to a higher optimal gain K. opt Value; the optimal gain K corresponds to the rated wind speed transition zone (close to rated power output, approximately 85%~100% of rated power). opt Value; in high wind speed areas (above the rated wind speed and with pitch control enabled, typically the operating condition after pitch adjustment is engaged), the corresponding optimal gain K is lower. opt Value; optimal gain K within each interval opt The values ​​can be obtained by fitting multiple operating conditions under different turbulence intensities using actual unit data or simulation platforms, and stored in the controller lookup table module.

[0043] Step S106: Compare the magnitudes of the first power and the second power, and output the smaller value as the current active power command to the power regulation unit of the wind turbine generator, so as to limit the output power of the wind turbine generator during the frequency regulation process to not exceed the maximum available mechanical power at the current speed.

[0044] In this embodiment, the first power can be used to characterize the target power of the inertial response driven by the system frequency rise rate, and its calculation formula is: P1=P0-K p △f; The second power can be used to characterize the maximum sustainable mechanical power extracted by the wind turbine at the current rotor kinetic energy level, and its calculation formula is: P2=K opt w r 3 By selecting the minimum value min(P1, P2) between the first and second power values ​​as the final active power command, it is output to the power regulation unit of the wind turbine generator. This limits the output power of the wind turbine generator during frequency regulation to not exceed the maximum usable mechanical power that can be extracted at the current speed, thereby avoiding rotor stall due to excessive release of kinetic energy. It can both respond to the system frequency regulation signal and prevent the risk of speed drop or even stall due to blindly increasing power.

[0045] Furthermore, the comparison process between the first and second power outputs can be completed by the wind turbine main control system within a millisecond-level control cycle. The comparison result can be used to generate a PWM modulation signal via a digital signal processor (DSP) or programmable logic controller (PLC), which is then transmitted to the active power closed-loop control loop of the converter to achieve rapid power point tracking. Simultaneously, the control system can record the source of each power command selection (i.e., from P1 or P2) for subsequent operational status diagnosis and control performance evaluation.

[0046] In summary, the wind turbine control method for adapting to high-power disturbances under random wind speeds provided by the embodiments of the present invention can activate frequency regulation control logic when a positive change in system frequency is detected (i.e., frequency begins to recover). By combining the theoretical maximum capture power corresponding to the current rotor speed as a constraint condition, the actual output power is limited to not exceeding the safety boundary, thereby achieving the goal of both rapid response and prevention of rotor stall, and thus improving the stability of grid frequency.

[0047] In one embodiment, the above method may further include: when the first power value is greater than the second power value, determining the second power as the current active power, outputting the current active power to the power regulation unit of the wind turbine generator, and recording the duration; if the duration for which the first power value is greater than the second power value exceeds a preset threshold, then automatically reducing the value of the unit regulation power coefficient.

[0048] In this embodiment, the aforementioned preset threshold can be set to a range of 5 to 30 seconds depending on the fan type and operating environment, used to distinguish between transient fluctuations and continuous frequency regulation pressure. When a continuous overshoot demand is determined, a yield mechanism for the unit regulation power coefficient can be activated, for example, by gradually reducing the unit regulation power coefficient K in fixed steps (e.g., decreasing by 0.5% / Hz each time) or using a proportional-integral method.p The value is adjusted until P1≤P2 is true or the minimum allowable coefficient is reached. This mechanism can effectively alleviate the problem of frequent power limitation triggered in high wind speed areas, avoid repeated oscillations of the controller, and improve the robustness of the overall frequency modulation response.

[0049] Furthermore, in another embodiment, the aforementioned automatic reduction process can be configured with hysteresis logic to prevent frequent back-and-forth parameter adjustments. For example, after the value of the unit adjustment power coefficient is reduced, the system frequency must be allowed to gradually return to its original value only after it has recovered to the normal range and maintained for a certain period of time (e.g., 2 minutes). In addition, the above adjustment process can be logged via a human-machine interface (HMI) or a remote monitoring system (SCADA) for maintenance personnel to trace and analyze.

[0050] In another embodiment, after the duration of the first power value being greater than the second power value exceeds a preset threshold and the value of the unit adjustment power coefficient is automatically reduced, the above method may further include: sending an alarm signal to the local monitoring terminal of the wind turbine and the remote operation and maintenance platform of the central control center, prompting maintenance personnel to check the system status to investigate whether there are problems such as abnormal wind conditions, sensor drift, excessive power prediction deviation, or grid frequency misjudgment. The alarm signal may include key information such as event type, occurrence time, duration, involved turbine number, wind speed at the time, rotor speed, original unit adjustment power coefficient, and adjusted value.

