Wind turbine generator control method and system based on instability risk analysis and electronic equipment

Abstract

The invention provides a wind turbine generator control method and system based on instability risk analysis and electronic equipment, and relates to the technical field of wind power generation control, and the method comprises the steps: calculating the tip speed ratio and the variation thereof by obtaining the wind speed and the wind wheel rotating speed at the current moment and the previous moment in real time; determining the pneumatic torque variation by combining the pneumatic torque at the current moment and the pneumatic torque at the previous moment; and generating a curve change slope reflecting the operation state, and judging whether the curve change slope is greater than zero or not. If the slope is larger than zero, it is judged that the unit has the instability risk, and control parameters are adjusted immediately to maintain stable operation. According to the method, the instability risk can be recognized in advance, the control response speed is increased, the problems of instability recognition lagging and untimely regulation in the prior art are solved, and the operation stability and safety of the wind turbine generator are improved.

Description

Technical Field

[0001] This invention relates to the field of wind power generation control technology, and more specifically, to a wind turbine control method, system, and electronic equipment based on instability risk analysis. Background Technology

[0002] With the continuous development of wind power generation technology, the stability control of wind turbines under complex operating conditions has received increasing attention. In actual operation, wind turbines may need to reduce their speed due to requirements such as noise reduction, frequency regulation, and load optimization. However, speed reduction can lead to an imbalance in the dynamic matching of speed and torque, thereby triggering the risk of turbine instability. Since instability is difficult to accurately identify within an extremely short timescale, and stabilization measures must be implemented immediately after instability occurs, this poses a severe challenge to the control system. Especially under variable wind speed conditions, multi-mode switching control strategies are required to achieve accurate power curve tracking, making smooth transition control under instability conditions even more complex. Therefore, advanced control methods are urgently needed to ensure that wind turbines maintain stable operation under various conditions. Summary of the Invention

[0003] The purpose of this invention is to provide a wind turbine control method, system, and electronic device based on instability risk analysis, so as to solve the technical problems of lagging instability identification and untimely control response in the prior art.

[0004] In a first aspect, embodiments of the present invention provide a wind turbine control method based on instability risk analysis, applied to the control system of a wind turbine. The method includes: determining the tip speed ratio at the current moment, the tip speed ratio at the previous moment, and the change in tip speed ratio based on the acquired wind speed and rotor speed of the wind turbine at the current moment, and the wind speed and rotor speed of the wind turbine at the previous moment; determining the change in aerodynamic torque based on the acquired aerodynamic torque of the wind turbine at the current moment and the aerodynamic torque at the previous moment; generating a curve slope based on the change in tip speed ratio and the change in aerodynamic torque, and determining whether the slope of the curve is greater than 0; if so, the wind turbine has an instability risk, and adjusting the control parameters of the wind turbine to maintain stable operation of the wind turbine.

[0005] In some optional implementations, the above method further includes: if the slope of the curve is not greater than 0, then the wind turbine is in a stable state, and the wind energy utilization coefficient of the current wind turbine is determined to be the maximum theoretical wind energy utilization coefficient.

[0006] In some optional implementations, the formula for calculating the tip speed ratio at the current moment, based on the wind speed and the rotor speed of the wind turbine, is: λ1=(ω1·R) / V1; where V1 is the wind speed at the current moment, ω1 is the rotor speed of the wind turbine at the current moment, and R is the blade radius.

[0007] In some optional implementations, the aerodynamic torque of the wind turbine is calculated by the following formula: CT = 2P / (ρπR²v³); where P is the mechanical power at the corresponding moment, ρ is the air density, R is the blade radius, and v is the wind speed at the corresponding moment; the mechanical power P is obtained by dividing the generator output power by the transmission chain efficiency, or by direct measurement by the main shaft torque sensor.

