Master station and voltage-time cooperative self-healing method, device and equipment

Abstract

The invention provides a master station and voltage-time cooperative self-healing method, device and equipment, and belongs to the technical field of power distribution automation of a power system. The method is applied to a power distribution network containing a distributed power supply, and comprises the following steps: when a fault signal of a feeder line and an opening signal of an outgoing circuit breaker are received, detecting whether a splitting signal of a grid-connected switch of the distributed power supply is received within a certain time, and if not, remotely controlling the splitting of the distributed power supply by a power distribution master station; and after delay time is determined according to the fault type of the feeder line and delay waiting is carried out, whether a closing and blocking signal is received is detected, and if yes, the power distribution main station starts self-healing to carry out fault positioning and recover power supply of a non-fault area at the downstream of a fault point. The method can improve the fault processing reliability of the power distribution network, and improves the safety and power supply reliability of the power distribution network.

Description

Technical Field

[0001] This disclosure relates to the field of power system distribution automation technology, and in particular to a master station and voltage-time coordinated self-healing method, apparatus and equipment. Background Technology

[0002] A dispatch automation system is an integrated system consisting of a master station, substations, corresponding data transmission channels, and secondary system security protection facilities. Generally, dispatch automation systems modeled around 35kV and above substations are called main grid dispatch automation systems; systems primarily targeting 10kV and below distribution network dispatch management are called distribution network dispatch automation systems, also known as distribution automation systems (DAS). DAS focuses on solving the problems of fault location, isolation, and restoration of power supply to non-faulty areas in the distribution network, playing a crucial role in reducing user power outage time, improving power supply reliability, and increasing user satisfaction. The distribution master station is an important part of DAS, mainly used for distribution network data acquisition and monitoring, as well as analysis and application functions. Self-healing technology based on the distribution master station is a fault handling technology that coordinates the distribution master station and the Feeder Terminal Unit (FTU). Currently, self-healing technologies based on the distribution master station can be divided into centralized master station type, master station and voltage-time coordinated type, master station and differential protection coordinated type, and master station and intelligent distributed coordinated type.

[0003] In related technologies, the master station and voltage-time coordinated self-healing method combine the distribution master station with voltage-time feeder automation (FA). When a permanent fault occurs in the feeder, the voltage-time pole-mounted switch automation equipment, in conjunction with outgoing line protection and circuit breaker reclosing, can achieve automatic fault isolation and power restoration in non-faulty areas of the feeder. The distribution master station can initiate self-healing to restore power supply to the downstream non-faulty area of ​​the fault point. When a transient fault occurs in the feeder, the distribution master station will not initiate self-healing. When a distributed generation (DG) is connected to the feeder, the grid-connected switch of the DG will have a local disconnection function. The characteristic quantities of this function are voltage and frequency. When the outgoing circuit breaker trips for the first time, the grid-connected switch will generally disconnect the DG locally before the first reclosing due to changes in these characteristic quantities, thus ensuring that the above self-healing method is not affected by the DG connection.

[0004] However, when a small-current ground fault (i.e., a single-phase ground fault) occurs on a feeder, the feeder connected to the distribution grid (DG) after the first trip of the outgoing circuit breaker may form a relatively stable isolated network with stable voltage and frequency, making it impossible for the local disconnection function of the grid-connected switch to reliably disconnect the DG. This situation will lead to a failure of the first reclosing operation. If the fault is transient, it will become a permanent fault. If the fault is permanent, it will cause the voltage-time type power distribution unit (FA) to fail and the distribution substation will not be able to initiate self-healing, thus affecting the reliability of fault handling in the distribution network. Summary of the Invention

[0005] This disclosure provides a master station and voltage-time coordinated self-healing method, apparatus, and equipment, which can improve the reliability of distribution network fault handling, and enhance the safety and power supply reliability of the distribution network. The technical solution includes at least the following: Firstly, a master station and voltage-time coordinated self-healing method is provided, applied to a distribution network containing distributed power sources. The method includes: upon receiving a fault signal from a feeder and a tripping signal from an outgoing circuit breaker, detecting whether a disconnection signal from the grid-connected switch of the distributed power source is received within a certain time; if not, the distribution master station remotely disconnects the distributed power source; after determining a delay time based on the fault type of the feeder and performing a delay wait, detecting whether a closing and blocking signal is received; if so, the distribution master station initiates self-healing to locate the fault and restore power supply to the non-faulty area downstream of the fault point.

