Inertia demand-based variable power tracking characteristic control method and device for fan

Abstract

The application is suitable for the field of wind power technology, and provides a wind turbine variable power tracking characteristic control method and device based on inertia demand. The method comprises the following steps: calculating a demand rotational speed variation of a wind turbine according to an inertia demand of a power system on the wind turbine; calculating a variation time of a frequency variation of the power system reaching a preset frequency deviation according to a frequency response of the power system when the power system is disturbed; determining a new proportional coefficient of a power tracking curve of the wind turbine according to the variation time and the demand rotational speed variation, so that the wind turbine generates additional active power according to the new proportional coefficient within the variation time and participates in an inertia response of the power system. The application can effectively improve the inertia response capability of the wind turbine, so that the active output of the wind turbine after the power system is disturbed can meet the inertia demand of the power system.

Description

Technical Field

[0001] This application relates to the field of wind power technology, specifically to a method and device for controlling the variable power tracking characteristics of wind turbines based on inertia requirements. Background Technology

[0002] The rotational speed of wind turbines (hereinafter referred to as wind turbines) is decoupled from the frequency of the power grid and cannot provide inertia for the power system. Inertia measures the ability of the power system to resist frequency abrupt changes. Therefore, large-scale grid connection of wind turbines will reduce the effective inertia of the power system, posing a threat to the safe operation of the power grid.

[0003] To address the aforementioned issues, researchers have proposed virtual inertial control methods that couple wind turbines with the power grid, such as traditional supplementary inertial control. Taking frequency sag as an example, when using traditional supplementary inertial control, during power system disturbances, the wind turbine generates active power due to frequency abrupt changes, which is added to the active power reference value for maximum power point tracking (MPPT). The turbine releases its rotor kinetic energy to provide active power support to the power system, reducing its rotor speed. However, in the MPPT region, the turbine speed drop leads to a decrease in the active power reference value, causing the turbine's active power output to fail to meet the power system's inertial requirements. Therefore, to resolve this contradiction and eliminate the mutual constraints between traditional supplementary inertial control and MPPT control, a variable power point tracking (VPT) characteristic control method is urgently needed. Summary of the Invention

[0004] In view of this, embodiments of this application provide a wind turbine variable power tracking characteristic control method and apparatus based on inertia requirements, in order to solve the technical problem that the active power output of the wind turbine cannot meet the inertia requirements of the power system in the traditional virtual inertia control method.

[0005] In a first aspect, embodiments of this application provide a wind turbine variable power tracking characteristic control method based on inertia demand, comprising: calculating the change in the required rotational speed of the wind turbine based on the inertia demand of the power system on the wind turbine; calculating the change time of the frequency change of the power system reaching a preset frequency deviation based on the frequency response of the power system when it is disturbed; and determining a new proportional coefficient of the power tracking curve of the wind turbine based on the change time and the change in required rotational speed, so that the wind turbine generates additional active power according to the new proportional coefficient during the change time and participates in the inertial response of the power system.

[0006] In one possible implementation of the first aspect, determining a novel scaling factor for the power tracking curve of the wind turbine based on the change in time and the change in demand speed includes: determining the rotor motion expression of the wind turbine in the maximum power tracking region based on the active power of the wind turbine in the maximum power tracking region; and performing an integral operation on the rotor motion expression based on the change in time and the change in demand speed to determine the novel scaling factor for the power tracking curve of the wind turbine.

[0007] In one possible implementation of the first aspect, the rotor motion expression is:

[0008]

[0009] In the formula, k t For a new type of proportionality coefficient, k opt ω is the proportional coefficient for the maximum power point tracking control of the wind turbine. r This refers to the real-time rotational speed of the fan. This refers to the active power of the wind turbine under the new proportional coefficient power tracking control after the power system is disturbed. H represents the active power of the wind turbine in the maximum power tracking region before the power system is disturbed. w Let t be the inherent inertial time constant of the fan, and t be time; perform an integral operation on the rotor motion expression:

[0010]

[0011] In the formula, t f For varying time, ω r0 ω represents the initial rotational speed of the fan. r1 =ω r0 +Δω r ,Δω r The change in required rotational speed; the new proportional coefficient is expressed as:

