New energy station active emergency control method considering reactive power to voltage support

Abstract

The invention discloses a new energy station active emergency control method considering reactive power to voltage support, belongs to the technical field of new energy station control, and aims to solve the problem that an existing control method cannot fully utilize the adjustment potential of a new energy station. The method comprises the following steps: calculating an active control priority mu p, i and a reactive control priority mu q, i of the controllable inverter; constructing a control type Ti of a controllable inverter, calculating the control type Ti of the inverter according to the results of mu p, i and mu q, i of each inverter, performing classification and sorting, dynamically distributing the control types of the inverters, and generating a dynamic control strategy by adopting the purpose of preferentially meeting the active power control requirement; the emergency state, the primary frequency modulation state and the reactive power control state of the new energy station are obtained in real time, periodic operation is performed, a coordination control algorithm is optimized, and a control strategy is selected. According to the invention, through accurate calculation and dynamic adjustment of the control strategy, the active and reactive support capabilities of the new energy station are maximized, and the stability of the power grid is enhanced.

Description

Technical Field

[0001] The present invention belongs to the technical field of new energy station control, and in particular relates to an active power emergency control method for a new energy station taking into account reactive power support for voltage. Background Art

[0002] With the transformation of energy structure, new energy stations have become an important part of the power system with their clean and renewable characteristics, mainly including wind farms and photovoltaic power stations. In the event of an emergency in the power grid, new energy stations should not only quickly adjust active power to respond to frequency changes, but also be able to provide reactive power to the maximum extent to maintain voltage stability.

[0003] Theoretical methods in the prior art have not considered the impact of the electrical distance between the power generation unit of a new energy station and the grid connection point on reactive power support. The reactive power support capacity of a new energy station 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 in the above background technology, researchers have proposed an emergency control method for active power of new energy stations taking into account reactive power support for voltage. Summary of the invention

[0005] The purpose of the present invention is to provide an emergency control method for active power of a new energy station taking into account reactive power support for voltage, so as to solve the problem that the existing control methods fail to fully utilize the regulation potential of the new energy station.

[0006] In order to solve the above problems, the technical solution of the present invention is:

[0007] A method for emergency control of active power of a new energy station considering reactive power support for voltage, the method 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] Determine whether each inverter in the new energy station is operating normally based on the grid-connected status and electrical quantity information, and set the normally operating inverter as a controllable inverter;

[0010] Constructing the electrical distance parameter K of the controllable inverter i and the 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 controllable inverter control type T i , according to each inverter μ p,i and μq,i The result of calculating the inverter control type T i , and classify and sort them, dynamically allocate the control type of the inverter, and generate a dynamic control strategy with the purpose of giving priority to meeting the active power control requirements;

[0012] According to the active power control priority μ of the controllable inverter p,i and reactive power control priority μ q,i , calculate the control type T of the controllable inverter i ;

[0013] Set T i =1, the inverter is in active control type, T i = 0, the inverter is in reactive power control mode. i = 1 are sorted from high to low according to the active power control priority, expressed as μ p,n ≥μ p,n―1 ≥…≥μ p,2 ≥μ p,1 Similarly, for T i = 0 are sorted from high to low according to the reactive power control priority, expressed as μ q,i ≥μ q,i―1 ≥…≥μ q,n+2 ≥μ q,n+1 ;

[0014] Generate dynamic control strategy based on active and reactive power control adjustment of new energy stations. i = 1. When the available power generation capacity of the active power control inverter is insufficient to meet the adjustment requirements of active power control, the active power control inverter is switched from T i =0, select the inverter for active power compensation in the order of reactive power control priority from low to high; if T i = 0. When the available generating capacity of the reactive power control inverter is insufficient to meet the reactive power control adjustment requirements, the reactive power control inverter is switched from T i =1, in the order of active power control priority from low to high, select the inverter to compensate the active power;

[0015] S3. Obtain the emergency status, primary frequency regulation and reactive power control status of new energy stations in real time, run and optimize the coordinated control algorithm periodically, and select the control strategy.