[0006] Optionally, when a fault signal from the feeder is received and a tripping signal from the outgoing circuit breaker is received, detecting whether a disconnection signal from the grid-connected switch of the distributed power source is received within a certain time period includes: acquiring the fault signal from the feeder and determining the fault type of the feeder; determining a detection time based on the fault type and detecting whether a tripping signal from the outgoing circuit breaker is received within the detection time period; if so, detecting whether a disconnection signal from the grid-connected switch of the distributed power source is received within a certain time period.

[0007] Optionally, the fault signal is a current protection action signal or a low current grounding alarm signal, and the determination of the fault type of the feeder includes: if the fault signal is the current protection action signal, then the fault type is determined to be a phase-to-phase short circuit fault; if the fault signal is the low current grounding alarm signal, then the fault type is determined to be a low current grounding fault.

[0008] Optionally, determining the detection time based on the fault type and detecting whether the tripping signal of the outgoing circuit breaker is received within the detection time includes: if the fault type is a phase-to-phase short-circuit fault, detecting whether the tripping signal of the outgoing circuit breaker is received within time t1; if the fault type is a low-current ground fault, detecting whether the tripping signal of the outgoing circuit breaker is received within time t2, where t2 is greater than t1.

[0009] Optionally, the detection of whether the grid-connected switch of the distributed power source is received within a certain period of time includes: detecting whether the grid-connected switch of the distributed power source is received within time t3, where t3 is greater than 1s and less than 2s.

[0010] Optionally, determining the delay time and performing a delay wait based on the fault type of the feeder includes: if the fault type is a phase-to-phase short-circuit fault, then determining the delay time as t4 and performing a delay wait; if the fault type is a low-current ground fault, then determining the delay time as t5 and performing a delay wait, where t5 is less than t4.

[0011] Secondly, a master station and voltage-time coordinated self-healing device is provided, applied to a distribution network containing distributed power sources. The device includes: a disconnection module, used to detect whether a disconnection signal from the grid-connected switch of the distributed power source is received within a certain time when a fault signal of the feeder and a tripping signal of the outgoing circuit breaker are received; if not, the distribution master station remotely disconnects the distributed power source; and a recovery module, used to determine a delay time according to the fault type of the feeder and, after a delay, detect whether a closing lockout signal is received; if so, the distribution master station initiates self-healing to locate the fault and restore power supply to the non-faulty area downstream of the fault point.

[0012] Thirdly, a computer device is provided, comprising: a memory and a processor, wherein the memory stores at least one computer program, and the at least one computer program is loaded and executed by the processor to implement the master station and voltage-time coordinated self-healing method described in the above embodiments.

[0013] Fourthly, a computer-readable storage medium is provided, wherein at least one computer program is stored in the computer-readable storage medium, the at least one computer program being loaded and executed by a processor to implement the master station and voltage-time coordinated self-healing method described in the above embodiments.

[0014] Fifthly, a computer program product is provided, including a computer program / instruction, which, when executed by a processor, implements the master station and voltage-time coordinated self-healing method described in the above embodiments.