[0008] In some optional implementations, the control parameters of the aforementioned wind turbine include torque control gain; adjusting the control parameters of the aforementioned wind turbine includes: when the aforementioned wind turbine has an instability risk, reducing the value of the aforementioned torque control gain by a preset adjustment range to reduce the growth rate of the generator torque command; the aforementioned preset adjustment range is set according to the magnitude of the slope of the aforementioned curve change: when the slope of the aforementioned curve change is greater than a first preset threshold, the aforementioned torque control gain is reduced by a linear decay method; when the slope of the aforementioned curve change is greater than or equal to a second preset threshold and less than or equal to a first preset threshold, the aforementioned torque control gain is reduced by a segmented step-down method; wherein, the first preset threshold is greater than the second preset threshold.

[0009] In some optional implementations, the above method further includes: monitoring the actual speed of the blade tip in real time during the operation of the wind turbine, and performing deceleration control when the actual speed of the blade tip exceeds a preset blade tip speed limit; wherein the blade tip speed limit is determined based on at least one of the following factors: material strength of the wind turbine blade, aerodynamic noise limit, and structural load limit.

[0010] In some optional implementations, the aforementioned tip speed ratio change and aerodynamic torque change are determined based on a uniform time sampling period.

[0011] Secondly, embodiments of the present invention provide a wind turbine control system based on instability risk analysis, used to execute the method described in the first aspect. The system includes: a determining module, used to determine the tip speed ratio at the current moment, the tip speed ratio at the previous moment, and the change in tip speed ratio based on the acquired wind speed and wind turbine rotor speed at the current moment, and the wind speed and wind turbine rotor speed at the previous moment; a calculating module, used to determine the change in aerodynamic torque based on the acquired aerodynamic torque of the wind turbine at the current moment and the aerodynamic torque at the previous moment; and a judging module, used to generate a curve slope based on the change in tip speed ratio and the change in aerodynamic torque, and judge whether the slope of the curve is greater than 0; if so, the wind turbine has an instability risk, and the control parameters of the wind turbine are adjusted to maintain the stable operation of the wind turbine.

[0012] Thirdly, embodiments of the present invention provide an electronic device, including a memory and a processor, wherein the memory stores a computer program that can run on the processor, and the processor executes the computer program to implement the steps of the method described in any of the first aspects above.

[0013] Fourthly, embodiments of the present invention provide a computer-readable storage medium storing computer-executable instructions, which, when invoked and executed by a processor, cause the processor to perform the method described in any of the first aspects above.

[0014] This invention provides a wind turbine control method, system, and electronic equipment based on instability risk analysis. The method acquires wind speed and rotor speed in real time compared to the previous moment, calculates the tip speed ratio and its change, and combines this with the aerodynamic torque from the previous moment to determine the change in aerodynamic torque. It then generates a curve reflecting the operating state, and determines whether the slope is greater than zero. If the slope is greater than zero, the turbine is deemed to have an instability risk, and control parameters are adjusted to maintain stable operation. This invention can identify instability risks in advance, improve control response speed, and solve the problems of delayed instability identification and untimely adjustment in existing technologies, thereby improving the stability and safety of wind turbine operation. Attached Figure Description

[0015] To more clearly illustrate the technical solutions of the embodiments of the present invention, the accompanying drawings used in the embodiments of the present invention will be briefly introduced below. It should be understood that the following drawings only show some embodiments of the present invention and should not be regarded as a limitation on the scope. For those skilled in the art, other related drawings can be obtained based on these drawings without creative effort.

[0016] Figure 1 A flowchart illustrating a wind turbine control method based on instability risk analysis provided in an embodiment of the present invention; Figure 2 A flowchart illustrating another wind turbine control method based on instability risk analysis provided in an embodiment of the present invention; Figure 3 A schematic diagram of a wind turbine control system based on instability risk analysis is provided for an embodiment of the present invention; Figure 4 This is a schematic diagram of the structure of an electronic device provided in an embodiment of the present invention. Detailed Implementation

[0017] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the technical solutions of the present invention will be clearly and completely described below in conjunction with the embodiments. Obviously, the described embodiments are only some embodiments of the present invention, not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0018] During wind turbine operation, speed regulation is frequently required due to multiple factors, including noise reduction optimization, frequency adjustment, and load control. However, reduced speed can lead to dynamic speed-torque mismatch, potentially inducing turbine instability. Real-time identification of this risk presents significant technical challenges, and stabilization control strategies must be implemented immediately upon instability. Notably, achieving power curve tracking under different wind speed conditions requires differentiated control algorithms, making smooth transition control during instability particularly complex. Therefore, there is an urgent need to establish an efficient dynamic control system for wind turbines to ensure stable operation across the entire operating range.

