Real-time coordination control method for multi-type voltage regulation devices of active power distribution network

Abstract

The present application relates to a kind of active power distribution network multi-type voltage regulating equipment real-time coordination control method, comprising: step 1: by phasor measurement unit (PMU) or monitoring and data acquisition unit (SCADA) obtains data, based on the data obtained, the selection of window period is carried out, and according to line voltage sensitivity, voltage is estimated, according to the charge-discharge equation of battery energy storage, the battery state of charge (SOC) is predicted;Step 2: based on the bandwidth limit of on-load tap changer (OLTC) and the power deviation of distributed new energy (DG), voltage is smoothed and corrected, and the constraint condition based on distributed new energy and battery energy storage system (BESS) is constructed;Step 3: to avoid early depletion of battery energy storage system, according to the difference between battery state of charge and battery reference state of charge, the active power of battery energy storage system is adjusted.The method can solve the problem of mutual interference when mechanical voltage regulating equipment and energy storage equipment operate.

Description

TECHNICAL FIELD

[0001] The application belongs to the technical field of voltage control of power distribution network, and particularly relates to a real-time coordination control method for multiple types of voltage regulating devices of an active power distribution network. BACKGROUND

[0002] With the continuous growth of global energy consumption, the demand for new energy is also increasing. Distributed new energy equipment, as an important part of new energy development, has advantages such as wide distribution, small scale, and environmental protection. However, the output of distributed new energy equipment is affected by external environmental factors and has randomness and uncertainty, resulting in voltage fluctuations with characteristics of short duration and large fluctuations. Traditional devices can be used to regulate voltage, and mechanical voltage regulation is generally load regulation and switchable capacitor banks. However, traditional mechanical voltage regulating devices have the problems of slow response and long action time, which makes them difficult to dynamically track and quickly adjust. This is not flexible enough in the face of frequent voltage fluctuations in the power grid or the need for fine adjustment.

[0003] Compared with traditional mechanical voltage regulating devices, continuous voltage regulating devices such as energy storage rely on inverters to connect to the grid and have dynamic voltage regulating capability. Energy storage devices have faster response time and can more timely adjust voltage to respond to changes in the power grid. Energy storage devices have strong dynamic voltage fluctuation tracking capability and fine voltage regulation granularity, and can effectively address voltage problems caused by large-scale access of distributed new energy. Due to the differences in action response time and regulation granularity between the two types of voltage regulating devices, how to coordinate their operation and avoid mutual interference to jointly participate in voltage regulation of the active power distribution network is a problem that needs to be solved. SUMMARY

[0004] The purpose of the present application is to provide a real-time coordination control method for multiple types of voltage regulating devices of an active power distribution network to solve the problem of mutual interference between mechanical voltage regulating devices and energy storage devices during operation.

[0005] To achieve the above purpose, the technical solution adopted by the present application is as follows: a real-time coordination control method for multiple types of voltage regulating devices of an active power distribution network, comprising:

[0006] Step 1: Obtain data through a phasor measurement unit (PMU) or a supervisory control and data acquisition unit (SCADA), select a window period based on the obtained data, estimate voltage according to line-to-line voltage sensitivity, and predict battery state of charge (SOC) according to the charge and discharge equation of the battery energy storage system (BESS);

[0007] Step 2: Smooth and correct the voltage based on the bandwidth limitation of the on-load tap changer (OLTC) and the power deviation of the distributed new energy (DG), and construct constraint conditions based on the distributed new energy and the battery energy storage system (BESS);

[0008] Step 3: To prevent the battery energy storage system from being depleted prematurely, adjust the active power of the battery energy storage system based on the difference between the battery's charge and the battery's reference charge.

[0009] Furthermore, in step 1, the distributed new energy system monitors and controls the active distribution network through PMU and SCADA. PMU acquires relevant data by being installed on the battery energy storage system, and SCADA collects real-time information on the rapid changes in the power system caused by the integration of different power electronic devices and renewable energy.

[0010] By analyzing the power fluctuations of distributed renewable energy in different periods, a period of 10 seconds was selected as the window period.

[0011] The method for estimating voltage is as follows:

[0012] The power values ​​of distributed renewable energy at three times t, t+2 and t+4 are measured respectively, and the predicted power value of distributed renewable energy at time t+10 is obtained by substituting it into equation (1).