[0012]

[0013] In one possible implementation of the first aspect, the inertia requirement of the power system for the wind turbine is the virtual inertia time constant of the wind turbine; the expression for the virtual inertia time constant of the wind turbine is:

[0014]

[0015] In the formula, H v Let Δω be the virtual inertial time constant of the wind turbine. r ω represents the change in required rotational speed. e Let Δω be the synchronous speed of the power grid. e ω is the change in synchronous speed of the power system. r0 H represents the initial rotational speed of the fan. wLet be the inherent inertia time constant of the fan; the change in required rotational speed is determined based on the expression for the virtual inertia time constant of the fan:

[0016]

[0017] In one possible implementation of the first aspect, the frequency response is expressed as:

[0018]

[0019] In the formula, H g Let Δf(t) be the inertial time constant of the power system, Δf(t) be the preset frequency deviation, t be time, and ΔP be the time constant. L D represents the load disturbance. s ΔP is the damping coefficient; m The change in mechanical power of a synchronous generator can be expressed as:

[0020]

[0021] In the formula, K s T is the primary frequency regulation coefficient of the synchronous generator. G The frequency regulation delay for the synchronous generator is determined based on the frequency response and the change in the mechanical power of the synchronous generator, according to the preset frequency deviation.

[0022] In one possible implementation of the first aspect, the method further includes: determining a recovery ratio coefficient of the power tracking curve of the wind turbine based on the novel proportional coefficient and the maximum power tracking control proportional coefficient of the wind turbine, so that the wind turbine smoothly switches to maximum power tracking control according to the recovery ratio coefficient within the recovery time; the recovery time is the time when the change in the frequency of the power system gradually decreases to 0 after reaching a preset frequency deviation.

[0023] In one possible implementation of the first aspect, the recovery scaling factor is expressed as:

[0024]

[0025] In the formula, k tt To restore the proportionality coefficient, k t For a new type of proportionality coefficient, k opt Δf(t) is the proportional coefficient for maximum power point tracking control of the wind turbine, and Δf(t) is the preset frequency deviation. max This represents the maximum frequency deviation of the power system.

[0026] Secondly, embodiments of this application provide a wind turbine variable power tracking characteristic control device based on inertia requirements, comprising:

[0027] The first calculation module is used to calculate the change in the required rotational speed of the wind turbine based on the inertia requirements of the power system.

[0028] The second calculation module is used to calculate the time it takes for the frequency of the power system to change to reach a preset frequency deviation based on the frequency response of the power system when it is disturbed.

[0029] The determination module is used to determine a new proportional coefficient for the power tracking curve of the wind turbine based on the change in time and the change in demand speed, so that the wind turbine can generate additional active power according to the new proportional coefficient during the change time and participate in the inertial response of the power system.

[0030] Thirdly, embodiments of this application provide an electronic device, including a memory and a processor. The memory stores a computer program that can run on the processor. When the processor executes the computer program, it implements the wind turbine variable power tracking characteristic control method based on inertia demand as described in any of the first aspects.

[0031] Fourthly, embodiments of this application provide a computer-readable storage medium storing a computer program that, when executed by a processor, implements the wind turbine variable power tracking characteristic control method based on inertia requirements as described in any of the first aspects.

[0032] Fifthly, embodiments of this application provide a computer program product that, when run on an electronic device, causes the electronic device to execute the wind turbine variable power tracking characteristic control method based on inertia requirements as described in any of the first aspects above.

[0033] It is understood that the beneficial effects of the second to fifth aspects mentioned above can be found in the relevant descriptions in the first aspect mentioned above, and will not be repeated here.

[0034] The wind turbine variable power tracking characteristic control method and device based on inertia demand provided in this application embodiment calculates the change in the required speed of the wind turbine and the change in the frequency of the power system to reach the change time of the preset frequency deviation, and then calculates a new proportional coefficient of the power tracking curve of the wind turbine. When the power system is disturbed, the wind turbine generates active power according to the power tracking curve of the new proportional coefficient, which effectively improves the inertial response capability of the wind turbine and enables the active power output of the wind turbine to meet the inertial demand of the power system after the power system is disturbed.