[0019] Based on this, the present invention provides a wind turbine control method, system and electronic device based on instability risk analysis to solve the technical problems of instability identification lag and untimely control response in the prior art. It has the technical advantages of low implementation cost, fast response speed and strong adaptability, and is suitable for various wind turbine operation scenarios that require high reliability and stable control.

[0020] To facilitate understanding of this embodiment, a wind turbine control method based on instability risk analysis disclosed in this invention will first be described in detail. (See [link to relevant documentation]). Figure 1 The diagram shows a flow chart of a wind turbine control method based on instability risk analysis. This method can be executed by electronic equipment and mainly includes the following steps S102 to S106: Step S102: Based on the current wind speed and wind turbine rotor speed, as well as the previous wind speed and wind turbine rotor speed, determine the current tip speed ratio, the previous tip speed ratio, and the change in tip speed ratio.

[0021] The wind speed at the current moment and the previous moment can be obtained by real-time data collection using wind speed sensors (such as ultrasonic anemometers or cup anemometers) installed in the wind turbine system. It should be noted that the wind speed data is recorded with a uniform time sampling period to ensure time synchronization and comparability between the current and previous moment's data.

[0022] The wind turbine rotor speed can be obtained as a real-time speed signal by measuring the main shaft encoder or speed sensor of the wind turbine. It is also collected with the same uniform time sampling period as the wind speed data to ensure the consistency of multi-source sensor data in time sequence.

[0023] Based on this, the tip speed ratio at the current moment and the previous moment can be calculated, and the change in tip speed ratio can be determined based on the calculation results.

[0024] In one embodiment, the formula for calculating the tip speed ratio at the current moment, based on the wind speed and the rotor speed of the wind turbine, is: λ1=(ω1·R) / V1; where V1 is the wind speed at the current moment, ω1 is the rotor speed of the wind turbine at the current moment, and R is the blade radius.

[0025] Based on the same principle, the tip speed ratio at the previous moment can be obtained as: λ0=(ω0·R) / V0; where V0 is the wind speed at the previous moment, ω0 is the wind turbine rotation speed at the previous moment, and R is the blade radius.

[0026] Furthermore, the change in tip speed ratio can be calculated by the difference between the tip speed ratio at the previous moment and the tip speed ratio at the current moment, i.e.: Δλ = λ0 - λ1.

[0027] Step S104: Based on the aerodynamic torque of the wind turbine at the current moment and the aerodynamic torque at the previous moment, determine the change in aerodynamic torque.

[0028] In one embodiment, the aerodynamic torque of the wind turbine can be calculated using the following formula: CT = 2P2 / (ρπR²v³); where P2 is the mechanical power at the corresponding moment, ρ is the air density, R is the blade radius, and v is the wind speed at the corresponding moment; the mechanical power P2 can be obtained by dividing the generator output power by the transmission chain efficiency, or by direct measurement by the main shaft torque sensor.

[0029] Specifically, the mechanical power P2 at the corresponding moment is obtained by dividing the generator output power by the transmission chain efficiency. This can be achieved by using the real-time acquired generator output power P1 as the input and performing a reverse calculation based on the transmission chain efficiency coefficient η under the current operating conditions to obtain the mechanical power P2 on the wind turbine side = P1 / η. The value of η can be determined based on the unit calibration curve or online lookup table method, taking into account the influence of factors such as load and temperature to improve the accuracy of power restoration.