[0013]

[0014] In the formula, It is the predicted value of distributed renewable energy power at the end of the cycle, P DG (t), P DG (t+2) and P DG (t+4) represent the measured values ​​of distributed renewable energy power at times t, t+2, and t+4, respectively; in each control cycle, the voltage deviation ΔV caused by the introduction of distributed renewable energy into the system is... DG as follows:

[0015]

[0016] In the formula, It is the line-to-line voltage sensitivity relative to the active power at the common coupling point;

[0017] The method for predicting SOC based on the charge and discharge equations of battery energy storage is as follows:

[0018]

[0019] In the formula, SOC(t+10) pred This represents the predicted SOC of BESS, where SOC(t) is the SOC at the start of the control loop, and ΔP b This is the power required by BESS. This is the nominal voltage of BESS, C b This is the rated capacity of BESS.

[0020] Further, the method of smoothing and modifying the voltage in step 2 is as follows:

[0021] According to the voltage sensitivity and voltage deviation, the voltage is smoothed and limited in the set range, considering the voltage deviation ΔV caused by the distributed new energy system DG , to obtain the target function of the voltage deviation caused by the introduction of distributed new energy generation; specifically as follows:

[0022]

[0023] In the formula, and are the average line voltage sensitivity coefficients with respect to active power and reactive power respectively; ΔP B , ΔQ B and ΔQ DG are the active and reactive power deviations of the BESS and the reactive power deviation of the distributed new energy.

[0024] Further, the correction process of the voltage deviation is as follows:

[0025] If the voltage exceeds the set range, the voltage is adjusted to ensure that the voltage regulation provided by the BESS and the distributed new energy can keep the voltage outside the OLTC dead zone;

[0026]

[0027] In the formula, is the corrected voltage deviation, V ref is the reference voltage, ΔP DG is the power deviation of the distributed new energy inverter, V PCC is the measured point voltage, V db is the dead zone voltage of the OLTC, [], ||, β, V min and V max represent the maximum integer function of voltage setting, absolute value function, correction factor, minimum voltage and maximum voltage limit respectively; β is 10% of the upper or lower voltage limit;

[0028] When the predicted voltage deviation at time t is greater than V max , the voltage deviation is adjusted to β outside the OLTC dead zone, so that the OLTC tap change signal remains continuous, and the OLTC changes its tap after a time delay T D ; through this voltage correction process, the voltage violation is corrected, so that the voltage is always kept within the appropriate range, thereby improving the resistance of the system to interference.

[0029] Further, in step 2, the constraints of the distributed new energy and battery energy storage system include ramp rate limit, power limit, SOC limit and power factor limit.

[0030] Further, the ramp rate limit is as follows:

[0031]

[0032]

[0033] wherein, are the maximum active and reactive power changes of the BESS, respectively, is the maximum reactive power change of the photovoltaic.

[0034] Further, the power limit is as follows:

[0035]

[0036] wherein, denotes the maximum power that the BESS can provide, P BZ denotes the sum of the active power and the active power deviation of the BESS.

[0037] Further, the SOC limit is as follows:

[0038] SOC min ≤ SOC (t + 10) pred ≤ SOC max (11)

[0039] wherein, SOC min is the minimum value that the SOC can reach, SOC max is the maximum value that the SOC can reach.

[0040] Further, the power factor limit is as follows:

[0041]

[0042] wherein, PF B and COSψ DG are the power factors of the BESS and the distributed new energy inverter, respectively; Q BZ is the sum of the reactive power and the reactive power deviation of the BESS, P DGZ is the sum of the active power and the active power deviation of the distributed new energy, Q DGZ is the sum of the reactive power and the reactive power deviation of the distributed new energy.