[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 Indicates the electrical distance from the grid connection point of the new energy station to the inverter, L max Indicates the maximum value of the electrical distance from the grid connection point to all inverters; calculates the inverter's available power generation capacity parameter J i The formula is as follows:

[0020]

[0021] The available power generation capacity P sur,i =max(P max,i ―P cur,i ,0),P max,i Indicates the maximum power generation capacity of the inverter, P cur,i Indicates the current active power of the inverter; according to 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:

[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 is a fixed parameter, and the available power generation capacity parameter J i It is a real-time dynamic parameter.

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

[0026]

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

[0028] S2.1. At the beginning of this cycle, obtain the current active power control adjustment value ΔP of the new energy station act , reactive power control adjustment ΔQ act ;

[0029] S2.2. Calculation of T i = 1 active power control inverter available power generation capacity If then, from the reactive power control inverters with T i = 0, the available power generation capabilities are accumulated in ascending order of the priority of the reactive power control inverters until the active power control requirements are 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 set of active power control inverters for the new energy power station to execute 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 to execute 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;

[0031] S2.3. Calculate the available power generation capabilities 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 requirements are met; calculate the smallest set of inverters {m, m + 1, m + 2, …, n} that meet the active power control requirements,

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

[0034] The set of active power control inverters for the new energy power station to execute 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;

[0035] 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;

[0036] S2.6. End the calculation of this cycle and start the next cycle to repeat the control strategy calculations from S2.1 to S2.6.

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

[0038] S3.1. At the beginning of this cycle, obtain the status of the stable control emergency control command issuance and the stable control emergency control command P wk , grid-connected line primary frequency modulation control command ΔP f 、Current output of new energy stations P cur , the latest reactive power control instruction Q target , reactive power compensation device status SVG state , the current reactive power Q of the reactive power compensation device svg ;

[0039] S3.2. If the current emergency control command needs to be issued, the active power control adjustment value ΔP of the new energy station is obtained act =P wk , end the calculation of this cycle; otherwise, enter S3.3;

[0040] S3.3. If there is a frequency modulation control instruction ΔP f , then continue to determine whether there is a latest reactive power control instruction Q target , there is the latest reactive power control instruction Q target , then enter S3.4, if it does not exist, the new energy station will execute the active power control adjustment ΔP act =ΔP f , end the calculation of this cycle; if there is no frequency modulation control instruction ΔP f , then enter S3.5;

[0041] S3.4. Calculate the maximum power generation capacity of the new energy station based on the maximum power generation capacity of N controllable inverters Calculate the current available active power P of the new energy station based on the maximum power generation capacity of the new energy station sur =max(P max ―P cur ―ΔP f ,0); if P sur >0, then judge the status of reactive power compensation device SVG state , whether the new energy station needs to provide reactive power support. If necessary, calculate the reactive power Q that the new energy station needs to support support =Q target ―Q svg , reactive power control adjustment of new energy stations Active power control adjustment ΔP act =ΔP f, the new energy station executes the active control adjustment and reactive control adjustment according to the dynamic control strategy, and ends the calculation of this cycle; otherwise, the new energy station executes the active control adjustment ΔP act =ΔP f , reactive power control adjustment ΔQ act =0, end the calculation of this cycle;

[0042] S3.5. If there is currently a reactive power control instruction Q target , then the reactive power control adjustment amount of the new energy station ΔQ act =Q target , end the calculation of this cycle; otherwise, enter S3.6;

[0043] S3.6. End the calculation of this cycle and start the next cycle to repeat the operations of S3.1 to S3.6.

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

[0045] (1) The core of the present invention is to calculate the control priority of the inverter's response to active power and reactive power, and formulate active and reactive dynamic control strategies on this basis. Make full use of the regulation potential of new energy stations, give full play to their ability in dynamic support of the power grid, maximize the active and reactive support capabilities of new energy stations through precise calculation and dynamic adjustment of control strategies, and enhance the stability of the power grid.

