A power distribution terminal automation commissioning method and system

Abstract

The application discloses a kind of power distribution terminal automation debugging method and system, it is related to power distribution equipment technical field.When determining that target power distribution terminal occurs voltage sag event, the starting time of event and the voltage drop amplitude value and phase jump value of target terminal during sag are obtained;Synchronization query request containing starting time is sent to other power distribution terminals, and the corresponding data returned by it is received;All terminals are sorted according to voltage drop amplitude from large to small, and if amplitude is the same, then according to phase jump value from large to small, the order number of target terminal is determined;Based on the corresponding table of pre-stored number and protection action delay time, the protection action delay time corresponding to target terminal is obtained by table lookup, and is written into protection setting parameter.The method uses real-time voltage sag characteristics to dynamically allocate protection action delay, without manual calculation, which improves the automation level and adaptability of protection coordination.

Description

Technical Field

[0001] This application relates to the field of power distribution equipment technology, and in particular to an automated commissioning method and system for power distribution terminals. Background Technology

[0002] In the field of distribution network automation, the setting of protection settings parameters for distribution terminals is a key link to ensure that protection devices cooperate correctly and achieve selective isolation in the event of a fault.

[0003] Currently, the mainstream commissioning method involves offline short-circuit current calculation, combined with typical operating modes of the distribution network, to pre-set delay time difference schemes for the protection actions of each terminal, followed by manual parameter writing and commissioning for each terminal. This approach faces numerous challenges in practical applications: the distribution network topology frequently changes due to load transfer, tie switch operation, and the access or withdrawal of distributed power sources, making it difficult for offline calculated setting schemes to track topology changes in real time, which can easily lead to protection coordination failures; common power quality events in distribution networks, such as voltage sags, have propagation characteristics on feeders, and the actual voltage impact on distribution terminals at different installation locations varies, while traditional methods fail to utilize this real-time fault variation for dynamic optimization of protection action timing, still executing according to fixed time differences, resulting in insufficient flexibility; when multiple terminals need to coordinate actions during voltage sag events, how to quickly determine their respective reasonable action delays to avoid cascading tripping currently relies on the experience judgment of commissioning personnel or pre-set static priority lists, lacking automated analysis, sorting, and setting writing methods, resulting in low overall commissioning efficiency and difficulty in guaranteeing coordination accuracy. Summary of the Invention

[0004] This application provides an automated commissioning method and system for power distribution terminals to improve the above-mentioned problems.

[0005] To achieve the above objectives, this application adopts the following technical solution: In a first aspect, embodiments of this application propose an automated commissioning method for a power distribution terminal, applied to an automated commissioning system for a power distribution terminal. The system includes a power distribution terminal and a control terminal. The method is executed by the control terminal and includes: When a voltage sag event is detected at the target distribution terminal, the following steps are taken: First, the start time of the voltage sag event is obtained, along with the voltage drop amplitude and phase jump value of the target distribution terminal during the duration of the voltage sag event. Then, a synchronization query request containing the start time is sent to other distribution terminals with communication connections to the target distribution terminal. Next, the voltage drop amplitude and phase jump value corresponding to the start time are received from the other distribution terminals. Finally, all distribution terminals and the target distribution terminal are sorted according to their corresponding voltage drop amplitudes from largest to smallest. If there are terminals with the same voltage drop amplitude, they are sorted according to their corresponding phase jump values ​​from largest to smallest to determine the target distribution terminal's order number. Based on this order number, the corresponding protection action delay time for the target distribution terminal is determined from a pre-existing table of numbers and protection action delay times stored within the distribution terminals. Finally, the protection setting parameters for the target distribution terminal are written based on the protection action delay time.

[0006] Therefore, based on the real-time voltage drop amplitude and phase jump values ​​measured by multiple distribution terminals during a voltage sag event, the severity of the fault and the electrical distance can be assessed, enabling automatic sequencing of protection actions. By using a pre-stored table mapping numbers to protection action delay times, the appropriate protection action delay time for each terminal can be quickly determined without manual intervention, improving the automation level and coordination accuracy of distribution terminal protection setting debugging.

[0007] In conjunction with the first aspect, optionally, the correspondence table between the number and the protection action delay time is determined as follows: Real-time topology information, line impedance parameters, and load characteristics of each distribution terminal are obtained from the managed distribution network; a distribution network simulation model is constructed based on the real-time topology information and line impedance parameters; voltage dip faults are set up line by line and segment by segment in the distribution network simulation model to determine the theoretical values ​​of voltage drop amplitude and phase jump during the fault for each distribution terminal; based on the theoretical values ​​of voltage drop amplitude and phase jump, the virtual sequence number of each distribution terminal under each fault scenario is determined; based on a preset stepped delay level, a corresponding protection action delay time is assigned to each virtual sequence number, generating an initial correspondence table indexed by the sequence number and with the protection action delay time as the value.

[0008] Therefore, by combining real-time distribution network topology information, line impedance parameters, and load characteristics to construct a simulation model, and by performing traversal calculations on various voltage sag fault scenarios, an initial correspondence table that conforms to the characteristics of the actual power grid can be generated based on theoretical analysis. This approach provides a theoretical basis and a global perspective for the pre-allocation of protection action delay time, offering reliable basic data support for online real-time protection coordination decisions.

[0009] In conjunction with the first aspect, optionally, the determination process for the correspondence table between the numbering and the protection action delay time may also include: The system acquires distribution network topology change events. When a change in the status of a feeder tie switch, the switching of distributed generation sources, or a topology change caused by line maintenance is detected, a revised correspondence table is generated. The revised correspondence table is then distributed via multicast to all distribution terminals within the scope of the topology change for storage.

[0010] Therefore, by monitoring distribution network topology change events, it is possible to promptly detect topology changes caused by feeder tie switch status changes, distributed generation switching, or line maintenance, and regenerate a revised correspondence table. Multicasting this information to all distribution terminals within the affected area enables rapid synchronous updates of the correspondence table, ensuring that protection coordination strategies always match the current actual operation of the power grid and preventing protection action coordination failures due to topology changes.

[0011] In conjunction with the first aspect, optionally, when the target control terminal determines that a voltage sag event exists, the start time of the voltage sag event and the voltage drop amplitude and phase jump value corresponding to the duration of the voltage sag event at the target power distribution terminal are obtained, including: obtaining the effective values ​​of the three-phase voltages; when the effective value of any phase voltage drops below a limited percentage threshold of the rated voltage and the duration of the drop exceeds a preset event confirmation delay, the voltage sag event is determined to have occurred; and a fixed compensation time is retrospectively taken forward from the end time of the confirmation delay as the start time of the voltage sag event.

