A Method for Coordinated Optimization Control of Active Power of Inverters in a Photovoltaic Power Station

Abstract

The present invention discloses a method for coordinated optimization control of active power of inverters in a photovoltaic power station, which relates to the field of active power control methods for photovoltaic power stations and mainly solves problems such as insufficient adjustment accuracy or speed that may be caused by conventional inverter power adjustment methods. This method first excludes inverters with communication interruptions according to the light attenuation between inverters on the loop network. The inverters are divided into regions according to their geographical locations, and sample inverters are selected. The power of the sample inverters is used as the base value for estimating the power of inverters in the same region, and this base value is corrected. Secondly, performance tests are carried out on each inverter to obtain the local adjustment response time, and the adjustment completion time is estimated, so as to comprehensively calculate the time required for adjustment and evaluate the adjustment speed performance. The adjustment accuracy performance of each inverter is evaluated through the historical data of adjustment errors. Finally, a comprehensive adjustment performance function including adjustable capacity, adjustment speed, and adjustment accuracy is constructed, and the optimal inverter combination is selected for power adjustment.

Description

Technical Field

[0001] The present invention relates to the field of active power control of photovoltaic power stations, and particularly relates to a method for coordinated optimization control of active power of inverters in photovoltaic power stations. Background Art

[0002] In recent years, the domestic photovoltaic power generation industry has developed rapidly and become one of the largest photovoltaic power generation markets in the world, with the production capacity of photovoltaic modules continuously expanding. By the end of 2021, the annual production capacity of photovoltaic modules has exceeded 250GW, accounting for more than 70% of the global total production capacity. Due to the wide access of photovoltaic power generation units, the impact of photovoltaic grid connection on the voltage of the distribution network and active power loss is increasing, which makes it more difficult for the planning and dispatching of the distribution network and ultimately leads to a decline in the stability of the power grid. To protect the overall stable operation of the power grid, it is often necessary to perform operations such as power limitation or power increase on photovoltaic power generation stations. To reduce the impact of transient processes on the operation of the power grid, specific requirements are imposed on the regulation speed, regulation accuracy, regulation capacity, etc. during power regulation. Currently, power regulation plans often only calculate the power target values of each region within the power station and evenly distribute them to each inverter within the region, rarely making the regulation plan accurate to individual inverters. However, different inverters within each area may also have different power generation capabilities due to individual differences. Simply averaging the power target values of each area and then distributing them to each inverter may lead to situations such as individual inverters being overloaded, thereby affecting the service life of the inverters and even the safe and stable operation of the entire power grid. Summary of the Invention

[0003] The present invention proposes a method for coordinated optimization control of active power of inverters in photovoltaic power stations, which evaluates the regulation capabilities of each photovoltaic inverter in scenarios such as emergency control, primary frequency modulation, and AGC, and on this basis, optimizes and distributes the power plan, mainly solving problems such as the regulation accuracy or regulation speed of inverters not meeting the operation requirements when the current photovoltaic inverters are adjusted according to control instructions.

[0004] A method for coordinated optimization control of active power of inverters in photovoltaic power stations, based on a control system composed of a station control device, an optical fiber ring network, a ring network switch, and an inverter, is implemented by the following steps:

[0005] Step 1: Use the optical attenuation d between each inverter i to judge the real-time communication link state. When the optical attenuation is lower than the lower limit d min , it is considered that the light source power is too high, which may lead to a series of consequences such as too high bit error rate and equipment damage; when the optical attenuation d i exceeds the upper limit d max , it is considered that the optical attenuation between nodes is too large and the communication quality deteriorates; when either of the above two situations occurs, it is considered that the communication of this inverter is interrupted, and this inverter should be removed from the range of controllable inverters.

[0006] Step 2: Predict the maximum adjustable capacity of each inverter. Divide each inverter in the power station into several zones according to its geographical location, and select sample inverters in each zone. The sample inverters do not participate in power regulation. Take the current power P of the sample inverter sample as the estimated value base of the maximum power generation of the inverters in this zone, and use the correction coefficient k based on the membership function pi to correct the estimated value base of the maximum power generation to obtain the predicted value of the maximum power generation of each inverter When power increase is required, the maximum adjustable capacity of each inverter where P ci is the current power of this inverter. When power decrease is required, the maximum adjustable capacity of each inverter where P si is the minimum adjustable threshold