[0046] Specifically, the technical advantages are as follows:

[0047] Emergency response: Through command classification and dynamic compensation strategies, active power support is quickly provided in the event of a power grid failure, ensuring priority response to emergency power grid needs;

[0048] Accurate resource allocation: Through dynamic parameter calculation, inverters with long electrical distance and high available capacity are given priority to undertake active power control, while inverters with long electrical distance and high available capacity are given priority to undertake reactive power control, thus avoiding resource waste;

[0049] Enhanced adaptability: Real-time update of power generation capacity parametersJ i , ensuring that the strategy responds quickly to grid fluctuations and improving the adaptability of new energy sites to complex working conditions;

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

[0051] Optimization of coordination capability: By classifying and sorting, conflicts between active and reactive control resources can be avoided, and the overall regulation potential of new energy stations can be maximized;

[0052] Active-reactive coordination: On the premise of meeting active power demand, the remaining capacity is flexibly called upon to support reactive power and avoid voltage instability;

[0053] Enhanced robustness: Periodic strategy updates ensure that the control strategy always matches the real-time status of the power grid. BRIEF DESCRIPTION OF THE DRAWINGS

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

[0055] Figure 2 This is the real-time control strategy diagram of the new energy station described in S3 in Example 1 of the present invention. DETAILED DESCRIPTION

[0056] In order to make the purpose, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of the present invention.

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

[0058] Example 1

[0059] A method for emergency control of active power of a new energy station considering reactive power support for voltage is provided, 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] Whether the inverter is operating normally is determined based on the grid-connected status and electrical quantity information of each inverter in the new energy station, and the normally operating inverter is set as the controllable inverter.

[0062] Constructing the electrical distance parameter K of the controllable inverter i and the 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 Indicates the electrical distance from the grid connection point of the new energy station to the inverter, L max Indicates the maximum value of the electrical distance from the grid connection point to all inverters; calculates the inverter's available power generation capacity parameter J i The formula is as follows:

[0066]

[0067] The available power generation capacity P sur,i =max(P max,i ―P cur,i ,0),P max,i Indicates the maximum power generation capacity of the inverter, P cur,i Indicates the current active power of the inverter; according to 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 is a fixed parameter, and the available power generation capacity parameter J i It is a real-time dynamic parameter.

[0071] S2. Constructing controllable inverter control type T i , according to each inverter μ p,i and μ q,i The result of calculating the inverter control type T i , and classify and sort them, dynamically allocate the control type of the inverter, and generate a dynamic control strategy with the purpose of giving priority to meeting the active power control requirements;

[0072] According to the active power control priority μ of the controllable inverter p,i and reactive power control priority μ q,i , calculate the control type T of the controllable inverter i ,Controllable inverter control type T i The calculation is as follows:

[0073]

[0074] Set T i =1, the inverter is in active control type, T i = 0, the inverter is in reactive power control mode. i = 1 are sorted from high to low according to the active power control priority, expressed as μ p,n ≥μ p,n―1 ≥…≥μ p,2 ≥μ p,1 Similarly, for T i = 0 are sorted from high to low according to the reactive power control priority, expressed as μ q,i ≥μ q,i―1 ≥…≥μ q,n+2 ≥μ q,n+1 ; Generate dynamic control strategy based on active and reactive power control adjustment of new energy stations. i = 1. When the available power generation capacity of the active power control inverter is insufficient to meet the adjustment requirements of active power control, the active power control inverter is switched from T i =0, select the inverter for active power compensation in the order of reactive power control priority from low to high; if T i = 0. When the available generating capacity of the reactive power control inverter is insufficient to meet the reactive power control adjustment requirements, the reactive power control inverter is switched from T i =1, in the order of active power control priority from low to high, the inverter is selected to compensate the active power.

[0075] like Figure 2 The specific strategies are as follows:

[0076] S2.1. At the beginning of this cycle, obtain the current active power control adjustment value ΔP of the new energy station act , reactive power control adjustment ΔQ act S2.2. Calculation of T i = 1 active power control inverter available power generation capacity like Then from T i = 0, the available power generation capacity is accumulated in the order of reactive power control inverter priority from low to high until the active power control demand is met. Calculate the inverter active compensation set {n+1, n+2, n+3, …, x} and set the active power compensation function

[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, go to S2.3.

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

[0079] S2.4. From the active power control inverters with i T = 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] Where: If m ≠ 1, calculate the inverter reactive power compensation set {1, 2, 3, …, y}, and set the reactive power compensation function Where:

[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, go to 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}, then go to S2.6.

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

[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 and 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 instruction issuance, the stable control emergency control instruction P wk , the primary frequency modulation control instruction ΔP f of the grid-connected line, and the current output P of the new energy power stationcur , the latest reactive power control instruction Q target , reactive power compensation device status SVG state , the current reactive power Q of the reactive power compensation device svg .

