Transformer area topology identification method and device based on carrier communication network, and concentrator

Abstract

The invention relates to a transformer area topology identification method and device based on a carrier communication network, and a concentrator. The method comprises the following steps: determining electric energy meter nodes in the same phase line and the same court and electric energy meter nodes in a cluster unit of the lowest level in a plurality of cluster units; performing hierarchical identification on the plurality of cluster units by adopting a carrier communication network to obtain hierarchies of the plurality of cluster units; according to the electric quantity data sent by the monitoring device corresponding to each branch box cluster unit in the plurality of cluster units and the electric quantity data sent by the monitoring devices corresponding to the superior power distribution room unit and the subordinate plurality of meter box units of each branch box cluster unit, determining an outgoing line and incoming line corresponding relation of the branch box cluster units in the plurality of cluster units, and forming a transformer area topological graph. By adopting the method, the transformer area topology identification can be carried out based on the carrier communication network, so that the situation that signal receiving devices are additionally arranged on branch boxes and electric meter boxes in a power distribution network is avoided, and the cost of transformer area topology identification is further reduced.

Description

Technical Field

[0001] The present application relates to the technical field of distribution network, and in particular to a method and device for identifying substation topology based on a carrier communication network, and a concentrator. Background Art

[0002] In the distribution network, the topology identification of the energy meter nodes in the low-voltage area is the basis for parameter setting, equipment debugging and equipment maintenance of the energy meter nodes in the low-voltage area. Therefore, the topology identification of the energy meter nodes in the low-voltage area is very important in the distribution network.

[0003] In related technologies, the topology identification of electric energy meter nodes in low-voltage substations often adopts the signal injection method, that is, the signal sending device in the distribution network injects characteristic current (such as pulse wave, superposition of sinusoidal waves of specific frequency, variable frequency signal, etc.) into the cable, and the signal receiving device in the distribution network (such as the signal receiving device in the transformer, each branch box and each meter box) identifies the parent node of each branch box and each meter box in the distribution network according to the current direction of the characteristic current, thereby obtaining the topology map of the entire substation.

[0004] However, in the related art, it is necessary to install signal receiving devices on transformers, branch boxes and meter boxes in the distribution network, resulting in high costs for substation topology identification. Summary of the Invention

[0005] Based on this, the present application provides a substation topology identification method, device, and concentrator based on a carrier communication network, which can perform substation topology identification based on a carrier communication network, thereby avoiding the installation of signal receiving devices to each branch box and each meter box in the distribution network, thereby reducing the cost of substation topology identification.

[0006] In a first aspect, the present application provides a method for identifying a topology of a cell area based on a carrier communication network, the method being applied to a concentrator in a cell area, the method comprising:

[0007] Determine the electric energy meter nodes in the same phase line and the same substation based on the collected information on the change of the voltage of each phase line in the substation over time and the information on the change of the voltage sent by each electric energy meter node over time;

[0008] Determine the electric energy meter node in the lowest level cluster unit among the plurality of cluster units according to the distance between the concentrator and the electric energy meter node in the same phase line and the same substation obtained by using the carrier communication network;

[0009] A carrier communication network is used to perform hierarchical identification on a plurality of cluster units to obtain hierarchies of the plurality of cluster units;

[0010] Determine the correspondence between the incoming and outgoing lines of the branch box cluster units in the multiple cluster units based on the power data sent at fixed time intervals by the monitoring device corresponding to each branch box cluster unit in the multiple cluster units, and the power data sent at fixed time intervals by the monitoring devices corresponding to the power distribution room unit above and the multiple meter box units below each branch box cluster unit;

[0011] A substation topology map is formed based on the electric energy meter nodes in the same phase line and the same substation, the electric energy meter nodes in each cluster unit, the hierarchy of multiple cluster units, and the correspondence between the incoming and outgoing lines.