[0051] This invention proposes a wind turbine control method that can be implemented without additional hardware modifications and only through software upgrades. It can judge the dynamic trend of system frequency changes in real time and set the optimal power output upper limit in combination with the rotor kinetic energy state. In this way, while ensuring the safe operation of the rotor, it maximizes the frequency regulation potential of the wind turbine and effectively improves the system frequency stability.

[0052] This invention also provides an application example of a wind turbine control method adapted to high-power disturbances under random wind speeds, see [link to relevant documentation]. Figure 2 The flowchart shown is another wind turbine control method adapted to high-power disturbances under random wind speeds. This method mainly includes the following steps S201 to S207: Step S201: Obtain the current system frequency f and the system frequency f0 of the previous sampling period; Step S202: Calculate the frequency change Δf = f - f0; This difference reflects the rate, direction, and magnitude of change in system frequency. If Δf ≤ 0, it indicates that the system frequency is still decreasing or remaining stable, and the wind turbine can maintain its original operating mode (such as maximum power point tracking, MPPT) and terminate the execution of this control logic. If Δf > 0, it indicates that the system frequency is rising, which usually means that a frequency regulation response has been initiated after a large disturbance. At this time, the wind turbine should assess whether to continue releasing energy.

[0053] Step S203: Determine whether Δf is greater than 0; If not (i.e., Δf≤0), then terminate the current control logic; if yes (i.e., Δf>0), then execute subsequent steps to obtain key operating parameters. When Δf > 0, the following parameters can be read from the wind turbine sensors and database: Fan unit regulating power coefficient K p : Represents the power adjustment corresponding to a unit frequency deviation, in MW / Hz; current rotor speed w r : Can be measured by an encoder or speed sensor, in rad / s or rpm; Optimal gain K opt : A proportional constant that can be used to map the cube of the rotor speed to the theoretical maximum mechanical power, in units of W·s³ / rad³; the output power of the fan at the previous moment P0: the actual active power output value of the previous control cycle, in units of MW.

[0054] Step S204, calculate the first power P1 = P0 - K p Δf and the second power P2=K opt w r 3 ; Step S205: Determine whether the first power P1 is greater than the second power P2; Step S206: If yes, then determine the current active power command P. ref =P2=K opt w r 3 ; Step S207: If not, determine the current active power command P. ref =P1=P0-K p △f.

[0055] This invention first considers the system frequency variation trend Δf and the preset unit adjustment power coefficient K. p The ideal frequency modulation power command P1 = P0 - K is calculated. p △f; However, to prevent this command from causing excessive rotor deceleration or even stalling under high-power disturbances, it is further compared with the safe power limit P2 = K determined based on the current rotor speed. opt w r 3 By comparing the values ​​and selecting a power value not exceeding the upper limit as the final active power command, the optimal balance between frequency regulation capability and operational safety is achieved.

[0056] The method provided in this invention can avoid rotor stall that may occur when the wind turbine participates in frequency regulation under high-power disturbances, thus maximizing the frequency regulation capability of the wind turbine. Furthermore, the method has low sensitivity to wind speed fluctuations and can provide effective control within a certain range of wind speed changes. The method can achieve the optimal minimum frequency, improve the average ROCOF and steady-state frequency. Moreover, the method can be implemented without installing any other hardware, only by upgrading the wind turbine control software, resulting in low modification costs and significant benefits.

[0057] Based on the same inventive concept, this invention also provides a wind turbine control system that adapts to high-power disturbances under random wind speeds. See [link to relevant documentation]. Figure 3 As shown, the system mainly includes the following parts: The judgment module 310 is used to obtain the rotor speed, optimal gain, and the unit regulation power coefficient and output power of the wind turbine when the frequency change determined based on the current system frequency and the previous system frequency is greater than zero. Calculation module 320 is used to calculate the first power based on the frequency change, the previous output power of the wind turbine, and the unit regulation power coefficient; and to calculate the second power based on the rotor speed and the optimal gain. The comparison module 330 is used to compare the magnitudes of the first power and the second power, and outputs the smaller value as the current active power command to the power regulation unit of the wind turbine generator, so as to limit the output power of the wind turbine generator during the frequency regulation process to not exceed the maximum available mechanical power at the current speed.

[0058] The system provided in this embodiment of the invention has the same implementation principle and technical effects as the aforementioned method embodiment. For the sake of brevity, any parts not mentioned in the system embodiment can be referred to the corresponding content in the aforementioned method embodiment.

[0059] Based on the same inventive concept, embodiments of the present invention also provide an electronic device, specifically, the electronic device includes a processor and a storage device; the storage device stores a computer program, and the computer program, when run by the processor, executes the method described in any of the above embodiments.

[0060] Figure 4 This is a schematic diagram of an electronic device provided in an embodiment of the present invention. The electronic device 400 includes: a processor 410, a memory 420, a communication interface 430, and a bus 440. The memory 420 stores machine-readable instructions that can be executed by the processor 410. When the electronic device is running, the processor 410 communicates with the memory 420 through the bus 440. The processor 410 executes the machine-readable instructions to perform the steps of the wind turbine control method adapted to high-power disturbances under random wind speeds as described above.