[0012] Therefore, by using the drop in the effective value of the three-phase voltage to a predetermined threshold and its sustained duration exceeding the confirmation delay as the event confirmation condition, voltage sag event identification can be reliably triggered, avoiding misjudgments caused by instantaneous disturbances. Simultaneously, determining the start time using a forward-backward fixed compensation time method can effectively compensate for the latency effects of the detection algorithm and communication transmission, providing a unified reference time for multi-terminal synchronous data extraction and ensuring the timing accuracy of subsequent sorting and coordination logic.

[0013] In conjunction with the first aspect, optionally, after the target distribution terminal performs a protection action based on the written protection setting parameters, the method further includes: obtaining the action time information recorded by each distribution terminal that participated in the sequencing and actually acted in the voltage sag event; using the time difference between the time represented by the action time information of each actually acting distribution terminal and the start time of the voltage sag event as the actual protection action delay of the distribution terminal; determining the protection action delay time corresponding to the sequence number of the distribution terminal from the correspondence table as the expected action delay; comparing the actual protection action delay with the expected action delay to determine the delay deviation between the two; when the absolute value of the delay deviation exceeds a preset allowable deviation threshold, adjusting the protection action delay time corresponding to the sequence number of the distribution terminal in the correspondence table with a preset step size based on the positive or negative direction of the delay deviation; updating the correspondence table based on the adjusted protection action delay time, and sending the updated correspondence table to each distribution terminal for storage.

[0014] Therefore, after the protection action is executed, by acquiring the actual action time recorded by each participating sequencing terminal and comparing it with the expected action delay, the delay deviation can be obtained as a feedback signal. When the deviation exceeds the limit, the protection action delay time in the corresponding table is automatically adjusted by a preset step size, forming a closed-loop self-optimization mechanism. This method can continuously correct the delay coordination deviation without manual inspection and analysis, so that the protection action coordination accuracy gradually converges to the optimal state during operation, enhancing the system's adaptability and long-term operational reliability.

[0015] In conjunction with the first aspect, optionally, before determining the order number of the target distribution terminal in the sorting, the method further includes: obtaining the three-phase voltage imbalance of other distribution terminals during the duration of the voltage sag event; when at least two distribution terminals have the same voltage drop magnitude and the absolute value of the difference between the phase jump values ​​is less than a preset phase proximity threshold, identifying at least two distribution terminals as a group of terminals to be distinguished; sorting the distribution terminals within each group based on the magnitude of the three-phase voltage imbalance, wherein terminals with larger three-phase voltage imbalance are ranked higher within the group; adjusting the local order of the terminals to be distinguished in the original sorting sequence based on the results of the group sorting; and determining the order number of the target distribution terminal in the sorting, including: determining the order number based on the final sorting sequence after adjusting the local order.

[0016] Therefore, when the voltage drop amplitude is the same and the phase jump values ​​are extremely close, making it difficult to distinguish the order of sorting, the three-phase voltage imbalance is further introduced as an auxiliary distinguishing indicator. Since the three-phase imbalance characteristics are usually more significant near the fault point, sorting within the group according to the magnitude of the imbalance can effectively improve the distinguishability and robustness of the sorting, avoid unreasonable order allocation due to small measurement fluctuations, and make the determined sequence number more accurately reflect the relative position of each terminal and the fault point.

[0017] In conjunction with the first aspect, optionally, the distribution terminals within each to be distinguished terminal are sorted within the group based on the magnitude of the three-phase voltage imbalance, including: if the three-phase voltage imbalance is the same, obtaining the active power fluctuation of each distribution terminal with the same three-phase voltage imbalance during the duration of the voltage sag event; sorting the distribution terminals within the group a second time based on the magnitude of the active power fluctuation, wherein the distribution terminals with larger active power fluctuations are sorted first; and adjusting the local order of the distribution terminals within the group based on the result of the second sorting.

[0018] Therefore, based on the introduction of three-phase voltage imbalance ranking, when the imbalance is still the same, the active power surge is further used as a secondary distinguishing index. Terminals with larger power surges are considered to be closer to the fault source or have experienced more severe impacts, and are ranked higher accordingly. This hierarchical and progressive distinguishing mechanism minimizes sequence conflicts when multiple terminals have similar electrical characteristics, ensuring a clear and reasonable terminal action sequence in all voltage sag scenarios, laying the foundation for accurate allocation of protection delay time.

[0019] A second aspect of this invention provides an automated commissioning system for power distribution terminals, comprising: The acquisition module is used to acquire the start time of the voltage sag event, the voltage drop amplitude value and the phase jump value of the target distribution terminal during the duration of the voltage sag event, when it is determined that there is a voltage sag event in the target distribution terminal. The sending module is used to send a synchronization query request containing the start time to other power distribution terminals that have a communication connection with the target power distribution terminal. The receiving module is used to receive the voltage drop amplitude and phase jump value corresponding to the start time returned by other power distribution terminals; The sorting determination module is used to sort all distribution terminals and target distribution terminals in descending order of their corresponding voltage drop amplitudes. When there are cases where the voltage drop amplitudes are the same, they are sorted in descending order of their corresponding phase jump values ​​to determine the order number of the target distribution terminal in the sorting. The time determination module is used to determine the protection action delay time corresponding to the target power distribution terminal based on the sequence number, from a pre-existing table of correspondence between the number and the protection action delay time in the power distribution terminal. The writing module is used to write protection setting parameters to the target power distribution terminal based on the protection action delay time.

[0020] A third aspect of the present invention provides a processing apparatus, the processing apparatus comprising: At least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores instructions executable by the at least one processor to enable the at least one processor to perform the method proposed in the first aspect of the present invention.

[0021] A fourth aspect of the present invention provides a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the method as described in the first aspect of the present invention. Attached Figure Description

[0022] Figure 1 This is a flowchart illustrating an automated commissioning method for a power distribution terminal proposed in an embodiment of this application.

[0023] Figure 2 This is a schematic diagram of the structure of an automated commissioning system for a power distribution terminal proposed in an embodiment of this application.