[0012] In some embodiments, determining electric energy meter nodes in the same phase line and the same substation based on the collected information on the change of the voltage of each phase line in the substation over time and the information on the change of the voltage sent by each electric energy meter node over time includes:

[0013] Determine the zero-crossing time of the voltage in each phase line in the substation, the zero-crossing time of the voltage in each electric energy meter node, the voltage sequence of each phase line in the substation, and the voltage sequence of each electric energy meter node based on the time-varying information of the voltage in each phase line in the substation and the time-varying information of the voltage at each electric energy meter node;

[0014] Determine the electric energy meter nodes in the same phase line according to the zero-crossing time of the voltage in each phase line in the substation and the zero-crossing time of the voltage in each electric energy meter node;

[0015] According to the voltage sequence of each phase line in the substation and the voltage sequence of the electric energy meter nodes in each phase line, the electric energy meter nodes in the same phase line and the same substation are determined.

[0016] In some embodiments, determining the electric energy meter nodes in the same phase line and the same substation according to the voltage sequence of each phase line in the substation and the voltage sequence of the electric energy meter nodes in each phase line includes:

[0017] Determine the correlation coefficient between the voltage series of each phase line in the substation and the voltage series of the electric energy meter nodes within each phase line;

[0018] determining a target correlation coefficient greater than or equal to a preset coefficient from the correlation coefficients;

[0019] The electric energy meter nodes corresponding to the target correlation coefficient are determined to be the electric energy meter nodes in the same phase line and the same substation.

[0020] In some embodiments, determining the electric energy meter node in the lowest-level cluster unit among the plurality of cluster units based on the distance between the concentrator and the electric energy meter node in the same phase line and the same substation obtained using a carrier communication network includes:

[0021] Using a carrier communication network, the distance between the concentrator and the electric energy meter nodes on the same phase line and in the same substation area, the similarity of the signal-to-noise ratio sequence, and the signal attenuation are obtained;

[0022] According to the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation, the similarity of the signal-to-noise ratio sequence and the signal attenuation, the electric energy meter node in the lowest level cluster unit among the multiple cluster units is determined.

[0023] In some embodiments, a carrier communication network is used to obtain the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation, the similarity of the signal-to-noise ratio sequence, and the signal attenuation, including:

[0024] Determine the distance between the concentrator and the electric energy meter nodes on the same phase line and in the same substation based on the time when the concentrator in the substation sends the carrier signal using the carrier communication network and the time when the electric energy meter nodes on the same phase line and in the same substation receive the carrier signal;

[0025] Determining similarity of signal-to-noise ratio sequences based on signal-to-noise ratio sequences transmitted by electric energy meter nodes in the same phase line and the same substation; wherein the signal-to-noise ratio sequences are obtained by measuring carrier signals received by the electric energy meter nodes in the carrier communication network;

[0026] The signal attenuation is determined based on the signal transmission strength of the carrier signal sent by the concentrator in the substation using the carrier communication network and the signal reception strength of the carrier signal sent by the electric energy meter node in the same phase line and the same substation.

[0027] In some embodiments, determining the electric energy meter node in the lowest level cluster unit among the plurality of cluster units based on the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation, the similarity of the signal-to-noise ratio sequence, and the signal attenuation includes:

[0028] Determine, based on the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation, a first affiliation relationship between the electric energy meter nodes in the same phase line and the same substation and the cluster units at the lowest level;

[0029] According to the similarity of the signal-to-noise ratio sequence, the first affiliation relationship is adjusted to obtain a second affiliation relationship between the electric energy meter nodes and the lowest-level cluster units in the same phase line and the same substation;

[0030] The second affiliation relationship is adjusted according to the signal attenuation to obtain the electric energy meter node in the lowest-level cluster unit among the multiple cluster units.