[0061] Specifically, the memory 420 and processor 410 can be general-purpose memory and processor, without any specific limitations. When the processor 410 runs the computer program stored in the memory 420, it can execute the wind turbine control method adapted to high-power disturbances under random wind speeds.

[0062] Processor 410 may be an integrated circuit chip with signal processing capabilities. In implementation, each step of the above method can be completed by the integrated logic circuitry in the hardware of processor 410 or by instructions in software form. The processor 410 may be a general-purpose processor, including a Central Processing Unit (CPU), a Network Processor (NP), etc.; it may also be a Digital Signal Processor (DSP), an Application Specific Integrated Circuit (ASIC), a Field-Programmable Gate Array (FPGA), or other programmable logic devices, discrete gate or transistor logic devices, or discrete hardware components. It can implement or execute the methods, steps, and logic block diagrams disclosed in the embodiments of this invention. The general-purpose processor may be a microprocessor or any conventional processor. The steps of the methods disclosed in the embodiments of this invention can be directly manifested as execution by a hardware decoding processor, or execution by a combination of hardware and software modules in the decoding processor. The software module can reside in a mature storage medium in the art, such as random access memory, flash memory, read-only memory, programmable read-only memory, electrically erasable programmable memory, or registers. This storage medium is located in memory 420, and processor 410 reads the information from memory 420 and, in conjunction with its hardware, completes the steps of the above method.

[0063] Corresponding to the above-described wind turbine control method for adapting to high-power disturbances under random wind speeds, this embodiment of the invention also provides a computer-readable storage medium storing machine-executable instructions. When the machine-executable instructions are invoked and executed by a processor, the machine-executable instructions cause the processor to perform the steps of the above-described wind turbine control method for adapting to high-power disturbances under random wind speeds.

[0064] The wind turbine control system adapted to high-power disturbances under random wind speeds provided in this embodiment of the invention can be specific hardware on the device or software or firmware installed on the device. The system provided in this embodiment of the invention has the same implementation principle and technical effects as the aforementioned method embodiments. For the sake of brevity, any parts not mentioned in the system embodiments can be referred to the corresponding content in the aforementioned method embodiments. Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working processes of the systems, devices, and units described above can all be referred to the corresponding processes in the above method embodiments, and will not be repeated here.

[0065] In the embodiments provided by this invention, it should be understood that the disclosed apparatus and method can be implemented in other ways. The apparatus embodiments described above are merely illustrative. For example, the division of units is only a logical functional division, and there may be other division methods in actual implementation. Furthermore, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Additionally, the coupling or direct coupling or communication connection shown or discussed may be through some communication interface; the indirect coupling or communication connection between apparatuses or units may be electrical, mechanical, or other forms.

[0066] For example, the flowcharts and block diagrams in the accompanying drawings illustrate the architecture, functionality, and operation of possible implementations of apparatus, methods, and computer program products according to various embodiments of the present invention. In this regard, each block in a flowchart or block diagram may represent a module, segment, or portion of code, which contains one or more executable instructions for implementing the specified logical function. It should also be noted that in some alternative implementations, the functions indicated in the blocks may occur in a different order than those indicated in the drawings. For example, two consecutive blocks may actually be executed substantially in parallel, and they may sometimes be executed in reverse order, depending on the functions involved. It should also be noted that each block in the block diagrams and / or flowcharts, and combinations of blocks in the block diagrams and / or flowcharts, may be implemented using a dedicated hardware-based system that performs the specified function or action, or using a combination of dedicated hardware and computer instructions.

[0067] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of this embodiment, depending on actual needs.

[0068] In addition, the functional units in the embodiments provided by the present invention can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit.

[0069] If a function is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this invention, or the part that contributes to the prior art, or a part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause an electronic device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the various embodiments of this invention. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0070] It should be noted that similar labels and letters in the following figures indicate similar items. Therefore, once an item is defined in one figure, it does not need to be further defined and explained in subsequent figures.

[0071] In the description of this invention, it should be noted that the terms "center," "upper," "lower," "left," "right," "vertical," "horizontal," "inner," and "outer," etc., indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings, or the orientation or positional relationship commonly used when the product of this invention is in use. They are only for the convenience of describing this invention and simplifying the description, and do not indicate or imply that the device or element referred to must have a specific orientation, or be constructed and operated in a specific orientation, and therefore should not be construed as a limitation of this invention. In addition, the terms "first," "second," "third," etc., are only used to distinguish descriptions and should not be construed as indicating or implying relative importance.

