A method for emergency control of active power in renewable energy stations considering reactive power support for voltage

Abstract

The present invention discloses an emergency control method for active power of a new energy station considering reactive power support for voltage, which belongs to the field of new energy station control technology and aims to solve the problem that existing control methods fail to fully utilize the regulation potential of new energy stations. The method includes calculating the active power control priority μ of the controllable inverter. p,i and reactive power control priority μ q,i ; Construct a controllable inverter control type T i , according to each inverter μ p,i and μ q,i The result calculates the inverter control type T. i , classifying and ranking them, dynamically assigning inverter control types, and generating dynamic control strategies that prioritize active power control requirements. The system also captures the emergency state, primary frequency regulation, and reactive power control status of renewable energy stations in real time, periodically running and optimizing coordinated control algorithms to select control strategies. This invention maximizes the active and reactive power support capabilities of renewable energy stations and enhances grid stability through precise calculation and dynamic adjustment of control strategies.

Description

Technical Field

[0001] This invention belongs to the field of new energy power station control technology, specifically relating to an emergency active power control method for new energy power stations that considers reactive power support for voltage. Background Technology

[0002] With the transformation of the energy structure, renewable energy power plants, characterized by their cleanliness and renewability, have become an important part of the power system, mainly including wind farms and photovoltaic power plants. In the event of a grid emergency, renewable energy power plants must not only quickly adjust their active power to respond to frequency changes, but also be able to provide reactive power to the maximum extent to maintain voltage stability.

[0003] Existing theoretical methods do not consider the impact of the electrical distance between the power generation unit and the grid connection point of a renewable energy power plant on reactive power support. However, the reactive power support capability of a renewable energy power plant is closely related to the voltage curve of its grid connection point, and the length of the electrical distance directly affects the shape and stability of the voltage curve.

[0004] Based on the problems mentioned above, researchers have proposed an emergency active power control method for new energy power plants that considers reactive power support for voltage. Summary of the Invention

[0005] The purpose of this invention is to provide an emergency control method for active power in renewable energy power plants that takes into account the voltage support of reactive power, so as to solve the problem that existing control methods fail to fully utilize the regulation potential of renewable energy power plants.

[0006] To solve the above problems, the technical solution of the present invention is as follows:

[0007] An emergency control method for active power in renewable energy power plants that considers reactive power support for voltage, comprising the following steps:

[0008] S1. Calculate the active power control priority μ of the controllable inverter. p,i and reactive power control priority μ q,i ;

[0009] Based on the grid connection status and electrical quantity information of each inverter in the new energy power station, it is determined whether it is operating normally, and the inverters that are operating normally are set as controllable inverters.

[0010] Constructing the electrical distance parameter K of the controllable inverter i With available power generation capacity parameter J i Calculate the active power control priority μ of the controllable inverter. p,i and reactive power control priority μ q,i ;

[0011] S2, Constructing a controllable inverter control type T i According to each inverter μ p,i and μq,i The result calculates the inverter control type T. i The inverters are categorized and sorted, and their control types are dynamically allocated. A dynamic control strategy is generated with the aim of prioritizing the active power control requirements.

[0012] Based on the active power control priority μ of the controllable inverter p,i and reactive power control priority μ q,i Calculate the controllable inverter control type T i ;

[0013] Set T i When T = 1, the inverter is of active power control type. i When T = 0, the inverter is of reactive power control type. i Controllable inverters with a power efficiency of 1 are sorted from highest to lowest active power control priority, denoted as μ. p,n ≥μ p,n―1 ≥…≥μ p,2 ≥μ p,1 Similarly, for T i Controllable inverters with a power efficiency of 0 are sorted from highest to lowest reactive power control priority, denoted as μ. q,i ≥μ q,i―1 ≥…≥μ q,n+2 ≥μ q,n+1 ;

[0014] Based on the dynamic control strategy for generating active and reactive power control adjustments at new energy power plants, when T i When the available generating capacity of the active power control inverter with a value of 1 is insufficient to meet the adjustment requirements of active power control, then from T... i In a reactive power control inverter with a reactive power control priority of 0, the inverter is selected for active power compensation in ascending order of reactive power control priority; provided that the active power control requirements are met, if T... i When the available generating capacity of the reactive power control inverter with a value of 0 is insufficient to meet the adjustment requirements of reactive power control, then from T... i In an active power control inverter with a power control priority of 1, the inverter is selected for active power compensation in order of active power control priority from low to high.