[0031] In some embodiments, performing hierarchical identification on a plurality of cluster units to obtain hierarchies of the plurality of cluster units includes:

[0032] Determining the distance between each non-lowest level cluster unit and the cluster unit at the next level based on the time at which the monitoring device corresponding to each non-lowest level cluster unit sends the carrier signal and the time at which the monitoring device corresponding to the cluster unit at the next level of each non-lowest level cluster unit receives the carrier signal;

[0033] The hierarchy of the plurality of cluster units is determined based on the distance between each non-lowest-level cluster unit and a cluster unit of a next-lower level.

[0034] In some embodiments, determining the correspondence between the incoming and outgoing lines of the branch box cluster units in the multiple cluster units based on the power data sent at fixed time intervals by the monitoring device corresponding to each branch box cluster unit in the multiple cluster units and the power data sent at fixed time intervals by the monitoring devices corresponding to the power distribution room unit above and the multiple meter box units below each branch box cluster unit includes:

[0035] Determine the power characteristic sequence of each branch box according to the power data sent by the monitoring device corresponding to each branch box in each branch box cluster unit at a fixed time interval;

[0036] Determine the power characteristic sequence of the power distribution room unit and the power characteristic sequence of each meter box unit based on the power data sent at fixed time intervals by the monitoring devices corresponding to the power distribution room unit above each branch box cluster unit and the multiple meter box units below;

[0037] Determine the branch box connected to the distribution room unit based on the power characteristic sequence of each branch box and the power characteristic sequence of the distribution room unit;

[0038] Determine the connection relationship of each branch box based on the branch box connected to the power distribution room unit and the power characteristic sequence of each branch box;

[0039] Determine the branch box connected to each meter box unit based on the power characteristic sequence of the last branch box in the connection relationship of each branch box and the power characteristic sequence of each meter box unit;

[0040] According to the branch box connected to the power distribution room unit, the connection relationship between each branch box and the branch box connected to each meter box unit, the corresponding relationship between the incoming and outgoing lines of the branch box cluster units in multiple cluster units is determined.

[0041] In a second aspect, the present application provides a device for identifying a topology of a substation based on a carrier communication network, the device comprising:

[0042] Phase line substation area determination module, used to determine the electric energy meter nodes in the same phase line and the same substation area based on the collected information on the change of the voltage of each phase line in the substation area over time and the information on the change of the voltage over time sent by each electric energy meter node;

[0043] A cluster unit determination module, configured to determine an electric energy meter node in a lowest-level cluster unit among the plurality of cluster units based on a distance between a concentrator and an electric energy meter node in the same phase line and the same substation area obtained using a carrier communication network;

[0044] A cluster level determination module is used to identify the levels of the multiple cluster units using a carrier communication network to obtain the levels of the multiple cluster units;

[0045] An incoming and outgoing line determination module is configured to determine the corresponding relationship between the incoming and outgoing lines of the branch box cluster units in the multiple cluster units based on the power data sent at fixed time intervals by the monitoring device corresponding to each branch box cluster unit in the multiple cluster units, and the power data sent at fixed time intervals by the monitoring devices corresponding to the power distribution room unit above and the multiple meter box units below each branch box cluster unit;

[0046] The formation module is used to form a substation topology map based on the electric energy meter nodes in the same phase line and the same substation, the electric energy meter nodes in each cluster unit, the hierarchy of multiple cluster units, and the correspondence between the incoming and outgoing lines.

[0047] In a second aspect, the present application provides a concentrator, comprising a memory and a processor, wherein the memory stores a computer program, and the processor implements the steps of any one of the methods in the first aspect when executing the computer program.