[0024] Figure 3 This is a schematic diagram of the structure of a processing device proposed in an embodiment of this application. Detailed Implementation

[0025] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some, not all, of the embodiments of the present invention. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0026] This invention provides an automated commissioning method for power distribution terminals, applied to an automated commissioning system for power distribution terminals. The system includes multiple power distribution terminals and at least one control terminal. The control terminal can communicate with the multiple power distribution terminals to coordinate and complete commissioning tasks. In this embodiment, the method is executed by the control terminal, such as... Figure 1 As shown, the main steps include: S101: When it is determined that there is a voltage sag event at the target power distribution terminal, obtain the start time of the voltage sag event and the voltage drop amplitude and phase jump value of the target power distribution terminal during the duration of the voltage sag event.

[0027] Specifically, the control terminal continuously monitors the operating status of the distribution terminals under its jurisdiction. When a voltage sag event is detected at a distribution terminal (i.e., the target distribution terminal), the start time of the event is recorded, and the voltage drop amplitude and phase jump value of the target distribution terminal during the duration of the voltage sag are collected. The voltage drop amplitude represents the degree to which the effective voltage value deviates from the rated value, while the phase jump value reflects the abrupt change angle of the voltage phase before and after the event. These two parameters can objectively measure the severity and electrical characteristics of the voltage sag experienced at the terminal. For example, if a terminal experiences a voltage drop of 70% of the rated voltage and a phase jump value of -15 degrees during an event, it indicates a significant voltage drop with a delayed phase jump.

[0028] S102: Send a synchronization query request containing the start time to other power distribution terminals that have a communication connection with the target power distribution terminal.

[0029] Understandably, to coordinate the protection actions of multiple distribution terminals, the control terminal uses the communication network to send synchronization query requests to other distribution terminals that have communication connections with the target distribution terminal. This request explicitly carries the start time of the voltage sag event. The purpose is to provide a unified time reference for all queried terminals, ensuring that the voltage drop amplitude and phase transition values ​​extracted by each terminal correspond to the same fault transient period, avoiding data incomparability due to time asynchrony. For example, if the clocks of terminal A and terminal B deviate by 5 milliseconds, it will cause a significant difference in the calculation of the voltage drop amplitude for the same event; unifying the start time can eliminate this effect.

[0030] S103: Receive the voltage drop amplitude and phase jump value corresponding to the start time from other power distribution terminals.

[0031] Upon receiving a synchronization query request, other distribution terminals extract the voltage sag and phase transition values ​​from their own waveform recordings or measurement buffers based on the start time specified in the request, and return this data to the control terminal. The control terminal receives all returned data, thereby obtaining distributed electrical measurement information for the entire group of related distribution terminals during the same voltage sag event. For example, the control terminal receives returned data from five distribution terminals, including voltage sags of 80%, 70%, and 60%, as well as the corresponding phase transition values.

[0032] Specifically, step S103 may include the following steps: S1031: Obtain the effective value of the three-phase voltage. When the effective value of any phase voltage drops below the specified percentage threshold of the rated voltage and the duration of the drop exceeds the preset event confirmation delay, determine that a voltage sag event has occurred.

[0033] Understandably, when the effective value of any phase voltage drops below the rated voltage multiplied by a predetermined percentage threshold, it is not immediately determined to be a voltage sag event. Instead, a timer is started to observe the duration of this low voltage state. Only when this duration exceeds a pre-set event confirmation delay is a voltage sag event officially recognized. By judging both the magnitude and duration of the effective value drop, transient voltage disturbances can be effectively filtered out, false alarms can be avoided, and the reliability of voltage sag detection can be improved. For example, if the predetermined percentage threshold is set to 90% of the rated voltage and the event confirmation delay is set to 10 milliseconds, an event is determined to have occurred when the phase voltage drops to 85% and lasts for 15 milliseconds, while a 5-millisecond transient drop is ignored.

[0034] S1032: The fixed compensation time backward from the confirmation delay end time is used as the start time of the voltage sag event.

[0035] After confirming a voltage sag event, directly using the end of the confirmation period as the start of the event would introduce a deviation due to time lags in detection algorithm processing and communication transmission, hindering time synchronization among multiple terminals. To address this issue, this step, after event confirmation, backtracks by a pre-calibrated fixed compensation time from the end of the confirmation delay, using this backtracked time as the start of the voltage sag event. This compensation mechanism more accurately approximates the actual fault initiation moment, providing a unified, high-precision reference time for all participating distribution terminals, ensuring that the voltage drop amplitude and phase transition values ​​extracted by each terminal strictly correspond to the same event period. For example, if the fixed compensation time is calibrated to 8 milliseconds, and the end of the confirmation delay is T1, then the start time is backtracked to T1-8 milliseconds.

[0036] S104: Sort all distribution terminals and target distribution terminals in descending order of their corresponding voltage drop amplitudes. If there are cases where the voltage drop amplitudes are the same, sort them in descending order of their corresponding phase jump values ​​to determine the order number of the target distribution terminal in the sorting.

[0037] Specifically, the control terminal arranges the target distribution terminal and all other distribution terminals returning data according to a preset sorting rule. During sorting, the voltage drop amplitude of each terminal is first compared. A larger amplitude indicates a more severe impact from the voltage sag or a closer electrical distance to the fault point, resulting in a higher sorting position. When voltage drop amplitudes are the same, the phase transition values ​​are further compared, with terminals having larger phase transition values ​​placed at a relatively higher position. Based on this sorting result, the order number of the target distribution terminal in the entire sequence is determined. The order number directly reflects the relative action priority of the terminal in this voltage sag event. For example, terminal A has a voltage drop amplitude of 85% and a phase transition of -20 degrees; terminal B has a voltage drop amplitude of 80% and a phase transition of -25 degrees; terminal C has a voltage drop amplitude of 85% and a phase transition of -15 degrees. The sorting result is A, C, B, with A having an order number of 1, indicating the highest priority.

[0038] Optionally, as one implementation, before determining the order number of the target distribution terminal in the sorting, the following steps may also be included: S301: Obtain the three-phase voltage imbalance of other distribution terminals during the duration of a voltage sag event.

[0039] Before executing the main sorting rules, the control terminal additionally obtains three-phase voltage imbalance data from other distribution terminals during the voltage sag event. The three-phase voltage imbalance can be calculated by the ratio of negative-sequence voltage to positive-sequence voltage, which reflects the degree of asymmetry of the three-phase voltage during the fault. Typically, distribution terminals near the fault point will exhibit a greater three-phase voltage imbalance.

