New energy station transient whole process time sequence coordination control method and system

Abstract

A method and system for time-series coordinated control of the entire transient process of renewable energy power plants is proposed, triggering coordinated control during grid disturbances. In the inertia support phase, under reactive power margin constraints, the renewable energy power plant supplies rotor kinetic energy of the renewable energy units, virtual inertia output power from energy storage, and reactive power dynamic loss compensation to the grid. In the frequency regulation phase, under frequency deviation constraints, the extreme value of the frequency change rate is determined based on the real-time frequency change acceleration within the observation time window, and an active power command for frequency regulation is generated based on this extreme value. Energy storage executes the active power command to adjust the active power deviation. In the voltage stabilization phase, the reactive power dynamic loss compensation is updated. The updated reactive power dynamic loss compensation is superimposed with the reactive power reference value to obtain the reactive power command. The renewable energy units execute the reactive power command to adjust the voltage deviation. This addresses the problems of fragmented control response, insufficient accuracy, and poor disturbance adaptability in existing renewable energy power plant technologies.

Description

Technical Field

[0001] This invention belongs to the field of power system control, specifically relating to a method and system for time-series coordinated control of transient inertia, frequency, and voltage throughout the entire process of a new energy power station. Background Technology

[0002] Currently, active support methods for new energy power plants mainly include inertia support, primary frequency regulation, and voltage regulation. The active support coordination control method for new energy power plants containing voltage-controlled sources sets the internal parameters of voltage-controlled and current-controlled sources in the power plant based on dispatching and grid-load-storage operation and control commands. It monitors the output status of the voltage source controlled units and calculates the voltage source regulation margin. Based on the overall target value of the power plant's external characteristics, it sets the multi-source coordinated control objective function and constraints. This method is applicable to frequency active support methods and power control devices for both new energy and energy storage power plants. By simulating the inertia response and primary adjustment of conventional thermal and hydropower generating units to the grid frequency, it coordinates the corresponding active power output with the existing AGC output of the power plant, enabling new energy and energy storage power plants to operate at multiple time scales. The system addresses several key aspects: Response to grid frequency changes; a centralized coordinated control method for new energy power plants; inertial response and low-voltage ride-through strategies calculated by collecting grid connection point parameters of the main circuit; centralized coordinated control of photovoltaic energy storage systems under dynamic operating conditions via current distribution logic; a grid-connected wind farm voltage source control method based on phase angle self-generation strategy; a grid-connected coordinated controller for wind turbine voltage sources with grid-side DC voltage control, turbine-side rotor kinetic energy control, and adaptive load reduction; and an active support control method and system for grid-connected hybrid new energy power plants, which switches the operating mode of units with grid-connected / connected power generation modes based on the short-circuit ratio of the power plant and coordinates grid-connected units to jointly complete inertial frequency regulation.

[0003] However, in existing technologies, inertia support (<500ms), frequency regulation (0.5-10s), and voltage regulation (>10s) are typically designed and executed independently in stages, lacking a full-process time-series coordination mechanism. This leads to potential conflicts between control objectives at different stages during grid disturbances; for example, frequency regulation may cause voltage instability, or voltage regulation may affect frequency recovery. Existing new energy power plant control systems, lacking accurate prediction and rapid response mechanisms for power extrema, typically exhibit power regulation deviations exceeding 2%, failing to meet the grid's high-precision support requirements. Especially under large disturbances, reactive power response times generally exceed 100ms, making it difficult to effectively suppress voltage fluctuations. Existing control methods are insufficiently adaptable to grid disturbances, particularly under complex disturbances. Failure to accurately predict power extrema and system response characteristics can easily lead to secondary frequency drops or voltage collapse, affecting the safe and stable operation of the grid. Existing technologies do not adequately consider the loss characteristics of converters during dynamic processes and lack reactive power feedforward compensation mechanisms based on loss models, resulting in untimely reactive power response during high power fluctuations, affecting voltage stability. Summary of the Invention

[0004] To address the shortcomings of existing technologies, this invention provides a time-coordinated control method and system for the entire transient process of new energy power plants. This method solves the problems of fragmented control response, insufficient accuracy, and poor disturbance adaptability in existing technologies. It enables time-coordinated control of the entire process of inertia support, frequency regulation, and voltage stability of new energy power plants, thereby improving their rapid response capability and support accuracy to grid disturbances. Through the time-coordinated control strategy, the rapid response of new energy power plants to grid disturbances is achieved, effectively enhancing grid stability.