[0048] In the technical solution provided in the embodiment of the present application, substation topology identification can be performed based on the carrier communication network, thereby avoiding the installation of signal receiving devices in each branch box and each meter box in the distribution network, thereby reducing the cost of substation topology identification, and there is no need to inject characteristic current into the cable, thereby reducing the risk of harmonic pollution; in addition, a substation topology map is formed based on the electricity meter nodes in the same phase line and the same substation, the electricity meter nodes in each cluster unit, the hierarchy of multiple cluster units, and the correspondence between the incoming and outgoing lines, so that the connection relationship of the scattered equipment in the complex distribution network can be converted into a visual, structured data model, which significantly improves the accuracy and completeness of the topology identification; through the systematic analysis of the correspondence between the hierarchy and the line, the efficiency of the topology map construction is greatly improved, providing intuitive and reliable data support for the rapid fault location, accurate load prediction and intelligent operation and maintenance management of the power system. BRIEF DESCRIPTION OF THE DRAWINGS

[0049] In order to more clearly illustrate the technical solutions in the embodiments of the present application or related technologies, the following briefly introduces the drawings required for use in the embodiments of the present application or related technical descriptions. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other related drawings can be obtained based on these drawings without paying any creative work.

[0050] Figure 1 The method for identifying the area topology based on the carrier communication network provided in the first embodiment;

[0051] Figure 2 The method for identifying the area topology based on the carrier communication network provided in the second embodiment;

[0052] Figure 3 The method for identifying the area topology based on the carrier communication network provided in the third embodiment;

[0053] Figure 4 A method for identifying a substation topology based on a carrier communication network provided in the fourth embodiment;

[0054] Figure 5 A schematic flow chart of a method for determining a correspondence between incoming and outgoing lines of branch box cluster units in a plurality of cluster units in some embodiments;

[0055] Figure 6 A schematic structural diagram of a carrier communication network-based substation topology identification device provided in some embodiments;

[0056] Figure 7 A schematic structural diagram of a concentrator provided in some embodiments. DETAILED DESCRIPTION

[0057] The following embodiments of the technical solution of the present application will be described in detail with reference to the accompanying drawings. The following embodiments are only used to more clearly illustrate the technical solution of the present application and are therefore only examples and are not intended to limit the scope of protection of the present application.

[0058] Unless otherwise defined, all technical and scientific terms used herein have the same meaning as commonly understood by those skilled in the art to which this application belongs; the terms used herein are only for the purpose of describing specific embodiments and are not intended to limit this application; the terms "including" and "having" and any variations thereof in the specification and claims of this application and the above-mentioned figure descriptions are intended to cover non-exclusive inclusions.

[0059] In the description of the embodiments of the present application, the technical terms "first" and "second" are only used to distinguish different objects and cannot be understood as indicating or implying relative importance or implicitly indicating the number, specific order or primary and secondary relationship of the indicated technical features. In the description of the embodiments of the present application, the meaning of "plurality" is more than two, unless otherwise clearly and specifically defined. In the description of the embodiments of the present application, "each" means each or each of a plurality, unless otherwise clearly and specifically defined.

[0060] References herein to "embodiments" mean that a particular feature, structure, or characteristic described in connection with the embodiments may be included in at least one embodiment of the present application. The appearance of this phrase in various places in the specification does not necessarily refer to the same embodiment, nor does it constitute an independent or alternative embodiment that is mutually exclusive of other embodiments. It is understood, both explicitly and implicitly, by those skilled in the art that the embodiments described herein may be combined with other embodiments.

[0061] In the description of the embodiments of this application, the term "and / or" is simply a description of the association relationship between associated objects, indicating that three relationships can exist. For example, A and / or B can represent the following three situations: A exists alone, A and B exist simultaneously, and B exists alone. In addition, the character " / " in this document generally indicates that the associated objects are in an "or" relationship.

[0062] In the low-voltage substation topology automatic identification technology, different methods can be used to identify the substation topology map. For example, common methods may include signal injection method and big data analysis method.