[0015] The beneficial effects of the technical solutions provided in this disclosure include at least the following: In this embodiment of the disclosure, when a fault signal from the feeder and a tripping signal from the outgoing circuit breaker are received, it is detected whether a disconnection signal from the grid-connected switch of the distributed generation is received within a certain period of time. If not, the distribution master station remotely disconnects the distributed generation. By taking advantage of the distribution master station's ability to obtain various change information messages (forwarded by the main grid dispatch and FTU) and remotely control the FTU, it can be ensured that the DG is remotely disconnected when a feeder fault occurs and the DG is not disconnected locally, thereby effectively reducing the probability of forming a relatively stable isolated network and improving the reliability of distribution network fault handling. Furthermore, a delay is performed before detecting the closing interlock signal to ensure the acquisition of complete change information messages, which is beneficial for auxiliary analysis. Then, it checks whether the closing interlock signal has been received. If so, the distribution master station initiates self-healing to locate the fault and restore power supply to the non-faulty area downstream of the fault point. This ensures that the voltage-time type FA has completed fault isolation. Upon receiving the fault signal, the outgoing circuit breaker trips, and the closing interlock triple insurance mechanism initiates self-healing. This reduces the probability of the distribution master station's self-healing function malfunctioning in non-fault situations or still malfunctioning after successful reclosing during a transient fault, thereby improving the safety and reliability of the distribution network and power supply. Attached Figure Description

[0016] To more clearly illustrate the technical solutions in the embodiments of this disclosure, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of this disclosure. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0017] Figure 1 This is a flowchart of a master station and voltage-time coordinated self-healing method provided in an embodiment of this disclosure; Figure 2 This is a flowchart of another master station and voltage-time coordinated self-healing method provided in this disclosure embodiment; Figure 3 This is a schematic diagram of a 10kV distribution network provided in an embodiment of this disclosure; Figure 4 This is a structural block diagram of a master station and voltage-time coordinated self-healing device provided in an embodiment of this disclosure; Figure 5 This is a schematic diagram of the structure of a computer device provided in an embodiment of this disclosure. Detailed Implementation

[0018] Unless otherwise defined, the technical or scientific terms used herein shall have the ordinary meaning as understood by one of ordinary skill in the art to which this disclosure pertains. The terms “first,” “second,” “third,” and similar terms used in this patent application specification and claims do not indicate any order, quantity, or importance, but are merely used to distinguish different components. Similarly, the terms “an” or “a” and similar terms do not indicate a quantity limitation, but rather indicate the presence of at least one. The terms “comprising” or “including” and similar terms mean that the elements or objects preceding “comprising” or “including” encompass the elements or objects listed following “comprising” or “including” and their equivalents, but do not exclude other elements or objects.

[0019] To make the objectives, technical solutions, and advantages of this disclosure clearer, the embodiments of this disclosure will be described in further detail below with reference to the accompanying drawings.

[0020] Figure 1 This is a flowchart illustrating a master station and voltage-time coordinated self-healing method provided in an embodiment of this disclosure. This method is applied to distribution networks containing distributed generation sources, such as... Figure 1 As shown, the method includes: In step S101, when a fault signal from the feeder is received and a tripping signal from the outgoing circuit breaker is received, it is detected whether a disconnection signal from the grid-connected switch of the distributed power source is received within a certain time. If not, the power distribution master station remotely disconnects the distributed power source.

[0021] In step S102, after determining the delay time according to the fault type of the feeder and waiting for the delay, it is detected whether a closing lockout signal is received. If so, the power distribution master station starts self-healing to locate the fault and restore power supply to the non-faulty area downstream of the fault point.

[0022] In this embodiment of the disclosure, when a fault signal from the feeder and a tripping signal from the outgoing circuit breaker are received, it is detected whether a disconnection signal from the grid-connected switch of the distributed generation is received within a certain period of time. If not, the distribution master station remotely disconnects the distributed generation. By taking advantage of the distribution master station's ability to obtain various change information messages (forwarded by the main grid dispatch and FTU) and remotely control the FTU, it can be ensured that the DG is remotely disconnected when a feeder fault occurs and the DG is not disconnected locally, thereby effectively reducing the probability of forming a relatively stable isolated network and improving the reliability of distribution network fault handling. Furthermore, a delay is performed before detecting the closing interlock signal to ensure the acquisition of complete change information messages, which is beneficial for auxiliary analysis. Then, it checks whether the closing interlock signal has been received. If so, the distribution master station initiates self-healing to locate the fault and restore power supply to the non-faulty area downstream of the fault point. This ensures that the voltage-time type FA has completed fault isolation. Upon receiving the fault signal, the outgoing circuit breaker trips, and the closing interlock triple insurance mechanism initiates self-healing. This reduces the probability of the distribution master station's self-healing function malfunctioning in non-fault situations or still malfunctioning after successful reclosing during a transient fault, thereby improving the safety and reliability of the distribution network and power supply.