[0035] It should be understood that the above general description and the following detailed description are exemplary and explanatory only, and are not intended to limit this specification. Attached Figure Description

[0036] To more clearly illustrate the technical solutions in the embodiments of this application, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0037] Figure 1 This is a schematic flowchart of a wind turbine variable power tracking characteristic control method based on inertia requirement provided in an embodiment of this application;

[0038] Figure 2 This is a schematic diagram of the power tracking curve switching principle provided in an embodiment of this application;

[0039] Figure 3 This is the topology diagram of the simulation system;

[0040] Figure 4 It is a schematic diagram of the frequency response curve of the power system after a disturbance occurs in the simulation system;

[0041] Figure 5 This is a schematic diagram of the fan speed response curve after a disturbance occurs in the simulation system;

[0042] Figure 6 This is a schematic diagram of the structure of a wind turbine variable power tracking characteristic control device based on inertia requirement provided in an embodiment of this application;

[0043] Figure 7 This is a schematic diagram of the structure of an electronic device provided in an embodiment of this application. Detailed Implementation

[0044] The present application will be described more clearly below with reference to specific embodiments. These embodiments will help those skilled in the art to further understand the function of the present application, but do not limit the present application in any way. It should be noted that those skilled in the art can make several modifications and improvements without departing from the concept of the present application. These all fall within the protection scope of the present application.

[0045] It should be understood that, when used in this application specification and the appended claims, the term "comprising" indicates the presence of the described features, integrals, steps, operations, elements and / or components, but does not exclude the presence or addition of one or more other features, integrals, steps, operations, elements, components and / or a collection thereof.

[0046] It should also be understood that the term “and / or” as used in this application specification and the appended claims means any combination of one or more of the associated listed items and all possible combinations, and includes such combinations.

[0047] In the description of this application and the appended claims, the terms "first," "second," "third," etc., are used only to distinguish descriptions and should not be construed as indicating or implying relative importance.

[0048] References to "one embodiment" or "some embodiments" as described in this specification mean that one or more embodiments of this application include a specific feature, structure, or characteristic described in connection with that embodiment. Therefore, the phrases "in one embodiment," "in some embodiments," "in other embodiments," "in still other embodiments," etc., appearing in different parts of this specification do not necessarily refer to the same embodiment, but rather mean "one or more, but not all, embodiments," unless otherwise specifically emphasized. The terms "comprising," "including," "having," and variations thereof mean "including but not limited to," unless otherwise specifically emphasized.

[0049] Furthermore, the term "multiple" mentioned in the embodiments of this application should be interpreted as two or more.

[0050] Figure 1 This is a schematic flowchart of a wind turbine variable power tracking characteristic control method based on inertia requirement provided in an embodiment of this application. Figure 1 As shown, the method in the embodiments of this application may include:

[0051] Step 101: Calculate the change in the required rotational speed of the wind turbine based on the inertia requirements of the power system.

[0052] The inertia requirement of the power system for the wind turbine is defined as the virtual inertia time constant of the wind turbine, which can be set according to requirements. The aforementioned wind turbine can be a doubly-fed inertial wind turbine.

[0053] The expression for the virtual inertial time constant of the wind turbine is:

[0054]

[0055] In the formula, H v Let Δω be the virtual inertial time constant of the wind turbine. r ω represents the change in required rotational speed. e Let Δω be the synchronous speed of the power grid. e ω represents the change in synchronous speed of the power system. r0 H represents the initial rotational speed of the fan. w is the inherent inertial time constant of the wind turbine.

[0056] Under normal circumstances, the speed regulation range of a wind turbine is larger than that of the synchronous speed change of a power system. Therefore, a wind turbine can be simulated to have an inertial time constant larger than its inherent inertial time constant. Moreover, compared to a synchronous generator, a wind turbine can be adjusted over a wider range of speed changes, and can simulate an inertial time constant that is no less than that of a synchronous generator.

[0057] The change in required rotational speed is determined according to formula (1):

[0058]

[0059] In the formula, Δω r This represents the change in required rotational speed.

[0060] Step 102: Calculate the time it takes for the frequency change of the power system to reach the preset frequency deviation based on the frequency response of the power system when it is disturbed.