[0005] The present invention adopts the following technical solution.

[0006] This invention proposes a transient full-process time-series coordinated control method for new energy power plants, including: When grid disturbances are detected based on the grid frequency change rate and voltage deviation, coordinated control is triggered. The coordinated control is divided into three phases according to the timing sequence: inertia support phase, frequency regulation phase, and voltage stabilization phase. During the inertia support stage, under the reactive power margin constraint, the rotor kinetic energy of the new energy unit, the output power of the energy storage virtual inertia, and the reactive power dynamic loss compensation are transmitted from the new energy power station to the grid. During the frequency regulation phase, under the constraint of frequency deviation, the extreme value of the frequency change rate is determined based on the real-time frequency change acceleration within the observation time window, and an active power command for frequency regulation is generated based on the extreme value of the frequency change rate; the energy storage executes the active power command to regulate the active power deviation. During the voltage stabilization phase, the reactive power dynamic loss compensation is updated; the updated reactive power dynamic loss compensation is superimposed with the reactive power reference value to obtain the reactive power command; the new energy unit executes the reactive power command to adjust the voltage deviation.

[0007] Preferably, the high-speed acquisition unit synchronously measures frequency, voltage, and grid-connected power at the 1ms level; when the frequency change rate is detected to be greater than 0.5Hz / s or the voltage deviation is greater than 0.1pu, the three-stage coordinated control is triggered. The period from 0ms to 500ms is the inertia support stage, from 0.5s to 10s is the frequency adjustment stage, and from 10s to minutes is the voltage stabilization stage.

[0008] Preferably, the reactive power margin constraint is: the output power of the static var generator is not greater than 80%. , This represents the maximum reactive power output of the static var generator. The rotor kinetic energy of the new energy unit is shown in the following formula:

[0009] In the formula, This represents the change in mechanical power. For rotational inertia, Angular velocity, Angular acceleration; The output power of the energy storage virtual inertia is shown in the following formula:

[0010] In the formula, For power adjustment amount, Let be the system inertia constant. The rate of change of frequency; The reactive power dynamic loss compensation is shown in the following formula:

[0011] In the formula, For the estimated switching loss, This is the switching loss factor. This represents the reactive current component.

[0012] Preferably, the switching loss factor is calibrated using the IGBT thermal resistance curve:

[0013] In the formula, This is the junction temperature of the semiconductor. For ambient temperature, This is the reactive current component. To reduce the thermal resistance of the environment.

[0014] Preferably, the frequency deviation constraint is: the absolute value of the frequency deviation is less than 0.1Hz; The extreme values ​​of the rate of change of frequency are shown in the following formula:

[0015] In the formula, For the extreme value of the rate of change of frequency, This is the scaling factor. For the observation time window, The second derivative of frequency, It is a time variable; Preferably, the active power command is as follows: = ( + )+

[0016] In the formula, This is an active power command. This is the proportional gain coefficient. For frequency deviation, The integral time constant is... For the acceleration term gain coefficient, This is the exponential decay coefficient.

[0017] Preferably, the updated reactive power dynamic loss compensation amount is as shown in the following formula:

[0018] In the formula, This is the updated reactive power dynamic loss compensation amount. This is the feedforward gain coefficient. , This is the junction temperature of the semiconductor. This is the switching loss factor. This is the iron loss coefficient. This is the reactive current component. This is the DC bus voltage.

[0019] Preferably, the updated reactive power dynamic loss compensation is superimposed with the reactive power reference value to obtain the reactive power command used for voltage regulation, as shown in the following formula:

[0020] In the formula, This is a reactive power command. This is the reactive power reference value. This is the updated reactive power dynamic loss compensation amount.