[0043] Further, in step 3, the early depletion problem of the BESS is as follows:

[0044] When dealing with voltage fluctuation at the PCC, the priority is to stabilize the voltage through reactive power compensation; the BESS can provide reactive power to balance the demand of the grid in this process, thereby alleviating voltage fluctuation; this also indirectly prompts the BESS to enter the dormant state, because only when the required reactive power exceeds the reserve will the BESS be awakened and put into operation;

[0045] However, if there is a long time voltage fluctuation and frequent need for BESS to provide reactive power, this will cause the BESS to be depleted prematurely, thereby affecting the availability of the BESS in future possible emergency situations; in order to avoid early depletion of the BESS, ΔP B is modified as and according to search for the next optimal value and so that the SOC is close to its reference level SOC ref ;

[0046] The SOC adjustment method of the BESS is as follows:

[0047] 1) Charging process

[0048] When the BESS is charging, the optimal value of ΔP B is negative in the control cycle; by modifying the value of ΔP B , the SOC is close to SOC ref ; if the current SOC is greater than its reference SOC value, the charging power is reduced to avoid early depletion of the BESS;

[0049] If the SOC value is less than its reference value, then increase ΔP B to close to its reference value; when SOC is equal to SOC max , tends to zero; the specific formula is as follows:

[0050]

[0051] In the formula, SOC ref is the reference SOC; is the optimal active power change of the BESS;

[0052] 2) Discharge process

[0053] The same as the charging process can be obtained:

[0054]

[0055] In the formula, and the distance between the current SOC and SOC ref is in direct proportion;

[0056] 3) SOC adjustment method

[0057] Priority is given to voltage fluctuation events, and if the voltage exceeds the specified range, the SOC adjustment method will not be executed, but the voltage violation event will be treated as a priority, and the system will divert the required active power elsewhere to avoid the voltage from continuing to exceed the specified range;

[0058] The SOC adjustment formula is as follows:

[0059]

[0060] In the formula, is the active power required by the optimized BESS.

[0061] Compared with the prior art, the present application has the following beneficial effects: the present application provides a real-time coordination control method for active power distribution network multi-type voltage regulating equipment, which reduces the mutual interference between devices by coordinating the operation of distributed new energy inverters, BESS and traditional OLTC, improves the ability to respond to voltage violations, improves the anti-interference ability of the system, and greatly reduces the BESS, bringing economic benefits. In addition, through the coordinated operation between devices, compared with the traditional control scheme, the OLTC tap operation is reduced. BRIEF DESCRIPTION OF DRAWINGS

[0062] Figure 1 is a flowchart of the real-time coordination control method for active power distribution network multi-type voltage regulating equipment of the embodiment of the present application;

[0063] Figure 2 is a realization principle block diagram of the real-time coordination control method for active power distribution network multi-type voltage regulating equipment of the embodiment of the present application;

[0064] Figure 3 is a window period selected by the embodiment of the present application. DETAILED DESCRIPTION

[0065] The present application will be further described below in conjunction with the drawings and embodiments.

[0066] It should be pointed out that the following detailed description is exemplary and is intended to provide further description of the present application. Unless otherwise specified, all technical and scientific terms used herein have the same meaning as generally understood by those skilled in the art to which the present application belongs.

[0067] It should be noted that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to limit the exemplary embodiments according to this application. As used herein, the singular form is intended to include the plural form as well, unless the context clearly indicates otherwise. Furthermore, it should be understood that when the terms "comprising" and / or "including" are used in this specification, they indicate the presence of features, steps, operations, devices, components, and / or combinations thereof.

[0068] like Figure 1 , 2 As shown in the figure, this embodiment provides a real-time coordinated control method for multiple types of voltage regulating equipment in an active power distribution network, including the following steps.

[0069] Step 1: Acquire data through a phasor measurement unit (PMU) or a monitoring and data acquisition unit (SCADA), select a window period based on the acquired data, estimate the voltage based on the line-to-line voltage sensitivity, and predict the battery charge (SOC) based on the battery energy storage charge and discharge equation.

[0070] Specifically, the distributed renewable energy system uses PMUs and SCADA systems to monitor and control the active power distribution network. PMUs acquire relevant data by being installed on battery energy storage systems, while SCADA systems collect real-time information on rapid changes in the power system caused by the integration of different power electronic devices and renewable energy sources. For example, PMUs and SCADA sensors can collect data on P... DG Q DG P B Q B V PCC And the data required by SOC, etc.