[0015] S3. Real-time acquisition of emergency status, primary frequency regulation and reactive power control status of new energy power plants, periodic operation and optimization of coordinated control algorithms, and selection of control strategies.

[0016] Furthermore, in S1, the active power control priority μ of the controllable inverter in the grid-connected feeder is calculated. p,i and reactive power control priority μ q,i ;

[0017] Calculate the electrical distance parameter K of the controllable inverter iThe formula is as follows:

[0018]

[0019] Where L i L represents the electrical distance from the grid connection point of a new energy power plant to the inverter. max This represents the maximum electrical distance from the grid connection point to all inverters; it is used to calculate the available power generation capacity parameter J of the inverters. i The formula is as follows:

[0020]

[0021] Among them, the available power generation capacity P sur,i =max(P max,i —P cur,i ,0), P max,i P represents the inverter's maximum power generation capacity. cur,i This indicates the current active power of the inverter; based on the electrical distance parameter K of the controllable inverter. i Available power generation capacity parameters J i Calculate the active power control priority μ of the controllable inverter. p,i and reactive power control priority μ q,i The calculation formula is as follows:

[0022] μ p,i =K i ×J i

[0023] μ q,i =(1―K) i )×J i

[0024] The above electrical distance parameter K i For fixed parameters, the power generation capacity parameter J can be used. i These are real-time dynamic parameters.

[0025] Furthermore, in S2, the controllable inverter control type T i The calculation method is as follows:

[0026]

[0027] Furthermore, in S2, the dynamic control strategy is specifically as follows:

[0028] S2.1. At the start of this cycle, obtain the current active power control adjustment ΔP of the renewable energy power station. act Reactive power control adjustment ΔQ act ;

[0029] S2.2. Calculate T i Available generating capacity of an active power control inverter with a value of 1 If then, from the reactive power control inverters with T i = 0, accumulate the available power generation capacity in ascending order of the priority of the reactive power control inverters until the active power control requirement is met; calculate the active power compensation set of the inverters {n + 1, n + 2, n + 3, …, x}, and set the active power compensation function

[0030] where x = min{α|α ∈ {n + 1, n + 2, n + 3, …, i} and f(α) > ΔP act}, if x = i, the active power control inverter set for the new energy power station is {1, 2, 3, …, i}, and the reactive power control inverter set is empty; if x < i, the active power control inverter set for the new energy power station is {1, 2, 3, …, x}, and the reactive power control inverter set is {x + 1, x + 2, x + 3, …, i}; otherwise, enter S2.3;

[0031] S2.3. Calculate the available power generation capacity of the reactive power control inverters with T i = 0 If then enter S2.4; otherwise, enter S2.5;

[0032] S2.4. From the active power control inverters with T i = 1, accumulate in ascending order of the priority of the active power control inverters until the reactive power control requirement is met; calculate the minimum inverter set {m, m + 1, m + 2, …, n} that meets the active power control requirement,

[0033] where: m = max{m|m ∈ {1, 2, 3, …, n} and }, if m ≠ 1, calculate the reactive power compensation set of the inverters {1, 2, 3, …, y}, and set the reactive power compensation function where:

[0034] The active power control inverter set for the new energy power station is {y + 1, y + 2, y + 3, …, n}, and the reactive power control inverter set is {1, 2, 3, …, y} ∪ {n + 1, n + 2, n + 3, …, i}; otherwise, enter S2.5;

[0035] S2.5. The active power control inverter set for the new energy power station is {1, 2, 3, …, n}, and the reactive power control inverter set is {n + 1, n + 2, n + 3, …, i}, enter S2.6;

[0036] S2.6. End the calculation for this cycle and begin the next cycle, repeating the control strategy calculations from S2.1 to S2.6.