[0061] Optionally, when a load disturbance occurs in the power system, the frequency response of the power system can be expressed as:

[0062]

[0063] In the formula, H g Let Δf(t) be the inertial time constant of the power system, ΔP be the preset frequency deviation, and ΔP be the inertial time constant of the power system. L D represents the load disturbance. s ΔP is the damping coefficient, t is time; m The change in mechanical power of the synchronous generator, which is related to the primary frequency regulation coefficient and the primary frequency regulation delay of the synchronous generator, can be expressed as:

[0064]

[0065] In the formula, K s T is the primary frequency regulation coefficient of the synchronous generator. G For the primary frequency modulation delay of the synchronous generator, s represents the Laplace transform.

[0066] Substituting formula (4) into formula (3), we obtain the expression for the frequency deviation:

[0067]

[0068] in,

[0069] The change time is determined based on the frequency response and the change in mechanical power of the synchronous generator, according to the preset frequency deviation.

[0070] Optionally, the preset frequency deviation can be the allowable value of the normal frequency deviation of the power system, that is, the preset frequency deviation can be 0.5Hz. Substituting the preset frequency deviation of 0.5Hz into formula (5), we can calculate that t is 2 seconds, that is, the change time t f It takes 2 seconds, meaning that when the power system is disturbed, it takes 2 seconds for the power system frequency to rise or fall by 0.5 Hz.

[0071] Step 103: Determine the new proportional coefficient of the power tracking curve of the wind turbine based on the change time and the change in demand speed, so that the wind turbine can generate additional active power according to the new proportional coefficient during the change time and participate in the inertial response of the power system.

[0072] In one possible implementation, step 103, which determines a novel scaling factor for the power tracking curve of the wind turbine based on the change in time and the change in demand speed, may specifically include:

[0073] Step 1031: Determine the rotor motion expression of the wind turbine in the maximum power tracking region based on the active power of the wind turbine in the maximum power tracking region.

[0074] Step 1032: Integrate the rotor motion expression based on the change in time and the change in required rotational speed to determine the new proportional coefficient of the power tracking curve of the fan.

[0075] Optionally, before the power system is disturbed, the formula for calculating the active power of the wind turbine can be expressed as:

[0076]

[0077] In the formula, P ref k represents the active power of the wind turbine before the power system was disturbed. opt ω0 is the proportional coefficient for maximum power point tracking (MPPT) of the wind turbine; ω1 is the minimum speed of the wind turbine when it is in the MPPT region; ω0 is the minimum speed of the wind turbine when it is in the MPPT region; ω1 is the maximum speed of the wind turbine when it is in the MPPT region; ω2 is the maximum power point tracking (MPPT) proportional coefficient of r P represents the real-time rotational speed of the fan. max ω is the output power limit value of the wind turbine. max This is the speed limit value for the fan.

[0078] For example, after the power system is disturbed, the formula for calculating the active power of a wind turbine can be expressed as:

[0079]

[0080] In the formula, P ref1 k represents the active power of the wind turbine after the power system is disturbed. t This is a new type of proportionality coefficient.

[0081] Optionally, according to formulas (6) and (7), the rotor motion expression can be:

[0082]

[0083] In the formula, k t For a new type of proportionality coefficient, k opt ω is the proportional coefficient for the maximum power point tracking control of the wind turbine. r This refers to the real-time rotational speed of the fan. This refers to the active power of the wind turbine under the new proportional coefficient power tracking control after the power system is disturbed. H represents the active power of the wind turbine in the maximum power tracking region before the power system is disturbed. w Let t be the inherent inertial time constant of the wind turbine, and t be time. The novel proportional coefficient power point tracking control is also known as variable power point tracking control, or variable power point tracking characteristic control.

[0084] Integrating both sides of the rotor motion expression simultaneously:

[0085]

[0086] In the formula, t f For varying time, ω r0 ω represents the initial rotational speed of the fan. r1 =ω r0 +Δω r ,Δω r Let this be the change in required rotational speed. The resulting proportional coefficient is expressed as:

[0087]

[0088] The new proportional coefficient obtained from formula (9), namely the new proportional coefficient of the power tracking curve of the wind turbine, enables the power tracking curve of the wind turbine to meet the expected change in the required speed of the wind turbine within a time period after the power system is disturbed. In other words, the active power output of the wind turbine can meet the inertial requirements of the power system after being disturbed.