[0071] Distributed renewable energy power fluctuates frequently, affecting voltage variations. However, the power fluctuations in a distributed renewable energy system are predictable because they exhibit a linear relationship during a small cyclic window. Power changes can be observed and power and state of charge (SOC) predicted by selecting an appropriate window period. Based on the analysis of distributed renewable energy power fluctuations at different times, a 10-second period is selected as the window period. The window period selected in this embodiment is as follows: Figure 3 As shown.

[0072] The method for estimating voltage is as follows:

[0073] The power values ​​of distributed renewable energy at three times t, t+2 and t+4 are measured respectively, and the predicted power value of distributed renewable energy at time t+10 is obtained by substituting it into equation (1).

[0074]

[0075] In the formula, P (t) is the predicted value of the distributed new energy power at the end of the cycle, P DG (t), P DG (t+2) and P DG (t+4) are the measured values of the distributed new energy power at t, t+2 and t+4 respectively.

[0076] In each control cycle, the voltage deviation ΔV DG caused by the distributed new energy introduced into the system is as follows:

[0077]

[0078] In the formula, is the line-to-line voltage sensitivity with respect to the active power of the common coupling point.

[0079] The method for predicting SOC according to the charge and discharge equation of the battery energy storage is as follows:

[0080]

[0081] In the formula, SOC(t+10) pred represents the predicted SOC of the BESS, SOC(t) is the SOC at the beginning of the control cycle, ΔP b is the power required by the BESS, is the nominal voltage of the BESS, C b is the rated capacity of the BESS.

[0082] Step 2: Smooth and correct the voltage based on the bandwidth limitation of the on-load tap changer (OLTC) and the power deviation of the distributed new energy (DG), and construct the constraint condition based on the distributed new energy and the battery energy storage system (BESS).

[0083] The specific method for smoothing and modifying the voltage is as follows:

[0084] According to the voltage sensitivity and the voltage deviation, the voltage is smoothed and limited within a set range, considering the voltage deviation ΔV DG caused by the introduction of the distributed new energy generation, to obtain the objective function of the voltage deviation caused by the introduction of the distributed new energy generation; specifically as follows:

[0085]

[0086] In the formula, and are the average line voltage sensitivity coefficients with respect to the active power and the reactive power respectively; ΔP B , ΔQ B and ΔQ DG are the active and reactive deviations of the BESS and the reactive deviation of the distributed new energy respectively.

[0087] The correction process of voltage deviation is as follows:

[0088] If the voltage exceeds the set range, the voltage is adjusted to ensure that the voltage regulation provided by the BESS and the distributed new energy can keep the voltage outside the dead zone of the OLTC. In this way, the continuity of the OLTC tap signal can be maintained, and the OLTC remains in the voltage regulation loop. When the OLTC changes its tap, the power consumed by the BESS will be adjusted accordingly after the OLTC waiting period, which helps to ensure that the BESS is available in future emergencies.

[0089]

[0090] wherein, is the corrected voltage deviation, V ref is the reference voltage, ΔP DG is the distributed new energy inverter power deviation, V PCC is the measured point voltage, V db is the dead zone voltage of the OLTC, [], ||, β, V min and V max respectively represent the maximum integer function of voltage setting, the absolute value function, the correction factor, the minimum voltage and the maximum voltage limit; β is 10% of the upper or lower voltage limit.

[0091] Specifically, when the predicted voltage deviation at time t is greater than V max , the voltage deviation is adjusted to β outside the OLTC dead zone, so that the OLTC tap change signal remains continuous, and the OLTC changes its tap after a time delay T D . Through this voltage correction process, the voltage violation will be corrected, so that the voltage is always kept within the appropriate range, and the resistance of the system to interference is improved.

[0092] Based on the constraints of the distributed new energy and the battery energy storage system, including the slope rate limit, the power limit, the SOC limit and the power factor limit optimization limit.

[0093] wherein, the slope rate limit is as follows:

[0094]

[0095] wherein, are the maximum changes of active and reactive power of the BESS, respectively, is the maximum reactive power change of the photovoltaic. Generally, the slope rate range of the distributed new energy inverter and the BESS inverter is between several percent and several thousandths. The value range of X1, X2 and X3 may be 1-2% of the change of active power and reactive power per second.

[0096] During discharging or charging, the maximum power value provided by the BESS should be subject to the maximum power limit of the BESS itself, whether it is active power or reactive power. The power limit is as follows:

[0097]

[0098] In the formula, Pmax represents the maximum power that the BESS can provide, P BZ represents the sum of active and active deviation of the BESS.