[0007] Step 3: Predict the regulation speed performance of each inverter. First, conduct performance tests on each inverter to obtain the local regulation response time t of the inverter pi and the time required for single-step regulation t set_i . The local regulation response time t of the inverter pi is defined as the time required for the controlled variable to change to 10% of the step amount from the start of the step amount addition in the step experiment. The time required for single-step regulation is the time interval for each change in voltage or current in the MPPT (Maximum Power Point Tracking) algorithm; when power regulation is required, the regulation response time directly uses the local response time t of the inverter in the performance test pi . The regulation in-place time should be combined with the regulation step value δ of each PV inverter set_i and the time required for single-step regulation t set_i for calculation Add the regulation response time t pi and the regulation in-place time t si to obtain the regulation time t required for each inverter i =t pi +t si , so as to evaluate the regulation speed of each inverter according to the regulation time required

[0008] Step 4: Evaluate the regulation accuracy performance of each inverter in combination with the historical data of the regulation error. Statistically analyze the historical data of the regulation error e i =|P di -P i '| / P Ni in the previous power regulation processes of each inverter, where P di is the target power, Pi ' is the active power of the inverter after entering the regulation dead zone, P Ni is the rated power of the inverter. Construct a pre-calculated table related to the regulation error and the current power generation P i , ambient temperature T i and directly use the look-up table method to select the corresponding e when power regulation is required i to evaluate the regulation accuracy.

[0009] Step five, construct the maximum adjustable capacity of each inverter The required time for regulation t i , regulation error e i as the input parameters of the regulation performance function, and obtain the comprehensive regulation performance Q of the inverter i , and uniformly upload it to the control systems at all levels.

[0010] Step six, when power regulation is required, the control system sorts the inverters according to their comprehensive regulation performance from high to low, and uses this order as the power regulation priority order to meet the requirements of different scenarios such as emergency control, primary frequency modulation, and AGC (Automatic Generation Control). When only AGC regulation is required, in order to ensure that there is still adjustable capacity when emergency control and primary frequency modulation are needed, a threshold should be set for the regulation performance. The inverters below this threshold are regulated by the AGC system according to the principle of comprehensive regulation performance from high to low to issue the target power value.

[0011] The present invention also provides a computer storage medium and an electronic device. Among them, a computer program is stored on the computer storage medium, and when the computer program is executed by a processor, the steps of the method are implemented. The electronic device includes a memory and one or more processors. The memory is used to store one or more programs; when the one or more programs are executed by the one or more processors, the method described above is implemented.

[0012] The beneficial effects of the present invention: The present invention evaluates the adjustable capacity, the time to reach regulation, and the regulation accuracy of the photovoltaic inverter, and sorts the priorities of different inverters in various application scenarios according to the magnitude of the regulation performance, so as to meet the requirements of different scenarios such as emergency control, primary frequency modulation, and AGC, and effectively avoid the situation where the regulation accuracy or regulation speed of the inverter cannot meet the operation requirements due to the lack of adjustable performance of the inverter to meet the time requirements for emergency control after AGC regulation. Description of the Drawings

[0013] Figure 1 is the flow chart of the method of the present invention.

[0014] Figure 2This is the control system architecture diagram of the photovoltaic power station in the present invention.

[0015] Figure 3 This is the membership function curve corresponding to the inverter power generation power in Step 2 of the present invention. Specific embodiments

[0016] The following further describes the present invention with reference to the accompanying drawings.

[0017] The flow of the active power coordination and optimization control method for the inverter of the photovoltaic power station in the present invention is as Figure 1 shown, in which the control system architecture of the photovoltaic power station is as Figure 2 shown, and it consists of a station control device, an optical fiber ring network, a ring network switch, and an inverter. This method is implemented by the following steps:

[0018] Step 1: Judgment of communication link status:

[0019] The present invention uses the optical attenuation between communication devices to evaluate the communication link status. The present invention uses network devices that support SNMP (Simple Network Management Protocol), and configures an SNMP agent and an SNMP management system on the control system, so as to identify and obtain through the specific OID (Object Identifier) of SNMP. Through the optical attenuation d of each inverter i judge the real-time communication link status, count the optical attenuation of each inverter, evaluate the communication link status of the optical fiber ring network, and the optical attenuation data is measured, collected, and sent up by the terminal or the switch. The calculation method of the optical attenuation d between nodes is as follows:

[0020] d = d s - d r

[0021] where d s is the optical attenuation of the sending end, and d r is the optical attenuation of the receiving end.

[0022] The optical attenuation of the optical fiber is usually related to factors such as the cable material and the cable length, and can be written as the following formula:

[0023] d = k d × l

[0024] where k d is the optical attenuation coefficient and l is the cable length.