[0037] Furthermore, in S3, the specific logic of the coordination control strategy is as follows:

[0038] S3.1. At the start of this cycle, acquire the status of the emergency control command issuance and the emergency control command P. wk Primary frequency regulation control command ΔP for grid-connected lines f The current output of new energy power stations (P) cur The latest reactive power control command Q target SVG status of reactive power compensation device state The reactive power Q of the reactive power compensation device svg ;

[0039] S3.2. If an emergency control command is required to stabilize the power generation station, the active power control adjustment amount ΔP is obtained. act =P wk If the current cycle calculation ends, proceed to S3.3; otherwise, proceed to S3.3.

[0040] S3.3. If a frequency modulation control command ΔP exists at present. f Then continue to determine whether there is a new reactive power control command Q. target The latest reactive power control command Q exists. target If it does not exist, proceed to S3.4; otherwise, the new energy power station will perform active power control adjustment ΔP. act =ΔP f End the current cycle calculation; if there is no primary frequency modulation control command ΔP at present. f Then proceed to S3.5;

[0041] S3.4. Calculate the maximum power generation capacity of the renewable energy power plant based on the maximum power generation capacity of N controllable inverters. Based on the maximum power generation capacity of the new energy power station, the current available active power (P) of the new energy power station is calculated. sur =max(P max —P cur ―ΔP f ,0); if P sur If the value is >0, then the status of the reactive power compensation device (SVG) is determined. state Is the power generation station required to provide reactive power support? If so, calculate the reactive power Q that the power generation station needs to support. support =Q target —Q svg Reactive power control adjustment of new energy power plants Active power control adjustment ΔP act =ΔP fThe renewable energy power station executes active power control adjustments and reactive power control adjustments according to the dynamic control strategy, ending the calculation for this cycle; otherwise, the renewable energy power station executes the active power control adjustment ΔP. act =ΔP f Reactive power control adjustment ΔQ act =0, end the calculation for this period;

[0042] S3.5. If a reactive power control command Q is currently in effect. target The reactive power control adjustment amount ΔQ of the new energy power station act =Q target If the current cycle ends, proceed to step S3.6; otherwise, proceed to step S3.6.

[0043] S3.6. End the calculation for this cycle and begin the next cycle by repeating the operations from S3.1 to S3.6.

[0044] The beneficial effects of this invention are as follows:

[0045] (1) The core of this invention lies in calculating the control priority of the inverter's response to active and reactive power, and formulating dynamic control strategies for active and reactive power based on this. By fully utilizing the regulation potential of new energy power plants and giving full play to their ability to support the dynamic power grid, the active and reactive power support capabilities of new energy power plants are maximized through precise calculation and dynamic adjustment of control strategies, thereby enhancing the stability of the power grid.

[0046] Specifically, it has the following technological advantages:

[0047] Emergency Response: Through hierarchical command and dynamic compensation strategies, active power support is rapidly provided during grid failures to ensure priority response to emergency grid needs;

[0048] Precise resource allocation: Through dynamic parameter calculation, inverters with long electrical distances and high availability are prioritized for active power control, while those with shorter electrical distances are prioritized for reactive power support, thus avoiding resource waste.

[0049] Enhanced Adaptability: Real-time updates of power generation capacity parameters J i This ensures that the strategy responds quickly to grid fluctuations and improves the adaptability of new energy power plants to complex operating conditions.

[0050] Strategy flexibility: Prioritize the use of high-priority inverters to quickly meet active power demand, while reserving low-priority inverters as backup resources;

[0051] Coordination capability optimization: By classifying and sorting, resource conflicts between active and reactive power control are avoided, and the overall regulation potential of new energy power plants is maximized.

[0052] Active-reactive power coordination: Under the premise of meeting active power demand, the remaining capacity is flexibly used to support reactive power, thus avoiding voltage instability;

[0053] Enhanced robustness: Periodic strategy updates ensure that the control strategy always matches the real-time state of the power grid. Attached Figure Description

[0054] Figure 1 This is the diagram of the emergency state, primary frequency regulation and reactive power coordination control strategy of the new energy power station described in S2 of Embodiment 1 of the present invention.

[0055] Figure 2 This is a diagram of the real-time control strategy for new energy power stations as described in S3 of Embodiment 1 of the present invention. Detailed Implementation

[0056] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. 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.