[0089] Specifically, refer to Figure 2 , Figure 2 The horizontal axis in the figure represents the real-time rotational speed ω of the fan. r The vertical axis represents the output power P of the fan. eTaking frequency drop and load surge as an example, when the power system is stable, the wind turbine is under maximum power point tracking (MPPT) control, and the turbine speed is stable. When the power system is subjected to load disturbance, the power system frequency will drop significantly in the initial stage of the disturbance. When the frequency change rate of the power system exceeds 0.5 Hz / s, the wind turbine switches from the proportional coefficient of MPPT control to a new proportional coefficient of the power point tracking curve, that is, from MPPT control to variable power point tracking (VPST) control. Due to the inertia of the wind turbine rotor, the wind turbine speed cannot change abruptly in the initial stage of the disturbance. Under the condition of constant speed, the active power of the wind turbine suddenly increases, that is, the operating point of the wind turbine quickly moves from A1 to A2. At this time, the active power output of the wind turbine also increases from P... A1 Rise to P A2 When the mechanical power of the wind turbine is less than its active power, the turbine rotor begins to decelerate, and the released rotor kinetic energy provides power support to the power system.

[0090] As the fan speed decreases, the fan output power will decrease along the power tracking curve of the new proportional coefficient. The fan's operating point gradually moves from A2 to A3. At this point, the fan's mechanical power and active power reach a balance, the fan speed drops to the desired speed, and the fan returns to maximum power tracking control, that is, the fan switches to the maximum power tracking curve.

[0091] As mentioned above, once the wind turbine's initial speed rises or falls along the power tracking curve to the desired change in required speed, the turbine needs to switch back to the maximum power tracking curve. If it switches directly to the maximum power tracking curve, the turbine's operating point will rapidly move from A3 to A4 (refer to...). Figure 2 This causes a secondary frequency drop. To smoothly recover to maximum power point tracking control and avoid a secondary frequency drop, the wind turbine variable power point tracking characteristic control method based on inertia requirements provided in this application embodiment may further include:

[0092] The recovery ratio of the power tracking curve of the wind turbine is determined based on the new proportional coefficient and the maximum power tracking control proportional coefficient of the wind turbine, so that the wind turbine can smoothly switch to maximum power tracking control according to the recovery ratio during the recovery time.

[0093] The recovery time is the time it takes for the frequency change of the power system to gradually decrease to 0 after reaching the preset frequency deviation (the recovery time does not include the change time).

[0094] Optionally, the recovery ratio coefficient can be expressed as:

[0095]

[0096] In the formula, k tt To restore the proportionality coefficient, k t For a new type of proportionality coefficient, kopt Δf(t) is the proportional coefficient for maximum power point tracking control of the wind turbine, and Δf(t) is the preset frequency deviation. max This represents the maximum frequency deviation of the power system.

[0097] In switching control, the allowable value of the normal frequency deviation of the power system can be introduced, that is, a preset frequency deviation can be introduced. Then, the change of the recovery ratio coefficient can be controlled by the gradual change of the frequency deviation of the wind turbine itself, thus avoiding frequency disturbance caused by sudden changes in the active power of the wind turbine.

[0098] This application provides a wind turbine variable power tracking characteristic control method based on inertia demand. By calculating the change in the required rotational speed of the wind turbine and the change in the frequency of the power system to reach the change time of the preset frequency deviation, a new proportional coefficient of the power tracking curve of the wind turbine is calculated. When the power system is disturbed, the wind turbine generates additional active power according to the power tracking curve of the new proportional coefficient within the change time, which effectively improves the inertial response capability of the wind turbine and makes the active power output of the wind turbine meet the inertial demand of the power system. During the recovery time, the wind turbine smoothly recovers to maximum power tracking control according to the recovery proportional coefficient, avoiding secondary frequency drops.

[0099] It should be understood that the sequence number of each step in the above embodiments does not imply the order of execution. The execution order of each process should be determined by its function and internal logic, and should not constitute any limitation on the implementation process of the embodiments of this application.