[0072] In the description of this invention, it should also be noted that, unless otherwise explicitly specified and limited, the terms "set," "install," "connect," and "link" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral connection; they can refer to a mechanical connection or an electrical connection; they can refer to a direct connection or an indirect connection through an intermediate medium; and they can refer to the internal connection of two components. Those skilled in the art can understand the specific meaning of the above terms in this invention based on the specific circumstances.

[0073] Finally, it should be noted that the above embodiments are merely specific implementations of the present invention, used to illustrate the technical solutions of the present invention, and not to limit it. The scope of protection of the present invention is not limited thereto. Although the present invention has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that any person skilled in the art can still modify or easily conceive of changes to the technical solutions described in the foregoing embodiments within the scope of the technology disclosed in the present invention, or make equivalent substitutions for some of the technical features; and these modifications, changes, or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present invention. All should be covered within the scope of protection of the present invention.

Claims

1. A wind turbine control method adaptable to high-power disturbances under random wind speeds, characterized in that, A control system applied to a wind turbine generator, the method comprising: When the frequency change determined based on the current system frequency and the previous system frequency is greater than zero, the rotor speed, optimal gain, and the unit regulation power coefficient and output power of the wind turbine generator at the previous moment are obtained. The first power is calculated based on the frequency change, the previous output power of the wind turbine, and the unit regulation power coefficient; the second power is calculated based on the rotor speed and the optimal gain. The magnitudes of the first power and the second power are compared, and the smaller value is output as the current active power command to the power regulation unit of the wind turbine generator, so as to limit the output power of the wind turbine generator during the frequency regulation process to not exceed the maximum available mechanical power at the current speed.

2. The method according to claim 1, characterized in that, The method further includes: when the frequency change is not greater than zero, terminating the current control logic or maintaining the current active power command unchanged; The steps of the method described in claim 1 are performed only when the frequency change is greater than zero in multiple consecutive sampling periods.

3. The method according to claim 2, characterized in that, The first power is the difference between the output power at the previous moment and the product of the unit adjustment power coefficient and the frequency change; the second power is the product of the optimal gain and the cube of the rotor speed. The optimal gain is a constant or piecewise function pre-calibrated based on the aerodynamic characteristics of the wind turbine, used to map the cube of the rotor speed to the theoretical maximum captured power.

4. The method according to claim 3, characterized in that, The method further includes: acquiring wind speed data through a wind measuring device installed on a wind turbine, and determining wind speed prediction information based on the wind speed data; The methods for obtaining the unit adjustment power coefficient include: The initial unit regulation power coefficient is determined based on the rated parameters of the wind turbine and the frequency regulation requirements of the power grid. Based on real-time wind speed data or the output power of the wind turbine, the initial unit adjustment power coefficient is dynamically adjusted using an adaptive algorithm.

5. The method according to claim 4, characterized in that, The methods for obtaining the optimal gain also include: Based on the wind speed prediction information, the wind speed range to which the predicted wind speed belongs is determined, and the corresponding gain value is selected from a plurality of preset optimal gain values; the wind speed range includes at least a low wind speed range, a rated wind speed range, and a high wind speed range, and each wind speed range corresponds to a different optimal gain value.

6. The method according to claim 1, characterized in that, The methods for obtaining the optimal gain include: Based on the current rotor speed, a preset optimal gain mapping table is queried to obtain the optimal gain. The optimal gain mapping table is established based on the aerodynamic characteristic experimental data of the wind turbine and is used to store the correspondence between rotor speed and optimal gain.

7. The method according to claim 1, characterized in that, The method further includes: When the first power value is greater than the second power value, the second power is determined to be the current active power, the current active power is output to the power regulation unit of the wind turbine, and the duration is recorded; If the duration for which the first power value is greater than the second power value exceeds a preset threshold, the value of the unit adjustment power coefficient will be automatically reduced.

8. A wind turbine generator control system adaptable to high-power disturbances under random wind speeds, characterized in that, The system for performing the method according to any one of claims 1 to 7, the system comprising: The judgment module is used to obtain the rotor speed, optimal gain, and the unit regulation power coefficient and output power of the wind turbine when the frequency change determined based on the current system frequency and the previous system frequency is greater than zero. The calculation module is used to calculate the first power based on the frequency change, the previous output power of the wind turbine, and the unit regulation power coefficient; and to calculate the second power based on the rotor speed and the optimal gain. The comparison module is used to compare the magnitudes of the first power and the second power, and output the smaller value as the current active power command to the power regulation unit of the wind turbine generator, so as to limit the output power of the wind turbine generator during the frequency regulation process to not exceed the maximum available mechanical power at the current speed.

9. An electronic device comprising a memory and a processor, wherein the memory stores a computer program executable on the processor, characterized in that, When the processor executes the computer program, it implements the steps of the method described in any one of claims 1 to 7.

10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer-executable instructions that, when invoked and executed by a processor, cause the processor to perform the method according to any one of claims 1 to 7.

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