[0099] For the protection of the BESS, some restrictions need to be made on the SOC to prevent excessive discharge or charge of the BESS. The SOC limit condition is as follows:

[0100] SOC min ≤ SOC (t + 10) pred ≤ SOC max (11)

[0101] In the formula, SOC min is the minimum value that the SOC can reach, and SOC max is the maximum value that the SOC can reach.

[0102] The power factor limit is as follows:

[0103]

[0104] In the formula, PF B and COSψ DG are the power factors of the BESS and the distributed new energy inverter, respectively; Q BZ is the sum of reactive and reactive deviation of the BESS, P DGZ is the sum of active and active deviation of the distributed new energy, Q DGZ is the sum of reactive and reactive deviation of the distributed new energy. θ takes a value between 0.95 and 1, and η takes a value between 0.8 and 1.

[0105] Step 3: To avoid early depletion of the battery energy storage system, the active power of the battery energy storage system is adjusted according to the difference between the battery state of charge and the battery reference state of charge.

[0106] The early depletion problem of the BESS is that when dealing with voltage fluctuations at the PCC, the priority is to stabilize the voltage through reactive power compensation. The BESS can provide reactive power to balance the demand of the power grid during this process, thereby reducing voltage fluctuations. This also indirectly prompts the BESS to enter a dormant state, because only when the required reactive power exceeds the reserve, the BESS will be awakened and put into operation.

[0107] However, if there is a long time voltage fluctuation and the BESS is frequently required to provide reactive power, this can cause the BESS to be prematurely depleted. This can affect the availability of the BESS in future emergency situations that can arise. In order to avoid early depletion of the BESS, ΔP B is modified to and according to the next optimal value is searched and to make the SOC close to its reference level SOC ref .

[0108] The SOC adjustment method for the BESS is:

[0109] 1) Charging process

[0110] When the BESS is charging, the optimal value of ΔP B is negative in the control cycle; by modifying the value of ΔP B to make the SOC close to SOC ref ; if the current SOC is greater than its reference SOC value, the charging power is reduced to avoid the problem of early depletion of the BESS.

[0111] If the SOC value is less than its reference value, then increase ΔP B to close to its reference value; when SOC is equal to SOC max , tends to zero; the specific formula is as follows:

[0112]

[0113] In the formula, SOC ref is the reference SOC; ΔP B r is the optimal active power change of the BESS.

[0114] 2) Discharge process

[0115] The same as the charging process can be obtained:

[0116]

[0117] In the formula, and the distance between the current SOC and SOC ref is in direct proportion.

[0118] 3) SOC adjustment method

[0119] The SOC adjustment method will give priority to voltage fluctuation events, and if the voltage exceeds the specified range, the SOC adjustment method will not be executed, but the voltage violation event will be treated as a priority, and the system will divert the required active power elsewhere to avoid the voltage from continuing to exceed the specified range.

[0120] The SOC adjustment formula is as follows:

[0121]

[0122] In the formula, is the required active power of the optimized BESS.

[0123] The application provides a real-time coordination control method for multi-type voltage regulation equipment of an active power distribution network, which utilizes real-time phasor measurement unit (PMU) data to coordinate an on-load tap changer (OLTC), a battery energy storage system (BESS) and a distributed new energy inverter for optimal control. First, phasor measurement units (PMUs) and supervisory control and data acquisition (SCADA) are used to measure data, and then a window period is selected, voltage and SOC are predicted, and voltage correction is performed. Then, key values such as SOC and power are constrained. Finally, to avoid early depletion of the BESS, the active power of the battery energy storage system is adjusted according to the distance between the battery state of charge and the battery reference state of charge, which makes the SOC recover to the reference level faster to cope with an upcoming emergency. The application solves the problems of fast and slow changes in voltage caused by distributed new energy systems and loads, reduces the mutual interference between devices, and solves the problem of early depletion of the BESS.

[0124] Those skilled in the art will understand that the embodiments of the present application can be provided as methods, systems, or computer program products. Therefore, the present application can take the form of an entirely hardware embodiment, an entirely software embodiment, or an embodiment combining software and hardware aspects. Moreover, the present application can take the form of a computer program product implemented on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROMs, optical storage, etc.) containing computer-usable program code.