[0087] S3.2. If the current emergency control command needs to be issued, the active power control adjustment value ΔP of the new energy station is obtained act =P wk , end the calculation of this cycle; otherwise, enter S3.3.

[0088] S3.3. If there is a frequency modulation control instruction ΔP f , then continue to determine whether there is a latest reactive power control instruction Q target , there is the latest reactive power control instruction Q target , then enter S3.4, if it does not exist, the new energy station will execute the active power control adjustment ΔP act =ΔP f , end the calculation of this cycle; if there is no frequency modulation control instruction ΔP f , then enter S3.5.

[0089] S3.4. Calculate the maximum power generation capacity of the new energy station based on the maximum power generation capacity of N controllable inverters Calculate the current available active power P of the new energy station based on the maximum power generation capacity of the new energy station sur =max(P max ―P cur ―ΔP f ,0); if P sur >0, then judge the status of reactive power compensation device SVG state , whether the new energy station needs to provide reactive power support. If necessary, calculate the reactive power Q that the new energy station needs to support support =Q target ―Q svg , reactive power control adjustment of new energy stations Active power control adjustment ΔP act =ΔP f , the new energy station executes the active control adjustment and reactive control adjustment according to the dynamic control strategy, and ends the calculation of this cycle; otherwise, the new energy station executes the active control adjustment ΔP act =ΔP f , reactive power control adjustment ΔQ act =0, ending the calculation of this cycle.

[0090] S3.5. If there is currently a reactive power control instruction Q target , then the reactive power control adjustment amount of the new energy station ΔQ act =Qtarget , end the calculation of this cycle; otherwise, enter S3.6.

[0091] S3.6. End the calculation of this cycle and start the next cycle to repeat the operations of S3.1 to S3.6.

Claims

1. A method for emergency control of active power of a new energy station considering reactive power support for voltage, characterized in that: The method is as follows: S1. Calculate the active power control priority μ of the controllable inverter p,i and reactive power control priority μ q,i ; Determine whether each inverter in the new energy station is operating normally based on the grid-connected status and electrical quantity information, and set the normally operating inverter as a controllable inverter; Constructing the electrical distance parameter K of the controllable inverter i and the 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 controllable inverter control type T i , according to each inverter μ p,i and μ q,i The result of calculating the inverter control type T i , and classify and sort them, dynamically allocate the control type of the inverter, and generate a dynamic control strategy with the purpose of giving priority to meeting the active power control requirements; According to the active power control priority μ of the controllable inverter p,i and reactive power control priority μ q,i , calculate the control type T of the controllable inverter i ; Set T i =1, the inverter is in active control mode, T i = 0, the inverter is in reactive power control mode. i = 1 are sorted from high to low according to the active power control priority, expressed as μ p,n ≥μ p,n―1 ≥…≥μ p,2 ≥μ p,1 Similarly, for T i = 0 are sorted from high to low according to the reactive power control priority, expressed as μ q,i ≥μ q,i―1 ≥…≥μ q,n+2 ≥μ q,n+1 ; Generate dynamic control strategy based on active and reactive power control adjustment of new energy stations. i = 1. When the available power generation capacity of the active power control inverter is insufficient to meet the adjustment requirements of active power control, the active power control inverter is switched from T i =0, select the inverter for active power compensation in the order of reactive power control priority from low to high; if T i = 0. When the available generating capacity of the reactive power control inverter is insufficient to meet the reactive power control adjustment requirements, the reactive power control inverter is switched from T i =1, in the order of active power control priority from low to high, select the inverter to compensate the active power; S3. Obtain the emergency status, primary frequency regulation and reactive power control status of new energy stations in real time, run and optimize the coordinated control algorithm periodically, and select the control strategy.

2. The method for emergency control of active power of a new energy station considering reactive power support for voltage according to claim 1, 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 Indicates the electrical distance from the grid connection point of the new energy station to the inverter, L max Indicates the maximum value of the electrical distance from the grid connection point to all inverters; calculates the inverter's available power generation capacity parameter J i The formula is as follows: The available power generation capacity P sur,i =max(P max,i ―P cur,i ,0),P max,i Indicates the maximum power generation capacity of the inverter, P cur,i Indicates the current active power of the inverter; according to 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: m p,i =K i ×J i m q,i =(1-K i )×J i The above electrical distance parameter K i is a fixed parameter, and the available power generation capacity parameter J i It is a real-time dynamic parameter.