[0040] S302: When at least two distribution terminals have the same voltage drop amplitude and the absolute value of the difference between the phase jump values ​​is less than the preset phase proximity threshold, the at least two distribution terminals are identified as a group of terminals to be distinguished.

[0041] In the main sorting rules, when multiple terminals have the same voltage drop magnitude and the absolute value of the difference between their corresponding phase transition values ​​is less than a preset phase proximity threshold, it indicates that these terminals have highly similar voltage characteristics, and the main sorting index cannot reliably distinguish their priority order. In this case, these distribution terminals with similar electrical characteristics are grouped together and marked as terminals to be distinguished. For example, if the preset phase proximity threshold is 2 degrees, and terminals D and E both have a voltage drop magnitude of 75%, and phase transitions of -12 degrees and -11 degrees respectively, and the difference between them is 1 degree, which is less than 2 degrees, then D and E are grouped together as terminals to be distinguished.

[0042] S303: Sort the distribution terminals within each group according to the magnitude of the three-phase voltage imbalance. Terminals with larger three-phase voltage imbalance are ranked higher in the group.

[0043] For each group of terminals to be distinguished, the primary ranking index is no longer relied upon. Instead, a local ranking is based on the magnitude of the three-phase voltage imbalance of each distribution terminal within the group. A terminal with a larger three-phase voltage imbalance value indicates a more severe voltage asymmetry, typically meaning it is closer to the fault point and should have a higher priority for protection actions. Therefore, it is placed earlier in the group ranking. For example, if terminal D has a three-phase voltage imbalance of 8% and terminal E has 5%, then D is ranked higher than E.

[0044] Optionally, if the three-phase voltage imbalance is the same, the active power fluctuation of each distribution terminal with the same three-phase voltage imbalance during the voltage sag event is obtained. Then, based on the magnitude of the active power fluctuation, the distribution terminals are sorted in the secondary group, with those having larger active power fluctuations sorted first. Finally, based on the results of the secondary group sorting, the local order of the distribution terminals in the group is adjusted.

[0045] When using three-phase voltage imbalance to sort terminals within a group, multiple terminals may still have the same three-phase voltage imbalance value. In this case, relying solely on the first two indicators is insufficient to reliably distinguish their priority order. To further eliminate ambiguity, we can start by analyzing the active power data of these distribution terminals during the voltage sag event, obtaining the active power fluctuation of each terminal—the difference between the active power during the fault and the steady-state active power before the fault. The magnitude of the active power fluctuation reflects the severity of the impact of the fault on the load or connected branch of the terminal. Generally, terminals with larger active power fluctuations are more electrically coupled to the fault point or closer to the fault point and should be given higher action priority. Therefore, for distribution terminals with the same three-phase voltage imbalance, a second sorting within the group is performed based on the active power fluctuation from largest to smallest, with terminals with larger fluctuations placed earlier. Based on the results of this second sorting within the group, the local order of these terminals within the original group is finally adjusted to obtain a clear and conflict-free sorting result. For example, if the three-phase voltage imbalance of terminals F and G is 6%, but the active power fluctuation of F is 50kW and that of G is 30kW, then F is ranked before G.

[0046] Further, the order number of the target distribution terminal in the sorting is determined, including: S1041: Determine the sequence number based on the final sorted sequence after adjusting the local order.

[0047] Understandably, after the intra-group sorting of the terminals to be distinguished is completed, the local sorting result replaces the parallel or slightly differentiable positions of these terminals in the original main sorting sequence, forming the final sorting sequence after adjusting the local order. At this point, the relative position of the target distribution terminal in the entire sequence is determined, and the issue of order ambiguity no longer exists. Based on this final sorting sequence, a clear sequence number is assigned to the target distribution terminal to ensure that the protection action delay time obtained from subsequent table lookups is unique and reasonable. For example, after adjustment, the final sequence number of the target distribution terminal is determined to be 3, indicating the third priority action among all terminals.

[0048] S105: Based on the sequence number, determine the protection action delay time corresponding to the target power distribution terminal from the pre-existing correspondence table of numbers and protection action delay times in the power distribution terminal.

[0049] Understandably, each distribution terminal pre-stores a mapping table between its serial number and the protection action delay time. This table, indexed by its sequence number, stores the protection action delay time corresponding to each sequence. The control terminal uses the sequence number of the target distribution terminal obtained in the previous step to look up the appropriate protection action delay time in this mapping table. This delay time represents the time that should be waited between fault confirmation and the issuance of a protection trip command, and is a key parameter for achieving selective protection.

[0050] Optionally, the correspondence between the number and the protection action delay time is determined as follows: S201: Obtain real-time topology information, line impedance parameters, and load characteristics of each distribution terminal of the managed distribution network.

[0051] Understandably, to generate a mapping table that accurately reflects the actual characteristics of the distribution network, it is first necessary to obtain real-time topology information of the managed distribution network, including feeder connection methods and switch status; obtain impedance parameters of each line segment, such as positive-sequence, negative-sequence, and zero-sequence impedance; and obtain load characteristics at the location of each distribution terminal, such as load power and type. For example, the obtained topology information shows that the current operation is a single-ring network with a line impedance of 0.2 + j0.4 Ω / km, and the terminal loads are mostly mixed residential loads.

[0052] S202: Construct a power distribution network simulation model based on real-time topology information and line impedance parameters.

[0053] Specifically, by utilizing the acquired real-time topology information and line impedance parameters, a distribution network simulation model that closely matches the actual distribution network is constructed. This model can simulate various operating modes and fault conditions in a computer. For example, based on the actual topology of a city's distribution network, a simulation model containing 50 nodes and 20 distribution terminals was built in MATLAB / Simulink.

[0054] S203: In the distribution network simulation model, voltage dip faults are set up one by one for each feeder and segment to determine the theoretical values ​​of voltage drop amplitude and phase jump during the fault period for each distribution terminal.

[0055] In the constructed distribution network simulation model, voltage dip faults are set up line by line and segment by segment to cover various possible fault locations and types. For each type of fault, the theoretical values ​​of voltage drop and phase transition experienced by each distribution terminal during the fault are determined through simulation calculations. These two theoretical values ​​reflect the severity and electrical characteristics of each terminal under ideal conditions. For example, if a three-phase short-circuit fault is set at 50% of feeder 1, the theoretical voltage drop of terminal X is calculated to be 40%, and the theoretical phase transition is -30 degrees.