[0057] Therefore, the following detailed description of embodiments of the invention provided in the accompanying drawings is not intended to limit the scope of the claimed invention, but merely to illustrate selected embodiments of the invention.

[0058] Example 1

[0059] An emergency control method for active power in renewable energy power plants that considers reactive power support for voltage, the method comprising the following steps:

[0060] S1. Calculate the active power control priority μ of the controllable inverter. p,i and reactive power control priority μ q,i ;

[0061] Based on the grid connection status and electrical quantity information of each inverter in the new energy power station, it is determined whether it is operating normally, and the inverters that are operating normally are set as controllable inverters.

[0062] Constructing the electrical distance parameter K of the controllable inverter i With available power generation capacity parameter J i Calculate the active power control priority μ of the controllable inverter. p,i and reactive power control priority μ q,i ;

[0063] Calculate the active power control priority μ of the controllable inverter in the grid-connected feeder. p,i and reactive power control priority μ q,i ; Calculate the electrical distance parameter K of the controllable inverter i The formula is as follows:

[0064]

[0065] Where L i L represents the electrical distance from the grid connection point of a new energy power plant to the inverter. max This represents the maximum electrical distance from the grid connection point to all inverters; it is used to calculate the available power generation capacity parameter J of the inverters. i The formula is as follows:

[0066]

[0067] Among them, the available power generation capacity P sur,i =max(P max,i —P cur,i ,0), P max,i P represents the inverter's maximum power generation capacity. cur,i This indicates the current active power of the inverter; based on the electrical distance parameter K of the controllable inverter. i Available power generation capacity parameter J i Calculate the active power control priority μ of the controllable inverter. p,i and reactive power control priority μ q,i The calculation formula is as follows:

[0068] μ p,i =K i ×J i

[0069] μ q,i =(1―K) i )×J i

[0070] The above electrical distance parameter K i For fixed parameters, the power generation capacity parameter J can be used. i These are real-time dynamic parameters.

[0071] S2, Constructing a controllable inverter control type T i According to each inverter μ p,i and μ q,i The result calculates the inverter control type T. i The inverters are categorized and sorted, and their control types are dynamically allocated. A dynamic control strategy is generated with the aim of prioritizing the active power control requirements.

[0072] Based on the active power control priority μ of the controllable inverter p,i and reactive power control priority μ q,i Calculate the controllable inverter control type T i Controllable inverter control type T i The calculation method is as follows:

[0073]

[0074] Set T i When T = 1, the inverter is of active power control type. i When T = 0, the inverter is of reactive power control type. i Controllable inverters with a power efficiency of 1 are sorted from highest to lowest active power control priority, denoted as μ. p,n ≥μ p,n―1 ≥…≥μ p,2 ≥μ p,1 Similarly, for T i Controllable inverters with a power efficiency of 0 are sorted from highest to lowest reactive power control priority, denoted as μ. q,i ≥μ q,i―1 ≥…≥μ q,n+2 ≥μ q,n+1 Based on the dynamic control strategy generated by the active and reactive power control adjustments of the new energy power station, when t i When the available generating capacity of the active power control inverter with a value of 1 is insufficient to meet the adjustment requirements of active power control, then from T... i In a reactive power control inverter with a reactive power control priority of 0, the inverter is selected for active power compensation in ascending order of reactive power control priority; provided that the active power control requirements are met, if T... i When the available generating capacity of the reactive power control inverter with a value of 0 is insufficient to meet the adjustment requirements of reactive power control, then from T... i In an active power control inverter with a power control priority of 1, the inverter is selected for active power compensation in order of active power control priority from low to high.

[0075] like Figure 2 As shown, the specific strategy is as follows:

[0076] S2.1. At the start of this cycle, obtain the current active power control adjustment ΔP of the renewable energy power station. act Reactive power control adjustment ΔQ act S2.2. Calculate T i Available generating capacity of an active power control inverter with a value of 1 like Then from T i In a reactive power control inverter with a power density of 0, the available generating capacity is accumulated sequentially according to the priority of the reactive power control inverters from low to high until the active power control requirement is met. The active power compensation set {n+1,n+2,n+3,…,x} of the inverter is calculated, and the active power compensation function is defined.