[0023] Figure 2 This is a flowchart of another master station and voltage-time coordinated self-healing method provided in this disclosure embodiment. This method is applied to distribution networks with distributed power sources, such as... Figure 2 As shown, the method includes: after a fault signal is triggered, step S201 is executed.

[0024] The method will be illustrated below with a specific example of a power distribution network. Figure 3 This is a schematic diagram of a 10kV distribution network provided in an embodiment of this disclosure. Figure 3 As shown, taking this 10kV distribution network as an example, M1, M2, and M3 are the busbars of three substations, M1 shows two feeders, M2 and M3 each show one feeder, for a total of four feeders, CB represents outgoing circuit breakers, CB1, CB2, CB3, and CB4 are the outgoing circuit breakers corresponding to the four feeders, LD is the load, DG is the distributed generation, S is the sectionalizing switch (among which S21, S31, and S51 also serve as the grid connection switches for DG21, DG31, and DG51, respectively), LS is the tie switch, and k1 and k2 are examples of fault points. Figure 3 In the middle, each section switch S is in the closed position, and each tie switch LS is in the open position.

[0025] For example, the fault signal is either a current protection activation signal or a low-current grounding alarm signal. The fault signal is forwarded to the DAS by the main network dispatcher. Figure 3As shown, when a phase-to-phase short-circuit fault occurs at fault point k1, the distribution master station will receive a current protection action signal forwarded by the main grid dispatch; when a small current ground fault occurs at fault point k1, the distribution master station will receive a small current ground fault alarm signal forwarded by the main grid dispatch. Both fault signals will trigger step S201.

[0026] In step S201, it is determined whether the fault type of the feeder is a phase-to-phase short circuit. If yes, then step S202a is executed; otherwise, step S202b is executed.

[0027] For example, if the fault signal is a current protection action signal, the fault type is determined to be a phase-to-phase short circuit fault; if the fault signal is a low-current grounding alarm signal, the fault type is determined to be a low-current grounding fault.

[0028] By using step S201, the fault signal of the feeder can be obtained and the type of fault of the feeder can be determined.

[0029] In step S202a, it is detected whether a tripping signal from the outgoing circuit breaker is received within time t1. If yes, then step S203 is executed; otherwise, the execution ends.

[0030] Optionally, t1 is greater than 1s and less than 2s.

[0031] For example, t1 = 1.5s. A phase-to-phase short circuit fault is caused by the overcurrent protection tripping. The tripping delay of this protection is generally 0.5s. Considering that signal transmission and the master station need a certain amount of time to obtain the change information message, a certain margin is given on this delay. Taking t1 as 1.5s can reliably detect the tripping signal of the outgoing line circuit breaker when the fault type is a phase-to-phase short circuit fault.

[0032] In step S202b, it is detected whether a tripping signal from the outgoing circuit breaker is received within time t2. If yes, then step S203 is executed; otherwise, the execution ends.

[0033] Optionally, t2 is greater than t1. Since low-current grounding faults are generally tripped by low-current grounding fault location devices, compared to phase-to-phase short-circuit faults which are tripped by overcurrent protection, the time required to select the faulty line is longer. This is beneficial to improving the efficiency of fault handling in the distribution network.

[0034] Optionally, t2 is greater than 5s and less than 15s.

[0035] For example, t2 = 10s. The low-current ground fault location device needs a certain amount of time to select the faulty line. Considering a certain margin, t2 is set to 10s to reliably detect the tripping signal of the outgoing line circuit breaker when the fault type is a low-current ground fault.