[0056] S204: Based on the theoretical values ​​of voltage drop amplitude and phase jump, determine the virtual sequence number of each distribution terminal under each fault scenario.

[0057] Based on the theoretical values ​​of voltage drop and phase jump obtained from simulation, all distribution terminals participating in the ranking under each fault scenario are ranked according to the rule of first comparing the voltage drop and then comparing the phase jump values, thus determining the virtual order number of each terminal in that fault scenario. The virtual order number represents the priority order of the protection action of that terminal relative to other terminals under that specific fault condition. For example, in the above feeder 1 fault scenario, terminal X is ranked first due to a voltage drop of 40%, and terminal Y is ranked second due to a voltage drop of 45%, corresponding to virtual order numbers 1 and 2 respectively.

[0058] S205: Based on the preset stepped delay level difference, assign a corresponding protection action delay time to each virtual sequence number, and generate an initial correspondence table with the sequence number as the index and the protection action delay time as the value.

[0059] A tiered delay level is pre-defined, representing the difference in action delay time between adjacent priorities. For each virtual sequence number, the corresponding protection action delay time is assigned sequentially, generally with smaller numbers having shorter delays. This generates an initial mapping table indexed by sequence number and containing protection action delay times. For example, if the preset tiered delay level is 200 milliseconds, sequence number 1 corresponds to 100 milliseconds, number 2 to 300 milliseconds, number 3 to 500 milliseconds, and so on.

[0060] S206: Acquire distribution network topology change events. When a change in the status of a feeder tie switch, the switching of distributed generation, or a topology change caused by line maintenance is detected, a revised corresponding table is generated.

[0061] Distribution networks undergo topology changes during actual operation, such as feeder tie switch switching, distributed generation connection or disconnection, and line maintenance. Control terminals can detect these topology change events to understand the alterations in the power grid structure. Once a topology change due to the aforementioned reasons is detected, the control terminal re-executes simulation calculations and sorting / allocation steps based on the new topology to generate a revised correspondence table that matches the current actual operation of the power grid. This ensures that the correspondence table reflects the latest power grid fault characteristics and protection coordination relationships. For example, if a tie switch changes from normally open to normally closed, the distribution network changes from a radial to a ring structure, altering the fault current path, requiring a re-simulation to generate a revised table.

[0062] S207: And the revised correspondence table will be distributed via multicast to all power distribution terminals within the scope affected by the topology change for storage.

[0063] After generating the revised mapping table, the control terminal uses multicast to distribute the table to all distribution terminals within the affected area of ​​the topology change. Multicast communication can efficiently transmit data to a group of target terminals simultaneously, avoiding the communication overhead of point-to-point transmission. Each relevant distribution terminal receives the revised mapping table and saves it in its local storage for future reference when voltage sag events occur. This ensures that the reference for protection action delay time is updated synchronously with the grid topology change, maintaining the accuracy and real-time performance of protection coordination. For example, using multicast to distribute the revised table to 15 distribution terminals within the affected area of ​​the tie switch takes less time than point-to-point transmission.

[0064] S106: Write the protection setting parameters to the target power distribution terminal based on the protection action delay time.

[0065] Specifically, the control terminal uses the protection action delay time obtained from the lookup table as a new protection setting parameter and writes it into the protection logic unit of the target distribution terminal via a remote communication link. After writing, the target distribution terminal will execute the corresponding protection output operation according to the newly set delay time in the current and subsequent protection actions, thereby automatically achieving timing coordination with other distribution terminals in the system and improving the selectivity and reliability of protection actions. For example, writing the 500-millisecond delay corresponding to sequence number 3 into terminal Z, terminal Z will wait 500 milliseconds after detecting a fault before issuing a trip command, avoiding conflicts with the actions of terminals numbered 1 and 2.

[0066] Optionally, after writing the protection setting parameters, in order to continuously optimize the matching accuracy of the protection action delay time, reduce the deviation between the actual protection action behavior and the expected behavior, and improve the protection selectivity and speed, the following steps may also be included: S107: Obtain the action time information recorded by each distribution terminal that participated in the sorting and actually took action in the voltage sag event.

[0067] Understandably, after a voltage sag event is handled, the precise timestamps of all distribution terminals in the sequence that actually issued protection action commands are collected. For example, terminal A's action time is 320 milliseconds after the event started, terminal B's action time is 520 milliseconds, and terminal C's action time is 710 milliseconds.

[0068] S108: The time difference between the time represented by the action time information of each actual action distribution terminal and the start time of the voltage sag event is used as the actual protection action delay of the distribution terminal.

[0069] Specifically, for each terminal that actually performs an action, the recorded action time is subtracted from the fault start time to obtain the actual protection action delay experienced by that terminal in this event. This delay value includes the terminal's own hardware and software response time, the circuit breaker's action time, and the waiting time introduced by the sequencing and coordination, thus accurately reflecting the execution of protection coordination. For example, the actual protection action delay for terminal A is 320 milliseconds, while for terminal B it is 520 milliseconds.

[0070] S109: Determine the protection action delay time corresponding to the sequence number of the power distribution terminal from the corresponding table, and use it as the expected action delay.

[0071] Understandably, based on the sorting sequence number determined by the terminal in step S104, a pre-stored corresponding table is consulted to extract the expected protection action delay time allocated for this sequence during the debugging phase. This expected delay is theoretically considered an ideal value that enables selective coordination. For example, if the sequence number of terminal A is 1, the expected action delay in the corresponding table is 300 milliseconds; if the sequence number of terminal B is 2, the expected action delay is 500 milliseconds.

[0072] S110: Compare the actual protection action delay with the expected action delay to determine the amount of delay deviation between the two.

[0073] Subtracting the actual delay obtained in S108 from the expected delay obtained in S109 yields the delay deviation. A positive deviation indicates that the actual action is slower than expected; a negative deviation indicates that the actual action is faster than expected. This deviation directly reflects the difference between the current correspondence table setting and the actual power grid response. For example, the deviation for terminal A is +20 milliseconds (320-300), and the deviation for terminal B is +20 milliseconds (520-500), both slightly slower than expected.

[0074] S111: When the absolute value of the delay deviation exceeds the preset allowable deviation threshold, the protection action delay time corresponding to the sequence number of the power distribution terminal in the corresponding table is adjusted by a preset step size based on the positive or negative direction of the delay deviation.