[0030] The blade radius R, as a design parameter of the wind turbine, can be pre-stored in the control system and directly called upon during system initialization or control algorithm startup. Air density ρ can be calculated jointly from measurements by ambient temperature, air pressure, and humidity sensors, or approximated using historical averages. The wind speed V at the corresponding moment can be acquired in real-time by a wind speed sensor installed in the wind turbine system, as described in the embodiment of step S102 above.

[0031] In this embodiment, the method of obtaining aerodynamic torque does not require the additional installation of blade load or spindle torque sensors, which has the advantages of low cost and strong engineering feasibility.

[0032] Furthermore, the change in aerodynamic torque can be calculated by the difference between the aerodynamic torque at the previous moment and the aerodynamic torque at the current moment, i.e.: △CT=CT0-CT1.

[0033] In one embodiment, the changes in tip speed ratio and aerodynamic torque are determined based on a uniform time sampling period. For example, this sampling period is 10ms to 100ms to ensure that the dynamic response capability of the slope of the subsequently generated curve meets the requirements of real-time control.

[0034] Step S106: Generate the curve slope based on the change in tip speed ratio and the change in aerodynamic torque, and determine whether the curve slope is greater than 0; if so, the wind turbine is at risk of instability, and adjust the control parameters of the wind turbine to maintain stable operation of the wind turbine.

[0035] In this embodiment, the slope of the curve can be obtained by dividing the change in aerodynamic torque by the change in tip speed ratio, i.e., K = ΔCT / Δλ. The slope K of the CT-λ curve can be used to represent the trend and sensitivity of the aerodynamic torque as the tip speed ratio changes dynamically under the current operating condition, reflecting the stability characteristics of the aerodynamic properties of the wind turbine during speed reduction or wind speed change.

[0036] In this embodiment, the slope K of the aforementioned curve is used as an early criterion for determining the instability trend. It can be used to identify the stable state of the unit in real time. Specifically, when the wind turbine is operating normally and in the optimal power tracking region, as the tip speed ratio decreases (such as due to active speed reduction control), the aerodynamic torque usually shows a downward trend. At this time, ΔCT and Δλ have the same sign, the slope K>0, and the system exhibits positive feedback characteristics, which can easily lead to speed and torque mismatch and instability. When K<0, or either ΔCT or Δλ is equal to 0, it indicates that the aerodynamic torque increases or remains stable as the tip speed ratio decreases, the system has self-recovery capability, and is in a relatively stable state.

[0037] Therefore, by calculating and monitoring the sign of the curve slope K in real time, potential risks can be identified before instability occurs significantly, thereby triggering an early intervention mechanism and avoiding the response lag problem caused by relying on oscillation signal detection in traditional methods.

[0038] The above judgment criteria do not rely on absolute numerical thresholds, but rather on the directionality of dynamic change trends. They have strong robustness and adaptability to operating conditions, and are particularly suitable for stability prediction and active control under complex transient processes.

[0039] In one embodiment, the control parameters of the wind turbine may include torque control gain; preferably, adjusting the control parameters of the wind turbine may include: when the wind turbine is at risk of instability, reducing the value of torque control gain by a preset adjustment range to reduce the growth rate of generator torque command, thereby enabling the wind turbine to achieve a smooth transition under instability risk.

[0040] The aforementioned preset adjustment range can be set according to the magnitude of the curve change slope: when the curve change slope is greater than the first preset threshold, the torque control gain is reduced by linear decay; when the curve change slope is greater than or equal to the second preset threshold and less than or equal to the first preset threshold, the torque control gain is reduced by segmented step-down; wherein, the first preset threshold is greater than the second preset threshold.

[0041] As a concrete example, the first preset threshold can be an empirical value, such as 0.8, based on the slope near the starting point of the downward section of the unit's aerodynamic characteristic curve; the second preset threshold can be a critical value near the system stability boundary, such as 0.5. These thresholds can be obtained through simulation modeling, wind tunnel testing, or statistical analysis of field operation data, and can be individually tuned according to the blade aerodynamic design, transmission chain characteristics, and control objectives of different turbine models.