[0036] Through the steps S202a and S202b described above, the detection time can be determined according to the fault type, and it can be checked whether the tripping signal of the outgoing circuit breaker is received within the detection time. This can prevent false alarms of fault signals. Furthermore, since the tripping time of the outgoing circuit breaker varies greatly for different fault types, different detection times can be set for t1 and t2 according to different fault types. In the event of a permanent fault, power supply to the non-faulty area downstream of the fault point can be restored as quickly as possible, thereby improving the efficiency of distribution network fault handling.

[0037] Specifically, such as Figure 3 As shown, when a small current ground fault occurs at fault point k1, the small current ground fault selection device will trip. The main distribution station will receive the tripping signal of the outgoing circuit breaker CB1 within time t2. If the tripping signal of the outgoing circuit breaker CB1 is not received within time t2, the operation will end.

[0038] In other embodiments, the maximum value of t1 and t2 can also be taken as the detection time, and this disclosure does not limit this.

[0039] In step S203, it is detected whether a disconnection signal from the grid-connected switch of the distributed power source is received within time t3. If not, then step S204 is executed before step S205; if yes, then step S205 is executed.

[0040] Optionally, t3 is greater than 1s and less than 2s.

[0041] For example, t3 = 1.5s.

[0042] Through the above steps S201 to S203, when a fault signal from the feeder and a tripping signal from the outgoing circuit breaker are received, it can be detected whether a disconnection signal from the grid-connected switch of the distributed power source is received within a certain period of time.

[0043] In step S204, the power distribution master station remotely disconnects the DG.

[0044] After the outgoing circuit breaker trips, due to changes in characteristic voltage and frequency, the local tripping protection of the grid-connected switch is generally configured in a two-stage manner to trip. Considering that the first-stage operating time setting of the local tripping protection of the grid-connected switch is greater than 0.5s, and the second-stage operating time setting is generally delayed by 0.5s based on the first stage, and taking into account a certain margin, setting t3 to 1.5s can effectively reduce the probability of forming a relatively stable isolated network and being unable to trip the DG, and can also avoid false tripping of the tripping protection caused by phase-to-phase short-circuit faults of other feeders. For example, Figure 3 If a phase-to-phase short-circuit fault occurs at fault point k2, before the outgoing circuit breaker CB2 trips, due to the change in the disconnection characteristic quantity, if a reasonable delay is not set, the disconnection protection of the grid-connected switches S21 and S31 on the feeder corresponding to the outgoing circuit breaker CB1 may malfunction and trip.

[0045] When the number of grid-connected switches is small, considering that the typical reclosing time of a voltage-time type FA is 15s, the above steps S203 and S204 can reliably disconnect the DG before the first reclosing. When the number of grid-connected switches that need to be remotely disconnected is large, the time required for the distribution master station to remotely disconnect the DG increases accordingly. In this case, adjusting the first reclosing time can be considered.

[0046] Specifically, such as Figure 3 As shown, when a small current ground fault occurs at fault point k1, after the outgoing circuit breaker CB1 is tripped, if the changes in the characteristic voltage and frequency of the disconnection are insufficient to trip the grid-connected switches S21 and S31 and disconnect the distributed power sources DG21 and DG31, and no disconnection signal is received from the grid-connected switches S21 and S31 within time t3, then the distribution master station remotely trips the grid-connected switches S21 and S31 to disconnect the distributed power sources DG21 and DG31.

[0047] It should be noted that if there are other situations where the DG cannot be disconnected locally, the DG can also be remotely disconnected by the distribution master station in step S204.

[0048] In step S205, it is determined whether the fault type of the feeder is a phase-to-phase short circuit. If yes, then step S206a is executed; otherwise, step S206b is executed.

[0049] For example, in step S205, the fault type can be determined based on the fault type determined in step S201 above.

[0050] In step S206a, the delay time is determined to be t4 and a delay waiting is performed.