[0075] Specifically, a tolerable deviation threshold can be set, such as 20% of the grade difference. Once the absolute value of the deviation exceeds this threshold, it is determined that there is a significant misalignment in the coordination and correction is required. Depending on the direction of the deviation, if the actual delay is too large, the delay value of the corresponding sequence number in the table is appropriately reduced; if it is too small, it is appropriately increased. The adjustment range is a predefined fixed step size to avoid over-correction causing oscillations. For example, the allowable deviation threshold is set to 40 milliseconds, and the fixed step size is set to 20 milliseconds. If the deviation of terminal A in a certain event is +20 milliseconds, which does not exceed the threshold, no adjustment is made; if the deviation in another event is +50 milliseconds, which exceeds the threshold, then the delay time of terminal A in the corresponding table is reduced by 20 milliseconds from 300 milliseconds to 280 milliseconds.

[0076] S112: Update the correspondence table based on the adjusted protection action delay time, and send the updated correspondence table to each power distribution terminal for storage.

[0077] The adjusted delay times are written to the corresponding positions in the mapping table, forming an updated mapping table. The complete updated mapping table is then distributed to all distribution terminals via the communication network for storage, overwriting the old table. In this way, during subsequent voltage sag events, the allocation of protection action delays will be based on the corrected parameters, forming a closed-loop self-learning mechanism that approaches the optimal coordination scheme. For example, after multiple event adjustments, the delay times in the mapping table gradually converge, and the deviation between the actual action delay and the expected action delay stabilizes within the allowable threshold, resulting in more precise protection coordination.

[0078] The automated commissioning method and system for distribution terminals proposed in this invention fully utilize the electrical quantity characteristics measured by multiple terminals during voltage sag events. By real-time sorting and pre-stored correspondence tables, it dynamically generates protection action delay times and supports closed-loop self-optimization, significantly improving the automation level and coordination accuracy of distribution terminal protection setting commissioning, and has high practical value.

[0079] Based on the same inventive concept, embodiments of this application also propose an automated commissioning system for power distribution terminals. Please refer to [link to relevant documentation]. Figure 2 ,include: The acquisition module is used to acquire the start time of the voltage sag event, the voltage drop amplitude value and the phase jump value of the target distribution terminal during the duration of the voltage sag event, when it is determined that there is a voltage sag event in the target distribution terminal. The sending module is used to send a synchronization query request containing the start time to other power distribution terminals that have a communication connection with the target power distribution terminal. The receiving module is used to receive the voltage drop amplitude and phase jump value corresponding to the start time returned by other power distribution terminals; The sorting determination module is used to sort all distribution terminals and target distribution terminals in descending order of their corresponding voltage drop amplitudes. When there are cases where the voltage drop amplitudes are the same, they are sorted in descending order of their corresponding phase jump values ​​to determine the order number of the target distribution terminal in the sorting. The time determination module is used to determine the protection action delay time corresponding to the target power distribution terminal based on the sequence number, from a pre-existing table of correspondence between the number and the protection action delay time in the power distribution terminal. The writing module is used to write protection setting parameters to the target power distribution terminal based on the protection action delay time.

[0080] Based on the same inventive concept, embodiments of this application also propose a processing apparatus, which includes: At least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores instructions executable by the at least one processor, the instructions being executed by the at least one processor to enable the at least one processor to perform the power distribution terminal automated commissioning method of the embodiments of this application.

[0081] In addition, to achieve the above objectives, embodiments of this application also propose a computer-readable storage medium storing a computer program, which, when executed by a processor, implements the power distribution terminal automated debugging method of embodiments of this application.

[0082] The following is a detailed introduction to each component of the processing equipment: The processor is the control center of the processing device. It can be a single processor or a collective term for multiple processing elements. For example, a processor can be one or more central processing units (CPUs), an application-specific integrated circuit (ASIC), or one or more integrated circuits configured to implement embodiments of the present invention, such as one or more digital signal processors (DSPs), or one or more field-programmable gate arrays (FPGAs).

[0083] Alternatively, the processor can perform various functions of the processing device by running or executing software programs stored in memory and by calling data stored in memory.

[0084] The memory is used to store the software program that executes the solution of the present invention, and the execution is controlled by the processor. The specific implementation method can be referred to the above method embodiment, which will not be repeated here.

[0085] Optionally, the memory can be read-only memory (ROM) or other types of static storage devices capable of storing static information and instructions, random access memory (RAM) or other types of dynamic storage devices capable of storing information and instructions, or electrically erasable programmable read-only memory (EEPROM), compact disc read-only memory (CD-ROM) or other optical disc storage, optical disc storage (including compressed optical discs, laser discs, optical discs, digital universal optical discs, Blu-ray discs, etc.), magnetic disk storage media or other magnetic storage devices, or any other medium capable of carrying or storing desired program code in the form of instructions or data structures and accessible by a computer, but not limited thereto. The memory can be integrated with the processor or exist independently and coupled to the processor through the interface circuit of the processing device; the embodiments of the present invention do not specifically limit this.

[0086] A transceiver is used to communicate with network devices or with terminal devices.

[0087] Optionally, the transceiver may include a receiver and a transmitter. The receiver is used to implement the receiving function, and the transmitter is used to implement the sending function.

[0088] Optionally, the transceiver can be integrated with the processor or exist independently and coupled to the processor through the router's interface circuit. This embodiment of the invention does not specifically limit this.

[0089] Figure 3 This is a schematic diagram of the structure of a processing device provided in an embodiment of the present invention. Exemplarily, this processing device may be a network device, or a chip (system) or other component or assembly that can be disposed in a network device. Figure 3 As shown, the processing device 300 may include a processor 301. Optionally, the processing device 300 may also include a memory 302 and / or a transceiver 303. The processor 301 is coupled to the memory 302 and the transceiver 303, for example, via a communication bus.

[0090] The following is combined with Figure 3 A detailed description of each component of the processing equipment 300 is provided below: The processor 301 is the control center of the processing device 300. It can be a single processor or a collective term for multiple processing elements. For example, the processor 301 can be one or more central processing units (CPUs), application-specific integrated circuits (ASICs), or one or more integrated circuits configured to implement embodiments of the present invention, such as one or more digital signal processors (DSPs), or one or more field-programmable gate arrays (FPGAs).

[0091] Alternatively, the processor 301 can perform various functions of the processing device 300 by running or executing software programs stored in the memory 302 and by calling data stored in the memory 302.