[0021] This invention also proposes a transient full-process time-series coordinated control system for new energy power plants, comprising: The triggering module is used to trigger coordinated control when grid disturbances are detected based on the grid frequency change rate and voltage deviation. The coordinated control is divided into three stages according to the timing sequence: inertia support stage, frequency regulation stage, and voltage stabilization stage. The inertia support module is used in the inertia support stage to transmit the rotor kinetic energy of the new energy unit, the output power of the energy storage virtual inertia, and the dynamic loss compensation of the reactive power from the new energy power station to the grid under the reactive power margin constraint. The frequency regulation module is used during the frequency regulation phase to determine the extreme value of the frequency change rate based on the real-time frequency change acceleration within the observation time window under the constraint of frequency deviation, and to generate an active power command for frequency regulation based on the extreme value of the frequency change rate; the energy storage executes the active power command to adjust the active power deviation; The voltage stabilization module is used during the voltage stabilization phase to update the reactive dynamic loss compensation amount. The updated reactive dynamic loss compensation amount is superimposed with the reactive power reference value to obtain the reactive power command. The new energy unit executes the reactive power command to adjust the voltage deviation.

[0022] The present invention is also a terminal, including a processor and a storage medium; the storage medium is used to store instructions; the processor is used to perform operations according to the instructions to execute the steps of the method.

[0023] The present invention is also a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the steps of the method.

[0024] The beneficial effects of this invention are, compared with the prior art, at least including that this invention can shorten the frequency recovery time, reduce the adjustment deviation, and accelerate the reactive power response, specifically: 1) By using the frequency modulation command acceleration approximation algorithm based on power extreme value estimation, the frequency recovery time has been shortened from about 10 seconds to 3-4 seconds, an increase of more than 50%, and the adjustment deviation has been controlled within 0.1%, which is far better than the national standard requirement of 1%. At the same time, the overshoot in the frequency recovery process has been eliminated, effectively preventing the phenomenon of secondary frequency drop.

[0025] 2) By adopting reactive dynamic loss feedforward voltage regulation technology, the mapping relationship between converter switching losses and reactive output is modeled in real time and feedforward compensation is performed, which shortens the reactive response time to less than 30ms, which is 62.5% higher than the industry average of 80ms, and the voltage regulation deviation is reduced to less than 0.5%, which is more than 60% better than the 1.5% of traditional control.

[0026] 3) A full-process timing coordination architecture was established, connecting the control links of the three stages: inertia support (0-500ms), frequency regulation (0.5-10s), and voltage stabilization (10s-minute level), thus resolving the control conflicts caused by independent actions in each stage in traditional control. By releasing virtual inertia through energy storage, the frequency change rate was effectively suppressed to within 0.2Hz / s, and the reactive power response time of the entire station was shortened to within 30ms, significantly improving the adaptability of new energy power plants to grid disturbances. Attached Figure Description

[0027] Figure 1 This is a flowchart of the transient full-process time-series coordinated control method for new energy power stations proposed in this invention. Detailed Implementation

[0028] To make the objectives, technical solutions, and advantages of this invention clearer, the technical solutions of this invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of this invention. The embodiments described in this application are merely some embodiments of this invention, and not all embodiments. Based on the spirit of this invention, all other embodiments obtained by those skilled in the art without creative effort are within the protection scope of this invention.

[0029] This invention proposes a transient full-process time-series coordinated control method for new energy power plants, such as... Figure 1 As shown, it includes: Step 1: Obtain the grid frequency change rate and voltage deviation. When a grid disturbance is detected, trigger coordinated control. The coordinated control is divided into three stages according to the timing sequence: inertia support stage, frequency regulation stage, and voltage stabilization stage.

[0030] Specifically, the high-speed acquisition unit detects grid disturbances in real time, synchronously measuring frequency, voltage, and grid-connected power at the 1ms level; when the frequency change rate is detected... >0.5Hz / s or voltage deviation When the frequency is greater than 0.1 pu, a three-stage collaborative control is triggered. Among them, 0.5 Hz and 0.1 pu are both unrestricted and preferred choices. In this embodiment, 0-500ms is the inertia support phase, 0.5-10s is the frequency adjustment phase, and 10s-minutes is the voltage stabilization phase, which is a non-limiting but preferred choice. In practical applications, the disturbance type is distinguished based on the frequency change rate and voltage deviation trajectory, and the target values, durations, and even resource allocation weights of the three phases are dynamically adjusted.

[0031] The method proposed in this invention divides the collaborative control according to the time sequence logic, avoiding the resource competition or response overshoot that may be caused by the parallel or simple superposition of inertia, primary frequency regulation and voltage control in traditional control. It conforms to the physical nature of the power grid dynamics after a large disturbance, that is, the inertial response suppresses the sudden drop in frequency (millisecond to second level), the primary frequency regulation calms the frequency fluctuation (second to ten-second level), and the voltage recovery ensures stable operation (ten-second to minute level).