[0051] For example, t4 is greater than the sum of the times for the two reclosings of the outgoing circuit breaker, the delayed opening and closing of the sectionalizing switches, and the closing interlocking action when the voltage-time type FA is operating. The delay during a phase-to-phase short circuit fault mainly considers the time for the two reclosings of the outgoing circuit breaker, the delayed opening and closing of each sectionalizing switch, and the closing interlocking action. t4 being greater than the sum of these times ensures that a complete change information message is obtained when a phase-to-phase short circuit fault occurs.

[0052] In step S206b, the delay time is determined to be t5 and a delay waiting is performed.

[0053] For example, t5 is greater than the sum of the times for the primary reclosing of the outgoing circuit breaker, the delayed opening and closing of the sectionalizing switches, and the closing interlocking action when the voltage-time type FA is operating. The delay during a small current ground fault mainly considers the time for the primary reclosing of the outgoing circuit breaker, the delayed opening and closing of each sectionalizing switch, and the closing interlocking action. t5 being greater than the sum of these times ensures that a complete change information message is obtained when a small current ground fault occurs.

[0054] Optionally, t5 is less than t4. Since the secondary reclosing and power-on delay closing times of voltage-time type FA are relatively long (typical secondary reclosing time is 5s, and typical power-on delay closing time is 7s), different delay times can be set for t4 and t5 according to different fault types. This can restore power supply to non-faulty areas downstream of the fault point as soon as possible, thereby further improving the efficiency of distribution network fault handling.

[0055] By using the above steps S206a and S206b, the delay time can be determined according to the fault type of the feeder and a delay waiting period can be implemented.

[0056] Specifically, such as Figure 3 As shown, when a small current ground fault occurs at fault point k1, in this embodiment, the delay time can be determined to be t5 and a delay waiting can be performed.

[0057] In step S207, it is checked whether a closing lockout signal has been received. If yes, then step S208 is executed; otherwise, the execution ends.

[0058] Step S207 confirms that the fault is permanent and that the voltage-time type FA has completed fault isolation and closing lockout, thereby reducing the probability that the self-healing function will still operate after successful reclosing of a transient fault, which is beneficial to improving the safety of the distribution network.

[0059] For example, the closing interlock signal includes a forward closing interlock signal and a reverse closing interlock signal.

[0060] By using the steps S205 to S207 above, the delay time can be determined according to the fault type of the feeder, and after the delay is completed, the closing and blocking signal can be detected.

[0061] Specifically, such as Figure 3 As shown, when a permanent fault occurs at fault point k1 and the voltage-time type FA is working normally, the sectionalizing switches S2 and S3 will open, and the master station will receive the forward closing lockout signal of sectionalizing switch S2 and the reverse closing lockout signal of sectionalizing switch S3.

[0062] In step S208, the power distribution master station initiates self-healing to locate the fault and restore power supply to the non-faulty area downstream of the fault point.

[0063] For example, after the distribution master station initiates self-healing, it first locates the fault in a certain section, and then restores power supply to the non-faulty area downstream of the fault point after the fault area is isolated, so as to reduce the power outage time for users.

[0064] For example, power can be restored by switching power to feeders in non-faulty areas via a closed interconnection switch.

[0065] It should be noted that since the power transfer may affect the load rate of the backup feeder, if the remaining capacity of the backup feeder is greater than the load of the area behind the fault point, the power transfer can be completed by closing the tie switch.

[0066] Specifically, such as Figure 3 As shown, when a permanent low-current ground fault occurs at fault point k1, in step S208, after the distribution master station calculates according to the relevant algorithm, if the feeder corresponding to the outgoing circuit breaker CB3 meets the power transfer requirements, the distribution master station can remotely close the tie switch LS1 to complete the power transfer.

[0067] In step S209, the self-healing process ends.

[0068] Step S209 is used to terminate the self-healing process.

[0069] The following are device embodiments of this application. For details not described in detail in the device embodiments, please refer to the above method embodiments.