[0025] Since the optical attenuation coefficient and the cable length of the optical fiber should have been determined during laying, the optical attenuation d of the default communication link of each inverter i should always meet the following standards:

[0026] dmin ≤d i ≤d max

[0027] where d min is the lower limit of strong light attenuation, d max is the upper limit of weak optical attenuation. The range of strong and weak optical attenuation and normal optical attenuation can be calculated based on the attenuation coefficient of the optical fiber and the transmission distance. min ≤d i ≤d max When , it is considered that the node communication is interrupted and the node should be removed from the controllable inverter range.

[0028] Step 2: Maximum power generation prediction:

[0029] Since the maximum power generation of a photovoltaic inverter is mainly related to factors such as light intensity and ambient temperature, photovoltaic inverters in similar geographical locations have similar conditions such as light intensity and ambient temperature. Therefore, the present invention divides the regions according to the geographical locations of each inverter, selects sample inverters in each partition, and the sample inverters do not participate in power regulation. The maximum power generation of the photovoltaic inverters in each partition is predicted with reference to the current power generation of the sample inverters in each partition. Taking into account individual differences such as installation angles, there is still a gap between the power generation of each inverter in the same area and the power generation of the sample inverter. Therefore, it is necessary to use historical data of the same power generation state to correct the predicted maximum power generation of each inverter. The prediction formula is as follows:

[0030]

[0031] in is the predicted value of the maximum power generation of the inverter, k pi is the correction coefficient of each inverter based on the membership function, where the membership is calculated according to the current power of the sample inverter, P sample is the current power generation of the sample inverter.

[0032] The present invention proposes a correction coefficient setting method based on membership function, combining the current power generation of the sample inverter to calculate the corresponding correction coefficient k pi In order to avoid data imbalance and increased complexity caused by too many levels or information loss caused by too few levels, the present invention establishes a power level set based on the inverter, which includes three power levels set in order from low to high, [0,P a ]、[P a ,P b ]、[P b ,P N ], P a , P bare the lower and upper limits corresponding to the medium power, respectively, and P N is the rated power of the sample inverter, and according to the current power generation power P of the sample inverter sample calculate the membership degree μ of each power level ij , then the final correction coefficient k corresponding to each inverter pi can be written in the following form:

[0033]

[0034] where k pij is the correction coefficient corresponding to different power levels of each inverter, and it is necessary to count the ratio between the power P of each inverter at the same time in the historical data i and the power P of the sample inverter sample , and take the average value of this ratio within the corresponding interval as the correction coefficient k of this inverter pij , that is

[0035]

[0036] where P sample_his_1 , P sample_his_2 , …, P sample_his_n are the sample inverter power sampling data corresponding to all in the j-th power level in the historical data, n is the number of corresponding sampling points, and P i_his_1 , P i_his_2 ,..., P i_his_n are the sampling data of the power of each inverter at the same time, n is the number of corresponding sampling points, where P sample_his_x = 0 or P i_his_x = 0, the historical data should not be used as a sample for calculation

[0037] The membership degree μ of each region ij is characterized by a Gaussian membership function, that is, a bell-shaped curve. Then the membership degree μ corresponding to each region ij can be written in the following form:

[0038]

[0039] where P j is the center point of the corresponding membership function, and σ ij is the standard deviation of the membership function. At the center point, the corresponding membership function is the largest, that is, when P sample = P j , μ ij = 1. It is recommended to select P1 = 0, P2 = 0.5P N , P3 = P N , where P N is the rated power of the sample inverter, and σ ijSpecifically affect the width of the membership function. P j , σ ij Should be selected in combination with the specific application of the actual project.

[0040] For example, select σ i1 = σ i2 = σ i3 = 0.1P N , when P i1 = 0, P i2 = 0.5P N , P i3 = P N When, the final membership function is as Figure 2 shown. When the power generation power P of the sample inverter sample = 0.5P N When, at this time, the membership degrees μ of the three power levels corresponding to it i1 = 3.72×10 -6 , μ i2 = 1, μ i3 = 3.72×10 -6 , then the correction coefficient of the inverter at this moment can be considered k pi ≈ k pi2 .