[0042] For example, when K > 0.8, a linear decay method is used to reduce the torque control gain. This means that the current torque control gain Kopt is gradually reduced at a constant rate according to time or iteration step size, such as reducing the original value by 2% every 100ms, until K ≤ 0.8 or the minimum allowable gain limit is reached. This method is suitable for scenarios with strong instability trends, and avoids new dynamic shocks caused by sudden changes in control quantity through smooth adjustment.

[0043] When 0.5 ≤ K ≤ 0.8, a segmented, step-wise reduction of the torque control gain is adopted. That is, based on the specific range where the slope K of the curve changes, the torque control gain is reduced to a preset lower level in one go. For example, if K ∈ (0.6, 0.8], the torque control gain is reduced by 15%; if K ∈ (0.5, 0.6], it is reduced by 10%. This method has a rapid response and clear logic, and is suitable for rapid suppression of moderate instability risks.

[0044] In one embodiment, the above method may further include: if the slope of the curve change is not greater than 0 (including the slope of the curve change being less than 0, and either the change in tip speed ratio or the change in torque being equal to 0), then the wind turbine is in a stable state, and the wind energy utilization coefficient Cp of the current wind turbine is determined to be the maximum theoretical wind energy utilization coefficient Cpmax.

[0045] One method for determining the maximum theoretical wind energy utilization coefficient Cpmax is as follows: based on the aerodynamic design parameters of the wind turbine blades, the Cp-λ performance curve is obtained by consulting a pre-calibrated Cp-λ performance curve database. This Cp-λ curve can be generated by modeling and calculating using aerodynamic simulation software (such as Bladed, FAST, or XFOIL combined with BEM theory), and then verified and corrected through wind tunnel testing or on-site power curve testing. During control system initialization, the corresponding curve data is automatically retrieved according to the turbine model, and the optimal tip speed ratio corresponding to the peak Cp value and its corresponding Cpmax value are extracted as the target benchmark for power point tracking control.

[0046] Furthermore, the initial value of the torque control gain mentioned above can correspond to the optimal operating point gain corresponding to the maximum wind energy utilization coefficient Cpmax. Its adjustment process aims to make the system dynamically return to the stable region, rather than completely turn off the power point tracking function, thereby balancing stability and power generation efficiency.

[0047] In one embodiment, the above method may further include: monitoring the actual speed of the blade tip in real time during the operation of the wind turbine, and performing deceleration control when the actual speed of the blade tip exceeds a preset blade tip speed limit.

[0048] The blade tip speed limit, vtipmax, can be determined based on at least one of the following factors: material strength, aerodynamic noise limits, and structural load limits of the wind turbine blade. For example, based on the blade material strength limit, vtipmax can be set to ensure that the bending moment at the blade root does not exceed the fatigue limit of the composite material. Typically, the stress distribution at different speeds is determined through finite element analysis, and the blade tip linear velocity corresponding to the maximum allowable speed with a safety factor greater than 1.5 is taken.

[0049] In summary, this invention provides a wind turbine control method based on instability risk analysis. It enables real-time monitoring and proactive control of instability risk during deceleration without requiring additional hardware installations, solely through software upgrades. By constructing a model of the relationship between the torque coefficient (CT) and the tip speed ratio (λ) and calculating its slope K, a judgment can be made as soon as an instability trend begins to appear: when K > 0, the turbine is determined to be in an unstable state, and the optimal gain Kopt is adjusted to guide the system back to stability.

[0050] This method enables rapid identification and intervention during wind turbine instability, avoiding the severe oscillations caused by delayed response in traditional control and significantly improving the smoothness of the transition process. Furthermore, it achieves continuous and stable power curve tracking under different wind speed conditions without switching controllers, simplifying the design and engineering implementation of control logic. In addition, by setting an upper limit value for blade tip velocity (vtipmax), the safety boundary of blade operation is further guaranteed.