[0063] In the signal injection method, the topology identification system consists of a signal transmitter and a signal receiver. The signal transmitter is built into the power line broadband carrier communication module, while the signal receiver is installed at the incoming or outgoing line of the transformer, branch box, and meter box. The signal transmitter injects a characteristic current into the cable, and the receiver detects the direction of the current. Based on this direction, it automatically identifies the corresponding parent and child nodes, thereby obtaining a topology map of the entire substation. However, the signal injection method has the following problems: First, the cost of substation topology identification is high, as signal receivers must be installed at the incoming or outgoing line of the transformer, branch box, and meter box. Second, there is the risk of harmonic pollution. Since characteristic current is injected into the cable at irregular intervals, the characteristic current can appear in the form of pulse waves, superposition of sinusoidal waves of a specific frequency, or variable frequency signals. The impact of the generated harmonic components on power supply quality is difficult to assess.

[0064] Big data analysis methods often rely on a large amount of sample data and deeply explore the intrinsic connections between various electrical parameters to achieve topology identification. However, the big data analysis topology identification method for low-voltage substations is still in its initial exploratory stage in theory and application, and the accuracy of the substation topology map obtained is low.

[0065] The following embodiment provides a substation topology identification method based on a carrier communication network, which can perform substation topology identification based on a carrier communication network, thereby avoiding the installation of signal receiving devices in each branch box and each meter box in the distribution network, thereby reducing the cost of substation topology identification, and there is no need to inject characteristic current into the cable, thereby reducing the risk of harmonic pollution.

[0066] Figure 1 The method for identifying a topology of a substation area based on a carrier communication network provided in the first embodiment is applied to a concentrator in the substation area. The method includes:

[0067] S101 : Determine electric energy meter nodes in the same phase line and the same substation based on the collected information on the change of the voltage of each phase line in the substation over time and the information on the change of the voltage sent by each electric energy meter node over time.

[0068] In the power system, the substation refers to the power supply range or area of ​​(a) transformer.

[0069] The concentrator in the substation area can be the concentrator at the beginning of the substation area. Substation refers to the distribution transformer, which is a key equipment in the power system.

[0070] The concentrator is the central management device and concentrator of the remote centralized meter reading system, responsible for functions such as regular reading of terminal data, system command transmission, data communication, network management, event recording, and horizontal transmission of data.

[0071] In some embodiments, the concentrator may include a local communication module (also known as a carrier communication module) that can collect information about the time-varying voltages of each phase line in the substation. For example, the local communication module can collect information about the time-varying voltages of each phase line in the substation via a collector.

[0072] For example, each phase line may include each phase line of phase a, phase b, and phase C. Different phase line voltages have different information about changes over time.

[0073] In the substation, each electric energy meter node can record the voltage change information over time, and then send the voltage change information over time to the concentrator.

[0074] In some embodiments, each electric energy meter node in the substation can send information about the voltage change over time sent by each electric energy meter node to the concentrator once every preset time period (for example, three days, a week, or a month). In other embodiments, the concentrator in the substation can output a voltage change request, and each electric energy meter node in the substation sends information about the voltage change over time sent by each electric energy meter node to the concentrator based on the received voltage change request. In some embodiments, each electric energy meter node in the substation can send information about the voltage change over time within a preset time period to the concentrator. In other embodiments, each electric energy meter node in the substation receives a stop sending request sent by the concentrator, and based on the received stop sending request, stops sending information about the voltage change over time within the preset time period to the concentrator.

[0075] For example, the voltage change over time information may include obtaining a timestamp at predetermined intervals and the voltage corresponding to the timestamp. For example, the predetermined interval may be a interval between 0.01 seconds and 2 seconds, for example, 0.01 seconds, 0.1 seconds, 1 second, or 2 seconds.

[0076] In some embodiments, the time period corresponding to the information on the change of voltage of each phase line in the substation over time can be the same as the time period corresponding to the information on the change of voltage over time sent by each electric energy meter node, thereby avoiding the problem of inaccurate phase lines and substations corresponding to the electric energy meter nodes due to time misalignment.

[0077] In some embodiments, the electric energy meter nodes in the same area may include the electric energy meter nodes in the area where the concentrator in this application is located. In this way, the concentrator in each area can obtain the electric energy meter nodes in each area.