[0125] The present application is described with reference to flowcharts and / or block diagrams according to the methods, devices (systems), and computer program products of the embodiments of the present application. It should be understood that each flow and / or block in the flowcharts and / or block diagrams, and the combination of flows and / or blocks in the flowcharts and / or block diagrams can be implemented by computer program instructions. These computer program instructions can be provided to a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing devices to produce a machine, so that the instructions executed by the processor of the computer or other programmable data processing devices produce a device that implements the functions described in the flowcharts and / or block diagrams.Figure 1 apparatuses that implement the functions specified in the flowchart Figure 1 block or blocks.

[0126] These computer program instructions can also be stored in a computer readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer readable memory produce an article of manufacture including instructions which implement the flowchart Figure 1 apparatuses that implement the functions specified in the flowchart Figure 1 block or blocks.

[0127] These computer program instructions can also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions that are executed on the computer or other programmable apparatus provide steps for implementing the flowchart Figure 1 apparatuses that implement the functions specified in the flowchart Figure 1 block or blocks.

[0128] The above descriptions are only preferred embodiments of the present application, and are not intended to limit the present application to other forms described. Any person skilled in the art may make modifications or improvements to the above-described embodiments based on the disclosed technical content, and the modifications or improvements are equivalent embodiments. However, any simple modifications, equivalent changes and modifications of the above embodiments that do not deviate from the technical solution of the present application and are based on the technical essence of the present application are still within the protection scope of the present application.

Claims

1. A method for real-time coordinated control of multiple types of voltage regulating equipment in an active power distribution network, characterized in that, include: Step 1: Acquire data through the phasor measurement unit (PMU) or the monitoring and data acquisition unit (SCADA), select the window period based on the acquired data, estimate the voltage according to the line-to-line voltage sensitivity, and predict the battery state of charge (SOC) according to the battery energy storage charge and discharge equation. Step 2: Smooth and correct the voltage based on the bandwidth limitation of the on-load tap changer (OLTC) and the power deviation of the distributed renewable energy (DG), and construct constraints based on the distributed renewable energy and battery energy storage system (BESS). Step 3: To prevent the battery energy storage system from being depleted prematurely, adjust the active power of the battery energy storage system based on the difference between the battery's charge and the battery's reference charge. In step 1, the distributed new energy system monitors and controls the active distribution network through PMU and SCADA. PMU acquires relevant data by being installed on the battery energy storage system, and SCADA collects real-time information on the rapid changes in the power system caused by the integration of different power electronic devices and renewable energy sources. By analyzing the power fluctuations of distributed renewable energy in different periods, a period of 10 seconds was selected as the window period. The method for estimating voltage is as follows: The values ​​of distributed renewable energy power at three times t, t+2 and t+4 are measured respectively, and the values ​​are substituted into equation (1) to obtain the predicted value of distributed renewable energy power at time t+10. In the formula, It is the predicted value of distributed renewable energy power at the end of the cycle. , and These are the measured values ​​of distributed renewable energy power at times t, t+2, and t+4, respectively; and the voltage deviation caused by the introduction of distributed renewable energy into the system during each control cycle. as follows: In the formula, It is the line-to-line voltage sensitivity relative to the active power at the common coupling point; The method for predicting SOC based on the charge and discharge equations of battery energy storage is as follows: In the formula, This represents the predicted SOC of BESS. It controls the SOC at the start of the control loop. This is the power required by BESS. That is the nominal voltage of BESS. This is the rated capacity of BESS; In step 2, the method for smoothing and modifying the voltage is as follows: Based on voltage sensitivity and voltage deviation, the voltage is smoothed and limited within a set range, taking into account voltage deviation caused by distributed renewable energy systems. The objective function for the voltage deviation caused by the introduction of distributed renewable energy generation is obtained; the details are as follows: In the formula, and These are the average line voltage sensitivity coefficients relative to active power and reactive power, respectively. , and These are the active and reactive power deviations of BESS and the reactive power deviation of distributed renewable energy sources, respectively.