[0051] This invention also provides an application example of a wind turbine control method based on instability risk analysis, see [link to relevant documentation]. Figure 2 The flowchart shown is another wind turbine control method based on instability risk analysis. This method mainly includes the following steps S201 to S207: Step S201: Obtain the current wind speed and calculate the current tip speed ratio λ1; Obtain the wind speed at the previous moment and calculate the tip speed ratio λ0 at the previous moment. Step S202: Calculate the change in tip speed ratio Δλ = λ0 - λ1; Step S203: Obtain the current aerodynamic torque CT1 and the previous aerodynamic torque CT0; Step S204: Calculate the change in aerodynamic torque ΔCT = CT0 - CT1; Step S205: Calculate the slope of the curve change K = △CT / △λ; Step S206: Determine if K is greater than 0; Step S207: If not, then the wind energy utilization coefficient Cp = Cpmax; Step S208: If yes, adjust Kopt to maintain stable operation of the wind turbine.

[0052] In this embodiment of the invention, a stability criterion is constructed by utilizing the relationship between the aerodynamic torque coefficient CT and the tip speed ratio λ. When K = ΔCT / Δλ < 0, it indicates that the torque change and the speed change are coordinated and consistent, the system exhibits negative feedback characteristics, and it is in a stable operating range. At this time, the unit can be adjusted according to the maximum power point tracking strategy so that the wind energy utilization coefficient Cp reaches its theoretical maximum value Cpmax. However, when K > 0, it indicates that the torque and speed changes are mismatched, there is a risk of positive feedback, and the stability control mechanism needs to be activated immediately.

[0053] The method provided in the above embodiments can effectively avoid wind turbine instability caused by speed and torque mismatch when it is necessary to limit the wind turbine speed. It can detect and effectively adjust the wind turbine at the moment of instability, and smoothly pass through the instability process. Furthermore, the method proposes a control strategy that can achieve power curve tracking without switching the controller under different wind speeds, simplifying the formulating, coding, testing and adjustment process of the control law. By setting a limit value vtipmax for the blade tip speed, it can prevent the blade tip speed from exceeding the limit. It can be implemented without installing any other hardware, only by upgrading the wind turbine control software, with low modification cost.

[0054] Based on the same inventive concept, this invention also provides a wind turbine control system based on instability risk analysis, see [link to relevant documentation]. Figure 3 As shown, this system can be used to execute any of the steps in the wind turbine control method based on instability risk analysis proposed in the above embodiments. The system mainly includes the following parts: The determination module 310 is used to determine the tip speed ratio at the current moment, the tip speed ratio at the previous moment, and the change in tip speed ratio based on the wind speed and wind turbine rotor speed at the current moment, as well as the wind speed and wind turbine rotor speed at the previous moment. The calculation module 320 is used to determine the change in aerodynamic torque based on the aerodynamic torque of the wind turbine at the current moment and the aerodynamic torque at the previous moment. The judgment module 330 is used to generate the curve change slope based on the change in tip speed ratio and the change in aerodynamic torque, and to determine whether the curve change slope is greater than 0; if so, the wind turbine has a risk of instability, and the control parameters of the wind turbine are adjusted to maintain the stable operation of the wind turbine.

[0055] The wind turbine control system based on instability risk analysis 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.

[0056] 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.

[0057] Figure 4This is a schematic diagram of the structure 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 based on instability risk analysis described above.

[0058] 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 based on instability risk analysis.

[0059] 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.

[0060] Corresponding to the above-described wind turbine control method based on instability risk analysis, this embodiment of the invention also provides a computer-readable storage medium storing machine-executable instructions. When the machine-executable instructions are called and executed by a processor, the machine-executable instructions cause the processor to perform the steps of the above-described wind turbine control method based on instability risk analysis.

[0061] The wind turbine control system based on instability risk analysis provided in this invention embodiment can be specific hardware on the equipment or software or firmware installed on the equipment. The system provided in this invention embodiment 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 section can be referred to the corresponding content in the aforementioned method embodiment. Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working processes of the systems, units, and processes described above can all be referred to the corresponding processes in the above method embodiments, and will not be repeated here.