[0070] Figure 4 This is a structural block diagram of a master station and voltage-time coordinated self-healing device provided in an embodiment of this disclosure. This device is applied to distribution networks containing distributed power sources, such as... Figure 4 As shown, the master station and voltage-time coordinated self-healing device 300 includes: a disconnect module 301 and a recovery module 302.

[0071] The disconnection module 301, upon receiving a fault signal from the feeder and a tripping signal from the outgoing circuit breaker, checks whether a disconnection signal from the grid-connected switch of the distributed power source is received within a certain time. If not, the distribution master station remotely disconnects the distributed power source. The recovery module 302, after determining the delay time based on the feeder fault type and performing the delay wait, checks whether a closing lockout signal is received. If so, the distribution master station initiates self-healing to locate the fault and restore power supply to the non-faulty area downstream of the fault point.

[0072] It should be noted that the self-healing process of the master station and voltage-time coordinated self-healing device provided in the above embodiments is only illustrated by the division of the above functional modules. In practical applications, the above functions can be assigned to different functional modules as needed, that is, the internal structure of the device can be divided into different functional modules to complete all or part of the functions described above. In addition, the master station and voltage-time coordinated self-healing device and the master station and voltage-time coordinated self-healing method embodiments provided in the above embodiments belong to the same concept, and the specific implementation process is detailed in the method embodiments, which will not be repeated here.

[0073] The module division in this embodiment is illustrative and represents only one logical functional division. In actual implementation, other division methods are possible. Furthermore, the functional modules in the various embodiments of this disclosure can be integrated into a single processor, exist as separate physical entities, or be integrated into a single module. The integrated modules described above can be implemented in hardware or as software functional modules.

[0074] If the integrated module is implemented as a software functional module and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this disclosure, in essence, or the part that contributes to the prior art, or all or part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a terminal device (which may be a personal computer, mobile phone, or communication device, etc.) or processor to execute all or part of the steps of the methods of the various embodiments of this disclosure. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0075] Figure 5 This is a schematic diagram of the structure of a computer device provided in an embodiment of this disclosure. For example... Figure 5 As shown, the computer device 1000 includes a processor 1001 and a memory 1002.

[0076] Processor 1001 may include one or more processing cores, such as a quad-core processor, an octa-core processor, etc. Processor 1001 may be implemented using at least one hardware form selected from DSP (Digital Signal Processing), FPGA (Field-Programmable Gate Array), and PLA (Programmable Logic Array). Processor 1001 may also include a main processor and a coprocessor. The main processor, also known as a CPU (Central Processing Unit), is used to process data in the wake-up state; the coprocessor is a low-power processor used to process data in the standby state. In some embodiments, processor 1001 may integrate a GPU (Graphics Processing Unit), which is responsible for rendering and drawing the content to be displayed on the screen. In some embodiments, processor 1001 may also include an AI (Artificial Intelligence) processor, which is used to handle computational operations related to machine learning.

[0077] The memory 1002 may include one or more computer-readable storage media, which may be non-transitory. The memory 1002 may also include high-speed random access memory and non-volatile memory, such as one or more disk storage devices or flash memory devices. In some embodiments, the non-transitory computer-readable storage media in the memory 1002 is used to store at least one instruction, which is executed by the processor 1001 to implement the master station and voltage-time co-operated self-healing method provided in the embodiments of this disclosure.

[0078] Those skilled in the art will understand that Figure 5 The structure shown does not constitute a limitation on the computer device 1000, and may include more or fewer components than shown, or combine certain components, or use different component arrangements.

[0079] This disclosure also provides a non-transitory computer-readable storage medium, wherein when instructions in the storage medium are executed by a processor of a computer device, the computer device is able to execute the master station and voltage-time co-operated self-healing method provided in this disclosure.

[0080] This disclosure also provides a computer program product, including a computer program / instruction, which, when executed by a processor, implements the master station and voltage-time coordinated self-healing method provided in this disclosure.