2. The real-time coordinated control method for multiple types of voltage regulating equipment in an active power distribution network according to claim 1, characterized in that, The correction process for voltage deviation is as follows: If the voltage exceeds the set range, the voltage will be adjusted to ensure that the voltage regulation provided by BESS and distributed renewable energy can keep the voltage outside the dead zone of OLTC. In the formula, This is the corrected voltage deviation. It is the reference voltage. It is the power deviation of distributed renewable energy inverters. It measures the voltage at the common point. It is the dead zone voltage of the OLTC, []. , , and These represent the maximum integer function, absolute value function, correction factor, minimum voltage, and maximum voltage limit, respectively. 10% of the upper or lower voltage limit; When the predicted voltage deviation at time t is greater than At that time, the voltage deviation is adjusted to be outside the OLTC dead zone. To ensure that the tap change signal of the OLTC remains continuous, and with a time delay The OLTC then changes its taps; through this voltage correction process, voltage violations are corrected, keeping the voltage within a suitable range, thereby improving the system's resistance to interference.

3. The real-time coordinated control method for multiple types of voltage regulating equipment in an active power distribution network according to claim 1, characterized in that, In step 2, the constraints based on distributed new energy and battery energy storage systems include ramp rate limits, power limits, SOC limits, and power factor limits.

4. The real-time coordinated control method for multiple types of voltage regulating equipment in an active power distribution network according to claim 3, characterized in that, The slope ratio is limited as follows: In the formula, , These represent the maximum changes in active and reactive power of BESS, respectively. This represents the maximum reactive power change in photovoltaic systems.

5. The real-time coordinated control method for multiple types of voltage regulating equipment in an active power distribution network according to claim 3, characterized in that, The power limits are as follows: In the formula, This indicates the maximum power that BESS can provide. This represents the sum of the active power and active power deviation of the BESS.

6. The real-time coordinated control method for multiple types of voltage regulating equipment in an active power distribution network according to claim 3, characterized in that, SOC limitations are as follows: In the formula, It is the minimum value that SOC can achieve. It is the maximum value that SOC can achieve.

7. The real-time coordinated control method for multiple types of voltage regulating equipment in an active power distribution network according to claim 3, characterized in that, The power factor limits are as follows: In the formula, and These are the power factors of BESS and distributed renewable energy inverters, respectively. It is the sum of BESS reactive power and reactive power deviation. It is the sum of the active power and active power deviation of distributed renewable energy sources. It is the sum of reactive power and reactive power deviation of distributed renewable energy.

8. The real-time coordinated control method for multiple types of voltage regulating equipment in an active power distribution network according to claim 1, characterized in that, In step 3, the early exhaustion problem of BESS is as follows: When dealing with voltage fluctuations at the PCC, the priority is to stabilize the voltage through reactive power compensation. In this process, BESS can provide reactive power to balance the grid demand, thereby mitigating voltage fluctuations. This also indirectly prompts BESS to enter a dormant state, because BESS will only be awakened and put into operation when the required reactive power exceeds the reserve. However, if there are prolonged voltage fluctuations and frequent demands for reactive power from the BESS, this can lead to premature BESS depletion, affecting its availability in potential future emergency situations. To avoid premature BESS depletion, [further measures should be taken]. Modified to and according to Search for the next optimal value and To bring the SOC closer to its reference level ; The SOC adjustment method for BESS is as follows: 1) Charging process While BESS is charging The optimal value obtained in the control loop is negative; by modifying Values ​​to bring SOC closer If the current SOC is greater than its reference SOC value, the charging power will be reduced to prevent the BESS from being depleted prematurely. If the SOC value is less than its reference value, then increase To get closer to its reference value; When SOC equals hour, It approaches zero; the specific formula is as follows: In the formula, For reference SOC; This represents the optimal active power variation for BESS; 2) Discharge process Similarly, the charging process can be understood as follows: In the formula, and current SOC and The distance between them is directly proportional; 3) SOC Adjustment Method Voltage fluctuation events are given priority. If the voltage exceeds the specified range, the SOC adjustment method will not be executed. Instead, the voltage violation event will be treated as a priority, and the system will transfer the required active power to other places to prevent the voltage from continuing to exceed the specified range. The SOC adjustment formula is as follows: In the formula, The active power required for the optimized BESS.

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