[0062] 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.

[0063] 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.

[0064] 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 according to actual needs.

[0065] 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.

[0066] 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.

[0067] 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.

[0068] 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.

[0069] 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.

[0070] 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 based on instability risk analysis, characterized in that, The method, applied to a control system for wind turbine generators, includes: Based on the current wind speed and wind turbine rotor speed, as well as the previous wind speed and wind turbine rotor speed, determine the current tip speed ratio, the previous tip speed ratio, and the change in tip speed ratio. Based on the aerodynamic torque of the wind turbine at the current moment and the aerodynamic torque at the previous moment, the change in aerodynamic torque is determined. The slope of the curve is generated based on the change in tip speed ratio and the change in aerodynamic torque, and it is determined whether the slope of the curve is greater than 0. If so, the wind turbine is at risk of instability, and the control parameters of the wind turbine are adjusted to maintain the stable operation of the wind turbine.

2. The method according to claim 1, characterized in that, The method further includes: if the slope of the curve is not greater than 0, the wind turbine is in a stable state, and the wind energy utilization coefficient of the current wind turbine is determined to be the maximum theoretical wind energy utilization coefficient.

3. The method according to claim 1, characterized in that, Based on the current wind speed and the wind turbine rotor speed, the formula for calculating the tip speed ratio at the current moment is: λ1=(ω1·R) / V1; Where V1 is the wind speed at the current moment, ω1 is the wind turbine rotation speed at the current moment, and R is the blade radius.

4. The method according to claim 1, characterized in that, The aerodynamic torque of the wind turbine is calculated using the following formula: CT = 2P / (ρπR²v³); where P is the mechanical power at the corresponding moment, ρ is the air density, R is the blade radius, and v is the wind speed at the corresponding moment. The mechanical power P is obtained by dividing the generator output power by the transmission chain efficiency, or by direct measurement by the spindle torque sensor.

5. The method according to claim 1, characterized in that, The control parameters of the wind turbine include torque control gain; Adjusting the control parameters of the wind turbine includes: when the wind turbine is at risk of instability, reducing the value of the torque control gain by a preset adjustment range to reduce the growth rate of the generator torque command; The preset adjustment range is set according to the magnitude of the curve change slope: when the curve change slope is greater than the first preset threshold, the torque control gain is reduced by linear decay; when the curve change slope is greater than or equal to the second preset threshold and less than or equal to the first preset threshold, the torque control gain is reduced by segmented step adjustment; wherein, the first preset threshold is greater than the second preset threshold.

6. The method according to claim 1, characterized in that, The method further includes: During the operation of the wind turbine, the actual speed of the blade tip is monitored in real time. When the actual speed of the blade tip exceeds the preset blade tip speed limit, deceleration control is executed. The blade tip rotation speed limit is determined based on at least one of the following factors: material strength of the wind turbine blade, aerodynamic noise limit, and structural load limit.

7. The method according to claim 1, characterized in that, The change in tip speed ratio and the change in aerodynamic torque are determined based on a uniform time sampling period.

8. A wind turbine control system based on instability risk analysis, characterized in that, The system for performing the method according to any one of claims 1 to 7, the system comprising: The determination module is used to determine the tip speed ratio at the current moment, the tip speed ratio at the previous moment, and the change in tip speed ratio based on the wind speed and wind turbine rotor speed at the current moment, as well as the wind speed and wind turbine rotor speed at the previous moment. The calculation module is used to determine the change in aerodynamic torque based on the aerodynamic torque of the wind turbine at the current moment and the aerodynamic torque at the previous moment. The judgment module is used to generate the slope of the curve based on the change in tip speed ratio and the change in aerodynamic torque, and to determine whether the slope of the curve is greater than 0; if so, the wind turbine is at risk of instability, and the control parameters of the wind turbine are adjusted to maintain the stable operation of the wind turbine.

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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