[0032] In step 2, the inertia support stage, under the reactive power margin constraint, the new energy power station transmits the rotor kinetic energy of the new energy unit, the output power of the energy storage virtual inertia, and the reactive power dynamic loss compensation to the grid.

[0033] During the inertia support phase, to reserve the reactive power margin required for voltage regulation, the output power of the static var generator (SVG) is limited to ≤80%. In the formula, This represents the maximum reactive power output of the SVG, measured in var. The core objective of the inertia support phase is to suppress the rate of frequency change, but a reactive power margin constraint is introduced, meaning that while providing emergency active power support, sufficient reactive power must be reserved for the subsequent voltage control phase.

[0034] The change in mechanical power based on rotational inertia is taken as the rotor kinetic energy of the new energy unit, as shown in the following formula:

[0035] In the formula, This is the change in mechanical power, measured in W, representing the instantaneous power of the change in kinetic energy of a rotating system. Moment of inertia, unit: kg· This represents an object's ability to resist angular acceleration and reflects its mass distribution characteristics; Angular velocity, unit: rad / s; Angular acceleration, unit: rad / .

[0036] The power adjustment based on the system inertia constant is used as the output power of the energy storage virtual inertia, as shown in the following formula:

[0037] In the formula, Power adjustment amount, unit: MW, represents the change in active power that the system needs to provide; a positive value indicates an increase in output. The system inertia constant, in seconds, measures the system's ability to resist frequency changes and represents the size of its kinetic energy reserves. Rate of change of frequency, in Hz / s, represents the rate at which the system frequency changes over time and reflects the degree of power imbalance.

[0038] The estimated switching loss is used as the reactive power dynamic loss compensation amount, as shown in the following formula:

[0039] In the formula, The estimated value of switching losses, in var, represents the estimated reactive power capacity that the converter will lose due to the switching process. The switching loss coefficient, in Ω, is a loss constant characterizing the switching device characteristics and circuit topology. The reactive current component, measured in A, represents the component of the converter output current that is orthogonal to the voltage (90° phase difference), and directly determines the magnitude of reactive power. The switching loss factor is calibrated using the IGBT thermal resistance curve.

[0040] In the formula, Semiconductor junction temperature, unit: °C; Ambient temperature, unit: °C; This refers to the reactive current component, in amperes (A). The junction thermal resistance, in °C / W, represents the total thermal resistance from the semiconductor junction to ambient air.

[0041] Step 3, in the frequency regulation stage, under the constraint of frequency deviation, the extreme value of the frequency change rate is determined based on the real-time frequency change acceleration within the observation time window, and an active power command for frequency regulation is generated based on the extreme value of the frequency change rate; the energy storage executes the active power command to regulate the active power deviation.

[0042] During the frequency regulation phase, voltage control of the photovoltaic inverter is initiated under a frequency deviation constraint, where the frequency deviation constraint is | | < 0.1 Hz.

[0043] The extreme values ​​of the rate of change of frequency are shown in the following formula:

[0044] In the formula, The extreme value of the rate of change of frequency, in Hz / s, represents the absolute value of the predicted maximum rate of change of the power grid frequency; The scaling factor, in dimensionless form, represents the model correction factor used to compensate for system inertia and measurement errors. The observation time window, in seconds, represents the length of time for integral prediction after the disturbance occurs. The second derivative of frequency, unit: Hz / This represents the acceleration due to frequency change, reflecting the dynamic characteristics of the power gap; For time variables, the unit is seconds (s). The method proposed in this invention does not directly use frequency deviation in the frequency regulation stage. Instead, it introduces an observation time window and frequency change acceleration to predict or determine the extreme value of the frequency change rate. This is actually a kind of feedforward or predictive control, which predicts how much frequency modulation power is needed based on the trend (acceleration) of frequency change. It is faster and more accurate than simple proportional feedback (such as traditional primary frequency modulation).