[0041] When power increase is required, the maximum adjustable capacity of the inverter can be expressed as the difference between the maximum power generation power and the current power P ci , that is When power decrease is required, the maximum adjustable capacity of the inverter is the difference between the current power generation power P ci and the minimum adjustable threshold P si , that is

[0042] Step 3. Performance evaluation of the photovoltaic inverter regulation speed:

[0043] Perform performance tests on each inverter to obtain the local regulation response time t pi , the time t required for single-step regulation set_i for testing. Among them, the local regulation response time t of the inverter pi is defined as the time required for the controlled quantity to change to 10% of the step quantity from the start of adding the step quantity in the step test. The time t required for single-step regulation set_i is the interval between each change of voltage or current in the MPPT control algorithm.

[0044] When increasing the power, to prevent the problem of inverter DC voltage collapse and tripping that may occur due to blindly and rapidly setting the power during the ramp-up process, currently, PV inverters mainly adopt the MPPT control method to avoid this situation. During the power generation process, the operating points of voltage and current are adjusted in real time to achieve the maximum power generation. Therefore, the adjustment time to reach the target mainly depends on the fixed value of the adjustment step of the PV inverter. Therefore, the present invention estimates the adjustment time to reach the target based on the fixed value of the adjustment step. When increasing the power, the adjustment time t si The calculation formula is as follows:

[0045]

[0046] where δ set_i is the fixed value of the adjustment step, and t set_i is the time required for a single-step adjustment of the PV inverter.

[0047] The time required for the final adjustment is calculated as follows:

[0048] t i = t pi + t si

[0049] Step 4: Evaluation of the adjustment accuracy performance:

[0050] The present invention evaluates the adjustment accuracy of the inverter based on the historical data of the adjustment error. The adjustment performance requirements in the three scenarios of emergency control, primary frequency modulation, and AGC control are inconsistent. Define the adjustment error as the difference between the generated power of the PV inverter after each adjustment and the target value. The calculation formula is as follows:

[0051]

[0052] where P di is the issued target value, P i ' is the active power of the inverter after entering the adjustment dead zone, and P Ni is the rated power of the inverter.

[0053] Considering that the adjustment error is mainly affected by the properties of the inverter itself, the current generated power, and environmental temperature factors, the present invention establishes a matrix of the adjustment error of each inverter with the generated power and environmental temperature: The information such as generated power and temperature is equally spaced and divided into multiple intervals, and the adjustment error within each interval is statistically calculated to obtain the average value. Among them, when the generated power is in the interval (P m , P n ), and the environmental temperature is in the interval (T x , T y ), the average value of the adjustment error can be expressed as

[0054]

[0055] Among them: e i1 , e i2 ,..., e iw are the historical adjustment errors of each inverter in the corresponding interval, and w is the number of adjustments made in the corresponding interval. When calculating the performance function and it is necessary to calculate the adjustment error, the look-up table method is used to find the average adjustment error in the corresponding interval As the calculated adjustment error e i , so as to evaluate the adjustment accuracy performance. When power adjustment is required, it should be based on the ambient temperature T i at that time and the generated power P i to perform a look-up table method to find the corresponding

[0056] Step Five: Construction of the comprehensive adjustment performance function:

[0057] The present invention proposes a method for constructing a comprehensive adjustment performance function. By normalizing indicators such as adjustment speed, adjustable capacity, and adjustment accuracy, a comprehensive adjustment performance function Q i can be used to represent the required performance indicators, and finally it can be written in the following form

[0058]

[0059] Among them: t i is the adjustment time calculated in Step Three, k1, k2, k3 ∈ (0, 1) are adjustable weight factors, and all inverters should use the same k1, k2, k3 when calculating the performance function is the maximum adjustable power of the PV inverter calculated in Step Two, P Ni is the rated power of the inverter, and e i is the adjustment error obtained from historical data in Step Four. In this comprehensive adjustment performance function, the term 1 / (1 + exp(-k1t i )) represents the adjustment speed performance represents the maximum adjustable capacity performance represents the adjustment accuracy performance. When the inverter performance function Q i is larger, it means that the adjustment performance of the inverter is better. Different k1, k2, k3 can be selected to meet different requirements. When higher requirements are placed on individual performances, the corresponding weight factor k i should be higher. For example, when higher requirements are placed on the adjustment speed, k1 > k2 and k1 > k3

[0060] Step Six: Inverter selection:

[0061] When power adjustment is required, the inverter that meets the performance requirements of the adjustment scenario should be selected first, and the adjustment should be carried out in descending order according to the comprehensive adjustment performance until the adjustable power of the selected inverter combination meets the power demand for this adjustment. When only AGC adjustment is required, in order to ensure that there is still adjustable capacity when emergency control and primary frequency modulation are required, a threshold should be set for the comprehensive adjustment performance. The setting of the threshold should ensure that when the power is reduced, the remaining adjustable capacity of the whole station is not less than α% of the rated power P of the whole station, and when the power is increased, the remaining adjustable capacity of the whole station is not less than β% of the rated power P of the whole station. Both α and β can be set by fixed values, and it is recommended not to be less than 10% and 6%. The inverters below this threshold are adjusted by the AGC system according to the principle of descending comprehensive adjustment performance to issue the target power value. N_set of the whole station, and when the power is increased, the remaining adjustable capacity of the whole station is not less than β% of the rated power P N_set of the whole station. Both α and β can be set by fixed values, and it is recommended not to be less than 10% and 6%. The inverters below this threshold are adjusted by the AGC system according to the principle of descending comprehensive adjustment performance to issue the target power value.

[0062] The technical means disclosed in the solution of the present invention are not limited to the technical means disclosed in the above embodiments, but also include technical solutions composed of any combination of the above technical features. It should be noted that for those of ordinary skill in the art in this technical field, without departing from the principle of the present invention, several improvements and refinements can be made, and these improvements and refinements are also regarded as the protection scope of the present invention.

Claims

1. A photovoltaic power station inverter active power coordinated optimization control method, characterized in that: Based on the control system composed of station control device, optical fiber ring network, ring network switch and inverter, the following steps are specifically included: Step 1: Use the light attenuation between each inverter i Determine the real-time communication link status. When the optical attenuation exceeds the lower limit d min When the light source power is too high, it may lead to a series of consequences such as high bit error rate and equipment damage; when the light decays i Over the limit d max When the above two situations occur, it is considered that the light attenuation between nodes is too large and the communication quality is reduced; when the above two situations occur, it is considered that the inverter communication is interrupted and the inverter should be moved out of the controllable inverter range; Step 2: divide the inverter into several zones according to the geographical location of each inverter in the station, and select sample inverters in each zone. The sample inverters do not participate in power regulation. sample As the estimated value base value of the maximum power generation of the inverter in this partition, and using the correction coefficient k based on the membership function pi Correct the maximum power generation estimated value base value to obtain the maximum power generation predicted value of each inverter When power needs to be increased, the maximum adjustable capacity of each inverter Where P ci The current power of the inverter. When the power needs to be reduced, the maximum adjustable capacity of each inverter Where P si is the minimum adjustable threshold; Step 3: Perform performance tests on each inverter to obtain the inverter local regulation response time t pi , single-step adjustment time t set_i , where the inverter local regulation response time t pi It is defined as the time required from the addition of the step quantity to the change of the controlled quantity to 10% of the step quantity in the step experiment. The time required for single-step regulation is the time interval for each change of voltage or current in the MPPT algorithm. When power regulation is required, the regulation response time directly adopts the local response time t of the inverter in the performance test. pi The adjustment time should be combined with the adjustment step value δ of each photovoltaic inverter. set_i And the time required for single-step adjustment t set_i calculate The response time t pi And the adjustment time t si Add together to get the time t required for each inverter to adjust i =t pi +t si , thereby evaluating the adjustment speed of each inverter according to the time required for adjustment; Step 4: Count the adjustment errors e of each inverter during the power adjustment process i The historical data of the inverter regulation error e is constructed i With power generation P i 、Ambient temperature T i The relevant pre-calculated table is used to directly select the corresponding adjustment error e when power adjustment is required. i As a performance indicator for evaluating regulation accuracy; Step 5: Build the maximum adjustable capacity of each inverter Adjustment time t i , adjustment error e i As the regulation performance function of the input parameters, the inverter comprehensive regulation performance Q is obtained. i ; Step 6: Based on the comprehensive regulation performance Q of each inverter i Sort from high to low, and use this order as the power adjustment priority order to meet the needs of different scenarios such as emergency control, primary frequency regulation, and AGC regulation; In step 5, it is necessary to construct a comprehensive regulation performance function Q for multiple scenarios of emergency control, primary frequency regulation, and AGC of the stability control system. i , taking the regulation speed, adjustable capacity and regulation accuracy as the comprehensive regulation performance function Q i The evaluation criteria are: i The final expression is written as: Where: t i is the time required for regulation calculated in step 3, k1, k2, k3∈(0,1) are adjustable weight factors, and all inverters should use the same k1, k2, k3 when calculating the performance function. is the maximum adjustable power of the photovoltaic inverter calculated in step 2, P Ni is the inverter rated power, e i is the adjustment error obtained from historical data in step 4.