[0077] Where x = min{α|α∈{n+1,n+2,n+3,…,i} and f(α)>ΔP act}, if x = i, the set of active power control inverters for the new energy power station is {1, 2, 3, …, i}, and the set of reactive power control inverters is empty; if x < i, the set of active power control inverters for the new energy power station is {1, 2, 3, …, x}, and the set of reactive power control inverters is {x + 1, x + 2, x + 3, …, i}; otherwise, enter S2.3.

[0078] S2.3. Calculate T i The available power generation capacity of the reactive power control inverters with T If Then enter S2.4; otherwise, enter S2.5.

[0079] S2.4. From the active power control inverters with T i = 1, accumulate them in ascending order of the priority of the active power control inverters until the reactive power control requirement is met. Calculate the smallest set of inverters {m, m + 1, m + 2, …, n} that meets the active power control requirement.

[0080] Among them: If m ≠ 1, calculate the inverter reactive power compensation set {1, 2, 3, …, y}, and set the reactive power compensation function Among them:

[0081] The set of active power control inverters for the new energy power station is {y + 1, y + 2, y + 3, …, n}, and the set of reactive power control inverters is {1, 2, 3, …, y} ∪ {n + 1, n + 2, n + 3, …, i}; otherwise, enter S2.5.

[0082] S2.5. The set of active power control inverters for the new energy power station is {1, 2, 3, …, n}, and the set of reactive power control inverters is {n + 1, n + 2, n + 3, …, i}, and enter S2.6.

[0083] S2.6. End the calculation of this cycle, and start the next cycle to repeat the control strategy operation from S2.1 to S2.6.

[0084] S3. Obtain the emergency state, primary frequency modulation, and reactive power control state of the new energy power station in real time, run cyclically, optimize the coordinated control algorithm, and select the control strategy.

[0085] As Figure 1 shown, the specific logic of the coordinated control algorithm is as follows:

[0086] S3.1. At the beginning of this cycle, obtain the state of the stable control emergency control command issuance, the stable control emergency control command P wk , the primary frequency modulation control command ΔP f of the grid-connected line, and the current output P of the new energy power stationcur The latest reactive power control command Q target SVG status of reactive power compensation device state The reactive power Q of the reactive power compensation device svg .

[0087] S3.2. If an emergency control command is required to stabilize the power generation station, the active power control adjustment amount ΔP is obtained. act =P wk If the current cycle ends, proceed to S3.3; otherwise, proceed to S3.3.

[0088] S3.3. If a frequency modulation control command ΔP exists at present. f Then continue to determine whether there is a new reactive power control command Q. target The latest reactive power control command Q exists. target If it does not exist, proceed to S3.4; otherwise, the new energy power station will perform active power control adjustment ΔP. act =ΔP f End the current cycle calculation; if there is no primary frequency modulation control command ΔP at present. f Then proceed to S3.5.

[0089] S3.4. Calculate the maximum power generation capacity of the renewable energy power plant based on the maximum power generation capacity of N controllable inverters. Based on the maximum power generation capacity of the new energy power station, the current available active power (P) of the new energy power station is calculated. sur =max(P max —P cur ―ΔP f ,0); if P sur If the value is >0, then the status of the reactive power compensation device (SVG) is determined. state Is the power generation station required to provide reactive power support? If so, calculate the reactive power Q that the power generation station needs to support. support =Q target —Q svg Reactive power control adjustment of new energy power plants Active power control adjustment ΔP act =ΔP f The renewable energy power station executes active power control adjustments and reactive power control adjustments according to the dynamic control strategy, ending the calculation for this cycle; otherwise, the renewable energy power station executes the active power control adjustment ΔP. act =ΔP f Reactive power control adjustment ΔQ act =0, end the calculation for this period.

[0090] S3.5. If a reactive power control command Q is currently in effect. target The reactive power control adjustment amount ΔQ of the new energy power station act =Qtarget If the current cycle ends, proceed to S3.6; otherwise, proceed to S3.6.

[0091] S3.6. End the calculation for this cycle and begin the next cycle by repeating the operations from S3.1 to S3.6.