[0045] The active power command used for frequency modulation is shown in the following formula: = ( + )+

[0046] In the formula, This is an active power command, in MW, representing the amount of power adjustment that the renewable energy power station needs to output. The proportional gain coefficient, in MW / Hz, represents the gain coefficient of the proportional control loop and determines the response strength to frequency deviation. For frequency deviation, the actual system frequency With reference frequency The difference; The integral time constant, in seconds, represents the time constant of the integral element and determines the rate at which steady-state error is eliminated. The observation time window, in seconds, represents the length of time for integral prediction after the disturbance occurs. The gain coefficient for the acceleration term is expressed in MW / (Hz / s), representing the weighting coefficient of the acceleration approximation term. This is the exponential decay coefficient, with units of: , which represents the exponential decay rate and controls the decay speed of the acceleration term; Among them, satisfying , This allows the power command to converge to the required value within 300ms.

[0047] In this embodiment, the power command for frequency regulation is preferentially executed by the energy storage. This achieves power regulation deviation.

[0048] Step 4, during the voltage stabilization phase, the reactive power dynamic loss compensation is updated; the updated reactive power dynamic loss compensation is superimposed with the reactive power reference value to obtain the reactive power command used for voltage regulation; the new energy unit executes the reactive power command to adjust the voltage deviation.

[0049] Specifically, the reactive power compensation is calculated in real time based on the converter loss model, and used as the updated dynamic reactive power loss compensation, as shown in the following formula:

[0050] In the formula, The updated reactive power dynamic loss compensation amount, in var, represents the additional reactive power compensation required to offset loss fluctuations. Forward gain coefficient, unit: s / Ω, represents the conversion coefficient from loss change rate to reactive power compensation; The switching loss coefficient, in Ω, is a loss constant characterizing the switching device characteristics and circuit topology. Iron loss coefficient, unit: S, is a proportionality constant characterizing the iron loss properties of a magnetic element; The reactive current component, measured in A, represents the component of the converter output current that is orthogonal to the voltage (90° phase difference), and directly determines the magnitude of reactive power. This is the DC bus voltage, in V, representing the DC side capacitor voltage of the converter. In this embodiment, the iron loss coefficient is taken as 0.05~0.12; the feedforward gain coefficient is adaptively adjusted with the operating temperature to meet the requirements. .

[0051] The key point in the voltage stabilization phase is to update the reactive power dynamic loss compensation. In the inertia and frequency regulation phase, due to the rapid throughput of a large amount of active power, the reactive power loss characteristics of the system, especially the new energy converter and the line, have changed dynamically. The update of the compensation in the voltage stabilization phase reflects the self-adaptation of control parameters and the information inheritance between phases, and is also a continuation of the reactive power margin constraint in the inertia support phase.

[0052] The updated reactive power dynamic loss compensation is superimposed with the reactive power reference value to obtain the reactive power command used for voltage regulation, as shown in the following formula:

[0053] In the formula, This is a reactive power command, measured in var, representing the actual reactive power control command sent to the converter. This is the reactive power reference value, in var, representing the theoretical reactive power demand calculated by the voltage controller. The updated reactive power dynamic loss compensation amount, in var, represents the additional reactive power compensation required to offset loss fluctuations.

[0054] In the embodiments, The output to the SVG and photovoltaic inverter achieves a voltage deviation of ≤0.27%.

[0055] The three-stage coordinated control proposed in this invention utilizes a combination of inertia support provided by the rotor kinetic energy released by the renewable energy power plant and virtual inertia provided by energy storage. This leverages the rotational mass of the renewable energy source and the rapid power throughput of the energy storage. Frequency regulation is explicitly controlled by the energy storage system, executing active power commands. This aligns with the techno-economic characteristics of energy storage—fast power response and high regulation accuracy—making it an ideal resource for executing frequency regulation commands. Voltage stability is explicitly controlled by the renewable energy unit, executing reactive power commands. This utilizes the inherent, rapid reactive power regulation capability of the renewable energy converter and avoids competition with the energy storage system for active power regulation capacity.

[0056] During phase switching, abrupt changes in control commands may cause secondary oscillations. In this embodiment, an overlap region is designed to smoothly decay commands from the previous phase and smoothly increase commands from the next phase. At the end of the second phase, the frequency regulation effect and remaining energy of the energy storage are evaluated. If the frequency regulation effect does not meet expectations or the energy storage capacity is insufficient, some voltage regulation tasks (third phase) can be allocated to other reactive power sources such as SVG in advance, or additional frequency regulation resources can be requested.