[0078] S102: Determine an electric energy meter node in a lowest-level cluster unit among multiple cluster units based on the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation obtained through the carrier communication network.

[0079] In some embodiments, the carrier communication network may include a high-speed power line carrier communication (HPLC) network. In other embodiments, the carrier communication network may include a high-speed dual-mode communication (HDC) network. In an HDC network, data transmission is performed using both high-speed power line carrier communication (HPLC) and high-speed radio frequency (HRF) technology. In some embodiments, in an HDC network, the same device may have both power line communication (PLC) and radio frequency (RF) modules, allowing data to be transmitted simultaneously or in a time-sharing manner over both links. For example, when a concentrator sends a meter reading instruction to an electricity meter, it first sends it via a PLC link. If no response is received after a timeout, it automatically switches to an RF link for retransmission to ensure delivery of the instruction. In other embodiments, the optimal link is dynamically selected based on real-time communication quality, for example, by monitoring indicators such as the received signal strength indicator (RSSI) and the bit error rate (BER), automatically switching to the PLC or RF link. For example, PLC is preferred for short-range devices, while RF is preferred for long-range devices or devices with many obstacles. For example, the embodiment of the present application is described with the carrier communication network being a high-speed power line carrier communication network.

[0080] In some embodiments, the concentrator can use a carrier communication network to send a carrier signal and record the signal sending time. The electric energy meter nodes in the same phase line and the same substation area can record the receiving time of the carrier signal and send the receiving time to the concentrator, so that the concentrator can obtain the communication time between the concentrator and the electric energy meter nodes in the same phase line and the same substation area. According to the communication time and the signal propagation speed (about 3×10 8 m / s), determine the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation.

[0081] Exemplarily, the multiple cluster units may include multiple distribution room cluster units, multiple branch box cluster units, and multiple meter box cluster units. In the power distribution system, the distribution room, branch box, and meter box are distribution equipment at different levels, which together complete the distribution, control, and metering of electric energy. As the hub of the distribution network, the distribution room is responsible for receiving high-voltage electricity, reducing the voltage to low voltage through a transformer, and then distributing it to downstream users or equipment. The branch box is located downstream of the distribution room and is used for branch distribution of electric energy, dividing one power supply into multiple routes to supply different areas or users. The meter box is used to install an electric energy meter to measure the user's electricity consumption.

[0082] In some embodiments, the electric energy meter nodes in each cluster unit may be electric energy meter nodes in each cluster unit under the same phase line and the same substation.

[0083] S103: Using a carrier communication network to perform hierarchical identification on the multiple cluster units to obtain hierarchies of the multiple cluster units.

[0084] In some embodiments, the distance between the concentrator and each cluster unit may be obtained, and the hierarchy of the plurality of cluster units may be determined according to the distance between the concentrator and each cluster unit.

[0085] For example, if the distance between the concentrator and a certain cluster unit is shorter, the level of the cluster unit is higher; if the distance between the concentrator and a certain cluster unit is longer, the level of the cluster unit is lower.

[0086] Among them, a cluster unit of a higher level can be connected to multiple cluster units of a lower level.

[0087] S104. Determine the correspondence between the incoming and outgoing lines of the branch box cluster units in the multiple cluster units based on the power data sent at fixed time intervals by the monitoring device corresponding to each branch box cluster unit in the multiple cluster units, and the power data sent at fixed time intervals by the monitoring devices corresponding to the upper-level distribution room unit and the multiple meter box units of each branch box cluster unit.

[0088] In S103, although the hierarchy of multiple cluster units can be determined, the branch box cluster unit includes multiple branch boxes, and the multiple branch boxes also have corresponding hierarchies. Therefore, it is also necessary to determine the correspondence between the incoming and outgoing lines of the branch box cluster unit to determine the connection relationship between the multiple branch boxes included in each branch box cluster unit, as well as the connection relationship between the top-level branch box and the distribution room cluster unit, and the connection relationship between the bottom-level branch box and the meter box cluster unit.