[0092] In a specific implementation, as one example, processor 301 may include one or more CPUs, for example... Figure 3 CPU0 and CPU1 are shown in the diagram.

[0093] In a specific implementation, as one embodiment, the processing device 300 may also include multiple processors. Each of these processors may be a single-core processor (single-CPU) or a multi-core processor (multi-CPU). Here, a processor may refer to one or more devices, circuits, and / or processing cores used for processing data (e.g., computer program instructions).

[0094] The memory 302 is used to store the software program that executes the solution of the present invention, and the processor 301 controls the execution. The specific implementation method can be referred to the above method embodiment, and will not be repeated here.

[0095] Optionally, the memory 302 may be a read-only memory (ROM) or other type of static storage device capable of storing static information and instructions, random access memory (RAM) or other type of dynamic storage device capable of storing information and instructions, or electrically erasable programmable read-only memory (EEPROM), compact disc read-only memory (CD-ROM) or other optical disc storage, optical disc storage (including compressed optical discs, laser discs, optical discs, digital universal optical discs, Blu-ray discs, etc.), magnetic disk storage media or other magnetic storage devices, or any other medium capable of carrying or storing desired program code in the form of instructions or data structures and accessible by a computer, but not limited thereto. The memory 302 may be integrated with the processor 301 or exist independently, and may be connected via the interface circuit of the processing device 300. Figure 3 (Not shown in the image) is coupled to processor 301, and this embodiment of the invention does not specifically limit this.

[0096] Transceiver 303 is used for communication with other processing devices. For example, if processing device 300 is a terminal, transceiver 303 can be used to communicate with a network device or with another terminal device. As another example, if processing device 300 is a network device, transceiver 303 can be used to communicate with a terminal or with another network device.

[0097] Alternatively, transceiver 303 may include a receiver and a transmitter. Figure 3 (Not shown separately). The receiver is used to implement the receiving function, and the transmitter is used to implement the transmitting function.

[0098] Optionally, the transceiver 303 can be integrated with the processor 301, or it can exist independently and be connected via the interface circuit of the processing device 300. Figure 3 (Not shown in the image) is coupled to processor 301, and this embodiment of the invention does not specifically limit this.

[0099] Understandable, Figure 3 The structure of the processing device 300 shown does not constitute a limitation on the processing device. The actual processing device may include more or fewer components than shown, or combine certain components, or have different component arrangements.

[0100] Furthermore, the technical effects of the processing device 300 can be referred to the technical effects of the methods in the above-described method embodiments, and will not be repeated here.

[0101] It should be understood that the processor in the embodiments of the present invention can be a central processing unit (CPU), or it can be other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. The general-purpose processor can be a microprocessor or any conventional processor.

[0102] It should also be understood that the memory in the embodiments of the present invention can be volatile memory or non-volatile memory, or may include both volatile and non-volatile memory. The non-volatile memory can be read-only memory (ROM), programmable read-only memory (PROM), erasable programmable read-only memory (EPROM), electrically erasable programmable read-only memory (EEPROM), or flash memory. The volatile memory can be random access memory (RAM), which is used as an external cache. By way of example, but not limitation, many forms of random access memory (RAM) are available, such as static random access memory (SRAM), dynamic random access memory (DRAM), synchronous dynamic random access memory (SDRAM), double data rate synchronous dynamic random access memory (DDRSDRAM), enhanced synchronous dynamic random access memory (ESDRAM), synchronous linked dynamic random access memory (SLDRAM), and direct rambus RAM (DRRAM). The above embodiments can be implemented, in whole or in part, by software, hardware (such as circuitry), firmware, or any other combination thereof. When implemented in software, the above embodiments can be implemented, in whole or in part, as a computer program product. A computer program product includes one or more computer instructions or computer programs. When the computer instructions or computer programs are loaded or executed on a computer, all or part of the flow or function according to embodiments of the present invention is produced. The computer can be a general-purpose computer, a special-purpose computer, a computer network, or other programmable device. Computer instructions can be stored in a computer-readable storage medium or transmitted from one computer-readable storage medium to another. For example, computer instructions can be transmitted from one website, computer, server, or data center to another via wired (e.g., infrared, wireless, microwave, etc.) means. A computer-readable storage medium can be any available medium that a computer can access, or a data storage device such as a server or data center that includes one or more sets of available media. Available media can be magnetic media (e.g., floppy disks, hard disks, magnetic tapes), optical media (e.g., DVDs), or semiconductor media. Semiconductor media can be solid-state drives (SSDs).

[0103] It should be understood that the term "and / or" in this article is merely a description of the relationship between related objects, indicating that three relationships can exist. For example, A and / or B can represent: A existing alone, A and B existing simultaneously, or B existing alone. A and B can be singular or plural. Additionally, the character " / " in this article generally indicates an "or" relationship between the preceding and following related objects, but it can also represent an "and / or" relationship. Please refer to the context for a more accurate understanding.

[0104] In this invention, "at least one" refers to one or more items, and "more than one" refers to two or more items. "At least one of the following" or similar expressions refer to any combination of these items, including any combination of a single item or a plurality of items. For example, at least one of a, b, or c can represent: a, b, c, ab, ac, bc, or abc, where a, b, and c can be single or multiple. It should be understood that in various embodiments of this invention, the sequence number of the above processes does not imply the order of execution. The execution order of each process should be determined by its function and internal logic, and should not constitute any limitation on the implementation process of the embodiments of this invention.

[0105] Those skilled in the art will recognize that the units and algorithm steps of the various examples described in conjunction with the embodiments disclosed herein can be implemented in electronic hardware, or a combination of computer software and electronic hardware. Whether these functions are implemented in hardware or software depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementations should not be considered beyond the scope of this invention.

Claims

1. A method for automated commissioning of a power distribution terminal, characterized in that, An automated commissioning system for a power distribution terminal is applied, the system including a power distribution terminal and a control terminal, the method being executed by the control terminal, including: When it is determined that a voltage sag event exists at the target distribution terminal, the start time of the voltage sag event and the voltage drop amplitude and phase jump value of the target distribution terminal during the duration of the voltage sag event are obtained. Send a synchronization query request containing the start time to other power distribution terminals that have a communication connection with the target power distribution terminal; Receive the voltage drop amplitude and phase jump value corresponding to the start time from other power distribution terminals; All the power distribution terminals and the target power distribution terminal are sorted from largest to smallest according to the corresponding voltage drop amplitude. When there are cases where the voltage drop amplitudes are the same, they are sorted from largest to smallest according to the corresponding phase jump values ​​to determine the order number of the target power distribution terminal in the sorting. Based on the sequence number, the protection action delay time corresponding to the target power distribution terminal is determined from the pre-existing correspondence table of number and protection action delay time in the power distribution terminal. Based on the protection action delay time, the protection setting parameters are written to the target power distribution terminal.