[0057] This disclosure can be a system, method, and / or computer program product. A computer program product may include a computer-readable storage medium having computer-readable program instructions loaded thereon for causing a processor to implement various aspects of this disclosure.

[0058] Computer-readable storage media can be tangible devices capable of holding and storing instructions for use by an instruction execution device. Computer-readable storage media can be, for example—but not limited to—electrical storage devices, magnetic storage devices, optical storage devices, electromagnetic storage devices, semiconductor storage devices, or any suitable combination of the foregoing. More specific examples (a non-exhaustive list) of computer-readable storage media include: portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), static random access memory (SRAM), portable compact disc read-only memory (CD-ROM), digital multifunction disc (DVD), memory sticks, floppy disks, mechanical encoding devices, such as punch cards or recessed protrusions storing instructions thereon, and any suitable combination of the foregoing. The computer-readable storage media used herein are not to be construed as transient signals themselves, such as radio waves or other freely propagating electromagnetic waves, electromagnetic waves propagating through waveguides or other transmission media (e.g., light pulses through fiber optic cables), or electrical signals transmitted through wires.

[0059] The computer-readable program instructions described herein can be downloaded from computer-readable storage media to various computing / processing devices, or downloaded via a network, such as the Internet, local area network, wide area network, and / or wireless network, to an external computer or external storage device. The network may include copper transmission cables, fiber optic transmission, wireless transmission, routers, firewalls, switches, gateway computers, and / or edge servers. A network adapter card or network interface in each computing / processing device receives the computer-readable program instructions from the network and forwards them to the computer-readable storage media in the respective computing / processing device.

[0060] Computer program instructions used to perform the operations of this disclosure may be assembly instructions, instruction set architecture (ISA) instructions, machine instructions, machine-dependent instructions, microcode, firmware instructions, status setting data, or source code or object code written in any combination of one or more programming languages, including object-oriented programming languages ​​such as Smalltalk, C++, etc., and conventional procedural programming languages ​​such as the "C" language or similar programming languages. The computer-readable program instructions may execute entirely on the user's computer, partially on the user's computer, as a standalone software package, partially on the user's computer and partially on a remote computer, or entirely on a remote computer or server. In cases involving a remote computer, the remote computer may be connected to the user's computer via any type of network—including a local area network (LAN) or a wide area network (WAN)—or may be connected to an external computer (e.g., via the Internet using an Internet service provider). In some embodiments, electronic circuitry, such as programmable logic circuitry, field-programmable gate arrays (FPGAs), or programmable logic arrays (PLAs), is personalized by utilizing the status information of the computer-readable program instructions to implement various aspects of this disclosure.

[0061] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention and not to limit it. Although the present invention has been described in detail with reference to the above embodiments, those skilled in the art should understand that modifications or equivalent substitutions can still be made to the specific implementation of the present invention. Any modifications or equivalent substitutions that do not depart from the spirit and scope of the present invention should be covered within the protection scope of the claims of the present invention.

Claims

1. A method for time-series coordinated control of the entire transient process of a new energy power station, characterized in that, include: When grid disturbances are detected based on the grid frequency change rate and voltage deviation, coordinated control is triggered. The coordinated control is divided into three phases according to the timing sequence: inertia support phase, frequency regulation phase, and voltage stabilization phase. During the inertia support stage, under the reactive power margin constraint, the rotor kinetic energy of the new energy unit, the output power of the energy storage virtual inertia, and the reactive power dynamic loss compensation are transmitted from the new energy power station to the grid. During the frequency regulation phase, under the constraint of frequency deviation, the extreme value of the frequency change rate is determined based on the real-time frequency change acceleration within the observation time window, and an active power command for frequency regulation is generated based on the extreme value of the frequency change rate; the energy storage executes the active power command to regulate the active power deviation. During the voltage stabilization phase, the reactive power dynamic loss compensation is updated; the updated reactive power dynamic loss compensation is superimposed with the reactive power reference value to obtain the reactive power command; the new energy unit executes the reactive power command to adjust the voltage deviation.

2. The transient full-process time-series coordinated control method for new energy power stations according to claim 1, characterized in that, The high-speed acquisition unit synchronously measures frequency, voltage, and grid-connected power at the 1ms level; when the frequency change rate is detected to be greater than 0.5Hz / s or the voltage deviation is greater than 0.1pu, the three-stage coordinated control is triggered. The period from 0ms to 500ms is the inertia support stage, from 0.5s to 10s is the frequency adjustment stage, and from 10s to minutes is the voltage stabilization stage.