[0100] To verify the effectiveness and feasibility of the wind turbine variable power tracking characteristic control method based on inertia demand provided in this application, a three-machine simulation system for wind farm integration was built based on the MATLAB / Simulink simulation platform. Figure 3 This is the topology diagram of the simulation system. The simulation system includes a 200MVA synchronous generator G1, a 300MVA synchronous generator G2, and a 300MVA doubly-fed wind turbine DFIG. The wind turbines transmit active power to the grid through RSC (rotor-side converter) and GSC (grid-side converter). The wind power penetration rate is 37.5%, and a 20% load surge is set at t=10s.

[0101] Virtual inertial time constant H of the air intake fan v The inherent inertial time constant H of the wind turbine is 9 seconds. w The initial rotational speed ω of the fan is 3.75 seconds. r0 The required rotational speed change Δω is calculated according to formula (2) as 0.82 pu. r The value is 0.03 pu. The time of change is t. f The maximum power tracking control proportional coefficient k of the wind turbine is 2 seconds. optIt is 1 / 1.2 3 According to formula (10), the new proportional coefficient of the power tracking curve is 0.75.

[0102] Figure 4 This is a schematic diagram of the frequency response curve of the power system after a disturbance occurs in the simulation system, where the horizontal axis represents time t and the vertical axis represents the real-time frequency f of the power system. Figure 5 This is a schematic diagram of the fan speed response curve after a disturbance in the simulation system, where the horizontal axis represents time t and the vertical axis represents the real-time fan speed ω. r .Depend on Figure 4 and Figure 5 Analysis shows that when the initial speed of the wind turbine is 0.822 pu, the maximum speed change of the wind turbine within the change time is 0.036 pu, and the maximum inertia is 9.38 seconds. These are close to the calculated change in required speed and the virtual inertia time constant, respectively, indicating the effectiveness and feasibility of the wind turbine variable power tracking characteristic control method based on inertia requirement provided in this application embodiment.

[0103] Figure 6 This is a schematic diagram of a wind turbine variable power tracking characteristic control device based on inertia requirements, provided in one embodiment of this application. Figure 6 As shown, the wind turbine variable power tracking characteristic control device based on inertia requirement provided in this embodiment may include: a first calculation module 201, a second calculation module 202, and a determination module 203.

[0104] The first calculation module 201 is used to calculate the change in the required rotational speed of the wind turbine based on the inertia requirements of the power system.

[0105] The second calculation module 202 is used to calculate the time it takes for the frequency of the power system to change to reach a preset frequency deviation based on the frequency response of the power system when it is disturbed.

[0106] The determination module 203 is used to determine a new proportional coefficient for the power tracking curve of the wind turbine based on the change time and the change in demand speed, so that the wind turbine can generate additional active power according to the new proportional coefficient during the change time and participate in the inertial response of the power system.

[0107] Optionally, the determining module 203 is specifically used to: determine the rotor motion expression of the wind turbine in the maximum power tracking zone based on the active power of the wind turbine in the maximum power tracking zone; and perform integral calculation on the rotor motion expression based on the change in time and the change in demand speed to determine the new proportional coefficient of the power tracking curve of the wind turbine.

[0108] Optionally, the determining module 203 is also specifically used to: determine the recovery ratio coefficient of the power tracking curve of the wind turbine according to the new proportional coefficient and the maximum power tracking control proportional coefficient of the wind turbine, so that the wind turbine can smoothly switch to maximum power tracking control according to the recovery ratio coefficient within the recovery time; the recovery time is the time when the change in the frequency of the power system gradually decreases to 0 after reaching the preset frequency deviation.

[0109] It should be noted that the information interaction and execution process between the above-mentioned devices / units are based on the same concept as the method embodiments of this application. For details on their specific functions and technical effects, please refer to the method embodiments section, and they will not be repeated here.