[0081] The above description is merely an optional embodiment of this disclosure and is not intended to limit this disclosure. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this disclosure should be included within the protection scope of this disclosure.

Claims

1. A master station and voltage-time coordinated self-healing method, applied to a distribution network containing distributed generation sources, characterized in that, The method includes: When a fault signal is received from the feeder and a trip signal is received from the outgoing circuit breaker, it is checked whether a disconnection signal from the grid-connected switch of the distributed power source is received within a certain period of time. If not, the power distribution master station remotely disconnects the distributed power source. After determining the delay time based on the fault type of the feeder and waiting for the delay, it checks whether a closing and blocking signal is received. If so, the power distribution master station initiates self-healing to locate the fault and restore power supply to the non-faulty area downstream of the fault point.

2. The master station and voltage-time coordinated self-healing method according to claim 1, characterized in that, The step of detecting whether a disconnection signal from the grid-connected switch of the distributed power source is received within a certain time after receiving a fault signal from the feeder and a tripping signal from the outgoing circuit breaker includes: Acquire the fault signal of the feeder and determine the fault type of the feeder; The detection time is determined according to the fault type, and it is detected whether the tripping signal of the outgoing circuit breaker is received within the detection time. If so, it is detected whether the disconnection signal of the grid-connected switch of the distributed power source is received within a certain period of time.

3. The master station and voltage-time coordinated self-healing method according to claim 2, characterized in that, The fault signal is either a current protection action signal or a low-current grounding alarm signal. Determining the fault type of the feeder includes: If the fault signal is the current protection action signal, then the fault type is determined to be a phase-to-phase short circuit fault. If the fault signal is the low current grounding alarm signal, then the fault type is determined to be a low current grounding fault.

4. The master station and voltage-time coordinated self-healing method according to claim 3, characterized in that, The step of determining the detection time based on the fault type and detecting whether the tripping signal of the outgoing circuit breaker is received within the detection time includes: If the fault type is a phase-to-phase short circuit fault, then check whether the tripping signal of the outgoing circuit breaker is received within time t1. If the fault type is a low-current ground fault, then check whether the tripping signal of the outgoing circuit breaker is received within time t2, where t2 is greater than t1.

5. The master station and voltage-time coordinated self-healing method according to claim 2, characterized in that, The detection of whether a disconnection signal is received from the grid-connected switch of the distributed power source within a certain period of time includes: Detect whether the grid disconnection signal of the distributed power source is received within time t3, where t3 is greater than 1s and less than 2s.

6. The master station and voltage-time coordinated self-healing method according to claim 3 or 4, characterized in that, The step of determining the delay time based on the fault type of the feeder and performing a delay wait includes: If the fault type is a phase-to-phase short circuit fault, then the delay time is determined to be t4 and a delay waiting is performed; If the fault type is a low-current ground fault, then the delay time is determined to be t5 and a delay waiting is performed, where t5 is less than t4.

7. A master station and voltage-time coordinated self-healing device, applied to a distribution network containing distributed power sources, characterized in that, The device includes: The disconnection module is used to detect whether the grid-connected switch of the distributed power source has been received within a certain period of time when a fault signal of the feeder and a trip signal of the outgoing circuit breaker are received. If not, the power distribution master station remotely disconnects the distributed power source. The recovery module is used to determine the delay time according to the fault type of the feeder and wait for the delay, and then detect whether a closing lockout signal is received. If so, the power distribution master station starts self-healing to locate the fault and restore power supply to the non-faulty area downstream of the fault point.

8. A computer device, characterized in that, The computer device includes a memory and a processor, wherein the memory stores at least one computer program, which is loaded and executed by the processor to implement the method according to any one of claims 1 to 6.

9. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores at least one computer program, which is loaded and executed by a processor to implement the method according to any one of claims 1 to 6.

10. A computer program product comprising a computer program / instructions, characterized in that, When the computer program / instructions are executed by the processor, they implement the method described in any one of claims 1 to 6.

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