Claims

1. A method for emergency active power control of renewable energy power plants considering reactive power support for voltage, characterized in that: The method consists of the following steps: S1. Calculate the active power control priority μ of the controllable inverter. p,i and reactive power control priority μ q,i ; Based on the grid connection status and electrical quantity information of each inverter in the new energy power station, it is determined whether it is operating normally, and the inverters that are operating normally are set as controllable inverters. Constructing the electrical distance parameter K of the controllable inverter i With available power generation capacity parameter J i Calculate the active power control priority μ of the controllable inverter. p,i and reactive power control priority μ q,i ; S2, Constructing a controllable inverter control type T i According to each inverter μ p,i and μ q,i The result calculates the inverter control type T. i The inverters are categorized and sorted, and their control types are dynamically allocated. A dynamic control strategy is generated with the aim of prioritizing the active power control requirements. Based on the active power control priority μ of the controllable inverter p,i and reactive power control priority μ q,i Calculate the controllable inverter control type T i ; Set T i When T = 1, the inverter is of active power control type. i When T = 0, the inverter is of reactive power control type. i Controllable inverters with a power efficiency of 1 are sorted from highest to lowest active power control priority, denoted as μ. p,n ≥μ p,n―1 ≥…≥μ p,2 ≥μ p,1 Similarly, for T i Controllable inverters with a power efficiency of 0 are sorted from highest to lowest reactive power control priority, denoted as μ. q,i ≥μ q,i―1 ≥…≥μ q,n+2 ≥μ q,n+1 ; Based on the dynamic control strategy for generating active and reactive power control adjustments at new energy power plants, when T i When the available generating capacity of the active power control inverter with a value of 1 is insufficient to meet the adjustment requirements of active power control, then from T... i In a reactive power control inverter with a reactive power control priority of 0, the inverter is selected for active power compensation in ascending order of reactive power control priority; provided that the active power control requirements are met, if T... i When the available generating capacity of the reactive power control inverter with a value of 0 is insufficient to meet the adjustment requirements of reactive power control, then from T... i In an active power control inverter with a power control priority of 1, the inverter is selected for active power compensation in order of active power control priority from low to high. S3. Real-time acquisition of emergency status, primary frequency regulation and reactive power control status of new energy power plants, periodic operation and optimization of coordinated control algorithms, and selection of control strategies.

2. The method for emergency active power control of new energy power plants considering reactive power support for voltage, as described in claim 1, is characterized in that: In S1, the active power control priority μ of the controllable inverter in the grid-connected feeder is calculated. p,i and reactive power control priority μ q,i ; Calculate the electrical distance parameter K of the controllable inverter i The formula is as follows: Where L i L represents the electrical distance from the grid connection point of a new energy power plant to the inverter. max This represents the maximum electrical distance from the grid connection point to all inverters; it is used to calculate the available power generation capacity parameter J of the inverters. i The formula is as follows: Among them, the available power generation capacity P sur,i =max(P max,i —P cur,i ,0), P max,i P represents the inverter's maximum power generation capacity. cur,i This indicates the current active power of the inverter; based on the electrical distance parameter K of the controllable inverter. i Available power generation capacity parameters J i Calculate the active power control priority μ of the controllable inverter. p,i and reactive power control priority μ q,i The calculation formula is as follows: m p,i =K i ×J i m q,i =(1-K i )×J i The above electrical distance parameter K i For fixed parameters, the power generation capacity parameter J can be used. i These are real-time dynamic parameters.

3. The method for emergency active power control of new energy power plants considering reactive power support for voltage, as described in claim 1, is characterized in that: In S2, the controllable inverter control type T i The calculation method is as follows:

4. The active power emergency control method for new energy power plants considering reactive power support for voltage, as described in claim 1, is characterized in that: In S2, the dynamic control strategy is specifically as follows: S2.

1. At the start of this cycle, obtain the current active power control adjustment ΔP of the renewable energy power station. act Reactive power control adjustment ΔQ act ; S2.