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

4. The method for emergency control of active power of a new energy station considering reactive power support for voltage according to claim 1, characterized in that: In S2, the dynamic control strategy is as follows: S2.

1. At the beginning of this cycle, obtain the current active power control adjustment value ΔP of the new energy station act , reactive power control adjustment ΔQ act ; S2.

2. Calculation of T i = 1 active power control inverter available power generation capacity like Then from T i =0, the available power generation capacity is accumulated in the order of reactive power control inverter priority from low to high until the active power control demand is met; the inverter active compensation set {n+1, n+2, n+3, …, x} is calculated, and the active power compensation function is set where \(x = \min\{\alpha|\alpha\in\{n + 1,n + 2,n + 3,\cdots,i\}\text{ and}f(\alpha)>\Delta P\}\) act}, if \(x = i\), the set of active power control inverters of the new energy power station is \(\{1,2,3,\cdots,i\}\), and the set of reactive power control inverters is empty. If \(x < i\), the set of active power control inverters of the new energy power station is \(\{1,2,3,\cdots,x\}\), and the set of reactive power control inverters is \(\{x + 1,x + 2,x + 3,\cdots,i\}\); otherwise, go to S2.3; S2.

3. Calculation of T i = 0 reactive power control inverter available generating capacity like Then go to S2.4; otherwise go to S2.5; S2.

4. From T i = 1, the active control inverters are accumulated in order of priority from low to high until the reactive power control requirement is met; the minimum inverter set {m, m+1, m+2, …, n} that meets the active power control requirement is calculated, in: If m≠1, calculate the inverter reactive compensation set {1,2,3,…,y} and set the reactive power compensation function in: The set of inverters for active power control executed by the new energy station is {y+1, y+2, y+3, …, n}, and the set of inverters for reactive power control is {1, 2, 3, …, y}∪{n+1, n+2, n+3, …, i}; otherwise, enter S2.5; S2.

5. The set of active control inverters of the new energy station is {1, 2, 3, ..., n}, and the set of reactive control inverters is {n+1, n+2, n+3, ..., i}, and the process goes to S2.6; S2.

6. End the calculation of this cycle and start the next cycle to repeat the control strategy calculations from S2.1 to S2.

6.

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

1. At the beginning of this cycle, obtain the status of the stable control emergency control command issuance and the stable control emergency control command P wk , grid-connected line primary frequency modulation control command ΔP f 、Current output of new energy stations P cur , the latest reactive power control instruction Q target , reactive power compensation device status SVG state , the current reactive power Q of the reactive power compensation device svg ; S3.

2. If the current emergency control command needs to be issued, the active power control adjustment value ΔP of the new energy station is obtained act =P wk , end the calculation of this cycle; otherwise, enter S3.3; S3.

3. If there is a frequency modulation control instruction ΔP f , then continue to determine whether there is a latest reactive power control instruction Q target , there is the latest reactive power control instruction Q target , then enter S3.4, if it does not exist, the new energy station will execute the active power control adjustment ΔP act =ΔP f , end the calculation of this cycle; if there is no frequency modulation control instruction ΔP f , then enter S3.5; S3.

4. Calculate the maximum power generation capacity of the new energy station based on the maximum power generation capacity of N controllable inverters Calculate the current available active power P of the new energy station based on the maximum power generation capacity of the new energy station sur =max(P max ―P cur ―ΔP f ,0); if P sur >0, then judge the status of reactive power compensation device SVG state , whether the new energy station needs to provide reactive power support. If necessary, calculate the reactive power Q that the new energy station needs to support support =Q target ―Q svg , reactive power control adjustment of new energy stations Active power control adjustment ΔP act =ΔP f , the new energy station executes the active control adjustment and reactive control adjustment according to the dynamic control strategy, and ends the calculation of this cycle; otherwise, the new energy station executes the active control adjustment ΔP act =ΔP f , reactive power control adjustment ΔQ act =0, end the calculation of this cycle; S3.

5. If there is currently a reactive power control instruction Q target , then the reactive power control adjustment amount of the new energy station ΔQ act =Q target , end the calculation of this cycle; otherwise, enter S3.6; S3.

6. End the calculation of this cycle and start the next cycle to repeat the operations of S3.1 to S3.6.

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