2. The automated commissioning method for a power distribution terminal according to claim 1, characterized in that, The correspondence between the number and the protection action delay time is determined in the following manner: Obtain real-time topology information, line impedance parameters, and load characteristics of each distribution terminal of the managed distribution network; A power distribution network simulation model is constructed based on the real-time topology information and line impedance parameters. In the power distribution network simulation model, voltage dip faults are set up for each feeder and each segment to determine the theoretical values ​​of voltage drop amplitude and phase jump during the fault for each distribution terminal. Based on the theoretical values ​​of the voltage drop amplitude and the phase jump, the virtual sequence number of each distribution terminal under each fault scenario is determined. Based on the preset tiered delay levels, a corresponding protection action delay time is assigned to each of the virtual sequence numbers, generating an initial correspondence table with the sequence number as the index and the protection action delay time as the value.

3. The automated commissioning method for a power distribution terminal according to claim 2, characterized in that, The process of determining the correspondence between the number and the protection action delay time also includes: The system acquires distribution network topology change events and generates a revised corresponding table when a change in the status of a feeder tie switch, the switching of distributed generation sources, or a topology change caused by line maintenance is detected. The revised correspondence table will be distributed via multicast to all power distribution terminals within the affected area of ​​the topology change for storage.

4. The automated commissioning method for a power distribution terminal according to claim 1, characterized in that, When the target control terminal determines that a voltage sag event exists, it acquires the start time of the voltage sag event and the voltage drop amplitude and phase jump value of the target power distribution terminal during the duration of the voltage sag event, including: The effective value of the three-phase voltage is obtained. When the effective value of any phase voltage drops below the specified percentage threshold of the rated voltage and the duration of the drop exceeds the preset event confirmation delay, a voltage sag event is determined to have occurred. The fixed compensation time preceding the confirmed end time of the delay is taken as the start time of the voltage sag event.

5. The automated commissioning method for a power distribution terminal according to claim 1, characterized in that, After the target power distribution terminal performs a protection action based on the written protection setting parameters, the process further includes: Obtain the action time information recorded by each of the power distribution terminals that participated in the sorting and actually took action in the voltage sag event; The time difference between the time represented by the action time information of each actual action of the power distribution terminal and the start time of the voltage sag event is used as the actual protection action delay of the power distribution terminal. The protection action delay time corresponding to the sequence number of the power distribution terminal is determined from the correspondence table and used as the expected action delay; The actual protection action delay is compared with the expected action delay to determine the delay deviation between the two. When the absolute value of the delay deviation exceeds the preset allowable deviation threshold, the protection action delay time corresponding to the sequence number of the power distribution terminal in the corresponding table is adjusted by a preset step size based on the positive or negative direction of the delay deviation. The corresponding table is updated based on the adjusted protection action delay time, and the updated corresponding table is sent to each of the power distribution terminals for storage.

6. The automated commissioning method for a power distribution terminal according to claim 1, characterized in that, Before determining the order number of the target power distribution terminal in the sorting, the method further includes: Obtain the three-phase voltage imbalance of the other distribution terminals during the duration of the voltage sag event; When at least two of the power distribution terminals have the same voltage drop magnitude and the absolute value of the difference between the phase jump values ​​is less than a preset phase proximity threshold, at least two of the power distribution terminals are identified as a group of terminals to be distinguished. The three-phase voltage imbalance of each distribution terminal within the terminal to be distinguished is used to sort the terminals within the group, wherein the terminals with larger three-phase voltage imbalance are ranked higher within the group. Based on the results of the intra-group sorting, the local order of the terminals to be distinguished in the original sorting sequence is adjusted. Determining the order number of the target power distribution terminal in the sorting includes: The order number is determined based on the final sorted sequence after adjusting the local order.

7. The automated commissioning method for a power distribution terminal according to claim 6, characterized in that, The group is sorted based on the magnitude of the three-phase voltage imbalance of the distribution terminals within each of the terminals to be distinguished, including: If the three-phase voltage imbalance is the same, then obtain the active power fluctuation of each distribution terminal with the same three-phase voltage imbalance in the terminal to be distinguished during the duration of the voltage sag event. Based on the magnitude of the active power fluctuation, the secondary groups of the distribution terminals are sorted, with those having larger active power fluctuations ranked first. Based on the results of the secondary group sorting, the local order of the power distribution terminal within the group is adjusted.

8. An automated commissioning system for power distribution terminals, characterized in that, include: The acquisition module is used to acquire the start time of the voltage sag event, the voltage drop amplitude value and the phase jump value of the target distribution terminal during the duration of the voltage sag event when it is determined that there is a voltage sag event in the target distribution terminal. A sending module, the sending module being used to send a synchronization query request containing the start time to other power distribution terminals that have a communication connection with the target power distribution terminal; The receiving module is used to receive the voltage drop amplitude and phase jump value corresponding to the start time returned by other power distribution terminals; The sorting determination module is used to sort all the power distribution terminals and the target power distribution terminal in descending order according to the corresponding voltage drop amplitude. When there are cases where the voltage drop amplitudes are the same, they are sorted in descending order according to the corresponding phase jump value to determine the order number of the target power distribution terminal in the sorting. A time determination module is used to determine the protection action delay time corresponding to the target power distribution terminal based on the sequence number, from a pre-existing correspondence table of numbers and protection action delay times in the power distribution terminal. The writing module is used to write protection setting parameters to the target power distribution terminal based on the protection action delay time.

9. A processing device, characterized in that, include: At least one processor; And, a memory communicatively connected to at least one of the processors; The memory stores instructions that can be executed by at least one of the processors, which are executed by at least one of the processors to enable at least one of the processors to perform an automated commissioning method for a power distribution terminal as described in any one of claims 1-7.

10. A computer-readable storage medium, characterized in that, It stores a computer program that, when executed by a processor, implements an automated commissioning method for a power distribution terminal as described in any one of claims 1-7.

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