2. Calculate T i Available generating capacity of an active power control inverter with a value of 1 like Then from T i In a reactive power control inverter with a power density of 0, the available generating capacity is accumulated sequentially according to the priority of the reactive power control inverters from low to high until the active power control requirements are met; the active power compensation set {n+1,n+2,n+3,…,x} of the inverter is calculated, and the active power compensation function is set. where \(x = \min\{\alpha|\alpha\in\{n + 1,n + 2,n + 3,\ldots,i\}\text{ and}f(\alpha)>\Delta P\}\) act}, if \(x = i\), the set of active power control inverters for the new energy power station is \(\{1,2,3,\ldots,i\}\), and the set of reactive power control inverters is empty. If \(x < i\), the set of active power control inverters for the new energy power station is \(\{1,2,3,\ldots,x\}\), and the set of reactive power control inverters is \(\{x + 1,x + 2,x + 3,\ldots,i\}\); otherwise, proceed to S2.3; S2.

3. Calculate T i Available generating capacity of a reactive power control inverter with a value of 0 like Then proceed to S2.4; Otherwise proceed to S2.5; S2.

4. From T i In the active power control inverters with a priority of 1, the active power control inverters are added sequentially from low to high priority until the reactive power control requirement is met; calculate the minimum set of inverters {m,m+1,m+2,…,n} that meets the active power control requirement. in: If m≠1, then calculate the inverter reactive power compensation set {1,2,3,…,y}, and set the reactive power compensation function. in: The set of active power control inverters in the new energy power plant is {y+1,y+2,y+3,…,n}, and the set of reactive power control inverters is {1,2,3,…,y}∪{n+1,n+2,n+3,…,i}; otherwise, proceed to S2.

5. S2.

5. The set of active power control inverters in the new energy power plant is {1,2,3,…,n}, and the set of reactive power control inverters is {n+1,n+2,n+3,…,i}. Proceed to S2.

6. S2.

6. End the calculation for this cycle and begin the next cycle, repeating the control strategy calculations from S2.1 to S2.

6.

5. The method for emergency active power control of a new energy power station considering reactive power support for voltage, as described in claim 1, is characterized in that: In S3, the specific logic of the coordination control strategy is as follows: S3.

1. At the start of this cycle, acquire the status of the emergency control command issuance and the emergency control command P. wk Primary frequency regulation control command ΔP for grid-connected lines f The current output of new energy power stations (P) cur The latest reactive power control command Q target SVG status of reactive power compensation device state The reactive power Q of the reactive power compensation device svg ; S3.

2. If an emergency control command is required to stabilize the power generation station, the active power control adjustment amount ΔP is obtained. act =P wk If the current cycle calculation ends, proceed to S3.3; otherwise, proceed to S3.

3. S3.

3. If a frequency modulation control command ΔP exists at present. f Then continue to determine whether there is a new reactive power control command Q. target The latest reactive power control command Q exists. target If it does not exist, proceed to S3.4; otherwise, the new energy power station will perform active power control adjustment ΔP. act =ΔP f End the current cycle calculation; if there is no primary frequency modulation control command ΔP at present. f Then proceed to S3.5; S3.

4. Calculate the maximum power generation capacity of the new energy power station based on the maximum power generation capacity of N controllable inverters. Based on the maximum power generation capacity of the new energy power station, the current available active power (P) of the new energy power station is calculated. sur =max(P max —P cur ―ΔP f ,0); if P sur If the value is >0, then the status of the reactive power compensation device (SVG) is determined. state Is the power generation station required to provide reactive power support? If so, calculate the reactive power Q that the power generation station needs to support. support =Q target —Q svg Reactive power control adjustment of new energy power plants Active power control adjustment ΔP act =ΔP f The renewable energy power station executes active power control adjustments and reactive power control adjustments according to the dynamic control strategy, ending the calculation for this cycle; otherwise, the renewable energy power station executes the active power control adjustment ΔP. act =ΔP f Reactive power control adjustment ΔQ act =0, end the calculation for this period; S3.

5. If a reactive power control command Q is currently in effect. target The reactive power control adjustment amount ΔQ of the new energy power station act =Q target If the current cycle ends, proceed to step S3.6; otherwise, proceed to step S3.

6. S3.

6. End the calculation for this cycle and begin the next cycle by repeating the operations from S3.1 to S3.6.

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