2. The photovoltaic power station inverter active power coordinated optimization control method according to claim 1, characterized in that: In step 1, all the devices in the system use network devices that support SNMP, and SNMP agent and SNMP management system are configured on the control system, so as to realize the light attenuation monitoring of each inverter through the specific OID of SNMP; i Determine the real-time communication link status, count the optical attenuation of each inverter, and evaluate the communication link status of the optical fiber ring network. i The following criteria should always be met under default communication link conditions: d min ≤d i ≤d max where d min is the lower limit of strong light attenuation, d max It is the upper limit of weak light attenuation.

3. The photovoltaic power station inverter active power coordinated optimization control method according to claim 1, characterized in that: In step 2, the maximum power generation prediction value of each inverter is The calculation formula is as follows: k pi is the correction coefficient of each inverter based on the membership function, where the membership is calculated according to the current power of the sample inverter; a power level set based on the sample inverter is established, which contains low power levels [0,P a ], medium power level [P a ,P b ] and high power levels [P b ,P N ]Three power levels, P a and P b are the lower and upper limits corresponding to the medium power level, P N is the rated power of the sample inverter, and according to the current power generation power P of the sample inverter sample Calculate the membership degree μ of each inverter at each power level ij , combined with the correction coefficient k corresponding to each power level pij Calculate the correction coefficient k of each inverter based on the membership function pi : The correction coefficient k corresponding to each inverter in each power level is pij The power generation power P of each inverter in the power-unrestricted state in the historical data is used i_his At the same time, the sample inverter power generation P samplej_his The average value of the ratio is calculated as follows: Where P sample_his_1 ,P sample_his_2 ,…,P sample_his_n is the power sampling data of all sample inverters corresponding to the jth power level in the historical data, and n is the number of corresponding sampling points; P i_his_1 ,P i_his_2 ,...,P i_his_n is the sampling data of the power of each inverter at the same time, n is the number of corresponding sampling points, where P sample_his_x =0 or P i_his_x = 0 when historical data should not be used as sample calculation; The membership degree μ of each inverter at each power level ij The Gaussian membership function, that is, the bell curve, is used for characterization, and its calculation method is as follows: Where P j is the center point of the membership function, σ ij is the standard deviation of the membership function, P j ,σ ij All are determined based on historical data from actual engineering applications.

4. The photovoltaic power station inverter active power coordinated optimization control method according to claim 1, characterized in that: In step 4, the adjustment accuracy needs to be evaluated through the historical data of the adjustment error. The definition of the adjustment error is as follows: Where: P di is the target value issued, P i 'To press P di The active power of the inverter after adjusting to the target value, P Ni is the inverter rated power; construct the regulation error e i With the current power generation P i 、Ambient temperature T i The relevant pre-calculated table divides the power generation and ambient temperature into multiple intervals at equal intervals. m ,P n ) range, the ambient temperature is (T x ,T y ) The average value of the adjustment error adjusted within the interval Expressed as Where: e i1 ,e i2 ,...,e iw is the adjustment error of each inverter in the corresponding interval, and w is the number of adjustments in the corresponding interval; when power adjustment is required, the corresponding value is directly selected by table lookup method. As the adjustment error e i , so as to evaluate the regulation accuracy of each inverter.

5. The photovoltaic power station inverter active power coordinated optimization control method according to claim 1, characterized in that: In step 6, all inverter priorities should be sorted from high to low according to the comprehensive adjustment performance until the adjustable power of the selected inverter combination meets the power demand required for this adjustment; When only AGC adjustment is required, in order to ensure that there is still adjustable capacity during transient and dynamic adjustment, the inverter performance function threshold should be set. The setting of the threshold should ensure that when the power is reduced, the remaining adjustable capacity of the entire station is not less than the rated power P of the entire station. N_set α%, when the power is increased, the remaining adjustable capacity of the whole station shall not be less than the rated power P of the whole station. N_set β%, α and β can be adjusted by fixed values. When the reserved capacity is not enough to meet the AGC regulation capacity demand, the reserved inverter part should be opened for regulation.

6. A computer storage medium, characterized in that: A computer program is stored thereon, and when the computer program is executed by a processor, the steps of the method according to any one of claims 1 to 5 are implemented.

7. An electronic device, characterized in that: It comprises a memory and one or more processors, wherein the memory is used to store one or more programs; when the one or more programs are executed by the one or more processors, the method according to any one of claims 1 to 5 is implemented.

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