[0110] Figure 7 This is a schematic diagram of the structure of an electronic device provided in an embodiment of this application. For example... Figure 7 As shown, the electronic device 300 of this embodiment includes a processor 310 and a memory 320, wherein the memory 320 stores a computer program 321 that can run on the processor 310. When the processor 310 executes the computer program 321, it implements the steps in any of the above-described method embodiments, for example... Figure 1 Steps 101 to 103 are shown. Alternatively, when processor 310 executes computer program 321, it implements the functions of each module / unit in the above-described device embodiments, for example... Figure 6 The functions of modules 201 to 203 are shown.

[0111] For example, computer program 321 may be divided into one or more modules / units, one or more of which are stored in memory 320 and executed by processor 310 to complete this application. The one or more modules / units may be a series of computer program instruction segments capable of performing a specific function, which describe the execution process of computer program 321 in electronic device 300.

[0112] Those skilled in the art will understand that Figure 7 This is merely an example of an electronic device and does not constitute a limitation on the electronic device. It may include more or fewer components than shown, or combinations of certain components, or different components, such as input / output devices, network access devices, buses, etc.

[0113] The processor 310 can be a central processing unit (CPU), or other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. The general-purpose processor can be a microprocessor or any conventional processor.

[0114] The memory 320 can be an internal storage unit of the electronic device, such as a hard drive or memory, or an external storage device, such as a plug-in hard drive, SmartMedia Card (SMC), Secure Digital (SD) card, or Flash Card. The memory 320 can also include both internal and external storage units. The memory 320 is used to store computer programs and other programs and data required by the electronic device. The memory 320 can also be used to temporarily store data that has been output or will be output.

[0115] Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the above-described division of functional units and modules is merely an example. In practical applications, the above functions can be assigned to different functional units and modules as needed, that is, the internal structure of the device can be divided into different functional units or modules to complete all or part of the functions described above. The functional units and modules in the embodiments 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. The integrated unit can be implemented in hardware or as a software functional unit. Furthermore, the specific names of the functional units and modules are only for easy differentiation and are not intended to limit the scope of protection of this application. The specific working process of the units and modules in the above system can be referred to the corresponding process in the foregoing method embodiments, and will not be repeated here.

[0116] In the above embodiments, the descriptions of each embodiment have different focuses. For parts that are not described in detail or recorded in a certain embodiment, please refer to the relevant descriptions of other embodiments.

[0117] Those skilled in the art will recognize that the units and algorithm steps of the various examples described in conjunction with the embodiments disclosed herein can be implemented in electronic hardware, or a combination of computer software and electronic hardware. Whether these functions are implemented in hardware or software depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementations should not be considered beyond the scope of this invention.

[0118] In the embodiments provided by this invention, it should be understood that the disclosed devices / electronic devices and methods can be implemented in other ways. For example, the device / electronic device embodiments described above are merely illustrative. For instance, the division of modules or units is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the coupling or direct coupling or communication connection shown or discussed may be through some interfaces; the indirect coupling or communication connection between devices or units may be electrical, mechanical, or other forms.

[0119] 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.

[0120] Furthermore, the functional units in the various embodiments of 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. The integrated unit can be implemented in hardware or as a software functional unit.

[0121] If the integrated module / unit 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, all or part of the processes in the methods of the above embodiments of the present invention can also be implemented by a computer program instructing related hardware. The computer program can be stored in a computer-readable storage medium, and when executed by a processor, it can implement the steps of the various method embodiments described above. The computer program includes computer program code, which can be in the form of source code, object code, executable files, or certain intermediate forms. The computer-readable medium can include: any entity or device capable of carrying the computer program code, a recording medium, a USB flash drive, a portable hard drive, a magnetic disk, an optical disk, a computer memory, a read-only memory (ROM), a random access memory (RAM), an electrical carrier signal, a telecommunication signal, and a software distribution medium, etc.

[0122] The above-described embodiments are only used to illustrate the technical solutions of the present invention, and are not intended to limit it. Although the present invention has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features. Such modifications 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, and should all be included within the protection scope of the present invention.