3. The transient full-process time-series coordinated control method for new energy power stations according to claim 1, characterized in that, The reactive power margin constraint is: the output power of the static var generator shall not exceed 80%. , This represents the maximum reactive power output of the static var generator. The rotor kinetic energy of the new energy unit is shown in the following formula: In the formula, This represents the change in mechanical power. For rotational inertia, Angular velocity, Angular acceleration; The output power of the energy storage virtual inertia is shown in the following formula: In the formula, For power adjustment amount, Let be the system inertia constant. The rate of change of frequency; The reactive power dynamic loss compensation is shown in the following formula: In the formula, For the estimated switching loss, This is the switching loss factor. This represents the reactive current component.

4. The transient full-process time-series coordinated control method for new energy power stations according to claim 3, characterized in that, The switching loss factor is calibrated using the IGBT thermal resistance curve: In the formula, This is the junction temperature of the semiconductor. For ambient temperature, This is the reactive current component. To reduce the thermal resistance of the environment.

5. The transient full-process time-series coordinated control method for new energy power stations according to claim 3, characterized in that, The frequency deviation constraint is: the absolute value of the frequency deviation is less than 0.1Hz; The extreme values ​​of the rate of change of frequency are shown in the following formula: In the formula, For the extreme value of the rate of change of frequency, This is the scaling factor. For the observation time window, The second derivative of frequency, It is a time variable.

6. The transient full-process time-series coordinated control method for new energy power stations according to claim 5, characterized in that, The active power command is shown in the following formula: = ( + )+ In the formula, This is an active power command. This is the proportional gain coefficient. For frequency deviation, The integral time constant is... For the acceleration term gain coefficient, Here, is the exponential decay coefficient, and e is the base of the natural logarithm. It is a time variable.

7. The transient full-process time-series coordinated control method for new energy power stations according to claim 6, characterized in that, The updated reactive power dynamic loss compensation is shown in the following formula: In the formula, This is the updated reactive power dynamic loss compensation amount. This is the feedforward gain coefficient. , This is the junction temperature of the semiconductor. This is the switching loss factor. This is the iron loss coefficient. This is the reactive current component. This is the DC bus voltage.

8. The transient full-process time-series coordinated control method for new energy power stations according to claim 7, characterized in that, The updated reactive power dynamic loss compensation is superimposed with the reactive power reference value to obtain the reactive power command used for voltage regulation, as shown in the following formula: In the formula, This is a reactive power command. This is the reactive power reference value. This is the updated reactive power dynamic loss compensation amount.

9. A transient full-process time-series coordinated control system for a new energy power station, used to implement the transient full-process time-series coordinated control method for a new energy power station as described in any one of claims 1 to 8, characterized in that, include: The triggering module is used to trigger coordinated control when grid disturbances are detected based on the grid frequency change rate and voltage deviation. The coordinated control is divided into three stages according to the timing sequence: inertia support stage, frequency regulation stage, and voltage stabilization stage. The inertia support module is used in the inertia support stage to transmit the rotor kinetic energy of the new energy unit, the output power of the energy storage virtual inertia, and the dynamic loss compensation of the reactive power from the new energy power station to the grid under the reactive power margin constraint. The frequency regulation module is used during the frequency regulation phase to determine the extreme value of the frequency change rate based on the real-time frequency change acceleration within the observation time window under the constraint of frequency deviation, and to generate an active power command for frequency regulation based on the extreme value of the frequency change rate; the energy storage executes the active power command to adjust the active power deviation; The voltage stabilization module is used during the voltage stabilization phase to update the reactive dynamic loss compensation amount. The updated reactive dynamic loss compensation amount is superimposed with the reactive power reference value to obtain the reactive power command. The new energy unit executes the reactive power command to adjust the voltage deviation.

10. A terminal, comprising a processor and a storage medium; characterized in that: The storage medium is used to store instructions; The processor is configured to operate according to the instructions to perform the steps of the method according to any one of claims 1-8.

11. A computer-readable storage medium having a computer program stored thereon, characterized in that, When executed by a processor, the program implements the steps of the method according to any one of claims 1-8.

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