Claims

1. A wind turbine variable power tracking characteristic control method based on inertia demand, characterized in that, include: The required speed change of the wind turbine is calculated based on the inertia requirements of the power system. The change time of the frequency of the power system reaching the preset frequency deviation is calculated based on the frequency response of the power system when it is disturbed. A novel proportional coefficient for the power tracking curve of the wind turbine is determined based on the change time and the change in required rotational speed, so that the wind turbine generates additional active power according to the novel proportional coefficient during the change time and participates in the inertial response of the power system. The novel proportionality coefficient for determining the power tracking curve of the wind turbine based on the change time and the change in required rotational speed includes: The rotor motion expression of the wind turbine in the maximum power tracking region is determined based on the active power of the wind turbine in the maximum power tracking region. Based on the change time and the change in required rotational speed, the rotor motion expression is integrated to determine a new proportional coefficient for the power tracking curve of the wind turbine. The rotor motion expression is: In the formula, k t For a new type of proportionality coefficient, k opt This is the proportional coefficient for the maximum power tracking control of the wind turbine. ω r This refers to the real-time rotational speed of the fan. This refers to the active power of the wind turbine under the new proportional coefficient power tracking control after the power system is disturbed. This refers to the active power of the wind turbine in the maximum power tracking region before the power system is disturbed. H w Let be the inherent inertial time constant of the wind turbine. t For time; Integral calculation of the rotor motion expression: In the formula, For varying time periods, ω r0 This is the initial rotational speed of the fan. ω r1 = ω r0 +Δ ω r Δ ω r This represents the change in required rotational speed. The new proportionality coefficient is expressed as follows: ； The power system's inertia requirement for the wind turbine is the wind turbine's virtual inertia time constant; the expression for the wind turbine's virtual inertia time constant is: In the formula, H v Let Δ be the virtual inertial time constant of the wind turbine. ω r This represents the change in required rotational speed. ω e For the synchronous speed of the power grid, Δ ω e This represents the change in synchronous speed of the power system. ω r0 This is the initial rotational speed of the fan. H w The inherent inertial time constant of the wind turbine; The change in required rotational speed is determined based on the expression for the virtual inertia time constant of the wind turbine: ； The frequency response is expressed as: In the formula, H g Let be the inertial time constant of the power system. For the preset frequency deviation, t For time, Δ P L This represents the load disturbance. D s Δ is the damping coefficient; P m The change in mechanical power of a synchronous generator can be expressed as: In the formula, K s This refers to the primary frequency regulation coefficient of the synchronous generator. T G For the primary frequency regulation delay of the synchronous generator; The change time is determined based on the frequency response and the change in mechanical power of the synchronous generator, according to the preset frequency deviation.

2. The wind turbine variable power tracking characteristic control method based on inertia demand according to claim 1, characterized in that, The method further includes: determining the recovery ratio coefficient of the power tracking curve of the wind turbine according to the new proportional coefficient and the maximum power tracking control proportional coefficient of the wind turbine, so that the wind turbine smoothly switches to maximum power tracking control according to the recovery ratio coefficient within the recovery time; the recovery time is the time when the frequency change of the power system gradually decreases to 0 after reaching a preset frequency deviation.

3. The wind turbine variable power tracking characteristic control method based on inertia demand according to claim 2, characterized in that, The recovery ratio coefficient is expressed as: In the formula, k tt To restore the proportionality coefficient, k t For a new type of proportionality coefficient, k opt This is the proportional coefficient for the maximum power tracking control of the wind turbine. For the preset frequency deviation, This represents the maximum frequency deviation of the power system.

4. A wind turbine variable power tracking characteristic control device based on inertia demand for implementing the wind turbine variable power tracking characteristic control method based on inertia demand as described in any one of claims 1 to 3, characterized in that, include: The first calculation module is used to calculate the change in the required rotational speed of the wind turbine based on the inertia requirements of the power system. The second calculation module is used to calculate the time it takes for the frequency of the power system to change to reach a preset frequency deviation based on the frequency response of the power system when it is disturbed. The determination module is used to determine a new proportional coefficient for the power tracking curve of the wind turbine based on the change time and the change in required rotational speed, so that the wind turbine generates additional active power according to the new proportional coefficient during the change time and participates in the inertial response of the power system.

5. 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 wind turbine variable power tracking characteristic control method based on inertia requirements as described in any one of claims 1 to 3.

6. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by the processor, it implements the wind turbine variable power tracking characteristic control method based on inertia requirements as described in any one of claims 1 to 3.

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