[0089] S105 , forming a substation topology map based on the electric energy meter nodes in the same phase line and the same substation, the electric energy meter nodes in each cluster unit, the hierarchy of multiple cluster units, and the correspondence between the incoming and outgoing lines.

[0090] Exemplarily, a directed graph is constructed based on the energy meter nodes within the same phase line and the same substation, the energy meter nodes within each cluster unit, the hierarchy of multiple cluster units, and the correspondence between incoming and outgoing lines, and the graph is determined as a substation topology graph. Exemplarily, each substation can form a directed graph, in which the vertices are substations, each substation connects to three phase lines, each phase line connects to a cluster unit at a higher level, each cluster unit connects to a cluster unit at the next level, and so on, until the cluster unit at the last level connects to multiple energy meter nodes.

[0091] In the technical solution provided in the embodiment of the present application, substation topology identification can be performed based on the carrier communication network, thereby avoiding the installation of signal receiving devices in each branch box and each meter box in the distribution network, thereby reducing the cost of substation topology identification, and there is no need to inject characteristic current into the cable, thereby reducing the risk of harmonic pollution; in addition, a substation topology map is formed based on the electricity meter nodes in the same phase line and the same substation, the electricity meter nodes in each cluster unit, the hierarchy of multiple cluster units, and the correspondence between the incoming and outgoing lines, so that the connection relationship of the scattered equipment in the complex distribution network can be converted into a visual, structured data model, which significantly improves the accuracy and completeness of the topology identification; through the systematic analysis of the correspondence between the hierarchy and the line, the efficiency of the topology map construction is greatly improved, providing intuitive and reliable data support for the rapid fault location, accurate load prediction and intelligent operation and maintenance management of the power system.

[0092] Figure 2 The second embodiment provides a method for identifying a topology of a station area based on a carrier communication network. The method is applied to a concentrator in a station area. Figure 2 Example compared to Figure 1 The difference between the embodiments is that S101 includes S1011 to S1013.

[0093] S1011. Determine the zero-crossing time of the voltage in each phase line in the substation, the zero-crossing time of the voltage in each electric energy meter node, the voltage sequence of each phase line in the substation, and the voltage sequence of each electric energy meter node based on the information on the change of the voltage of each phase line in the substation over time and the voltage change of each electric energy meter node over time.

[0094] Exemplarily, the zero-crossing time may be the zero-crossing time during a voltage rising process, or the zero-crossing time during a voltage falling process, or the zero-crossing time during a voltage rising process and the zero-crossing time during a voltage falling process.

[0095] In some embodiments, taking the zero-crossing time as the zero-crossing time in the voltage rising process as an example, when the acquired voltage change information over time is discrete data, two voltages of adjacent timestamps can be obtained, the first of the two voltages is a negative value, and the second voltage is a positive value. The zero-crossing time in the voltage rising process is determined based on the slopes corresponding to the two voltages of the adjacent timestamps.

[0096] In some embodiments, the voltage sequence and the voltage sequence may be a sequence consisting of voltages collected within a specified period (eg, one hour, 30 minutes, or ten minutes, etc.), wherein the different voltage sequences are all voltage sequences within the specified period.

[0097] S1012. Determine the electric energy meter nodes in the same phase line according to the zero-crossing time of the voltage in each phase line in the substation and the zero-crossing time of the voltage in each electric energy meter node.

[0098] For example, the phase line where each energy meter node is located can be identified based on the fact that the voltage zero crossing time between energy meter nodes on the same phase line is the same and the voltage zero crossing time between energy meter nodes on different phase lines is different, thereby determining the energy meter nodes within the same phase line.

[0099] S1013. Determine the electric energy meter nodes in the same phase line and the same substation according to the voltage sequence of each phase line in the substation and the voltage sequence of the electric energy meter nodes in each phase line.

[0100] For example, the voltage sequence correlation of the energy meter nodes on the same phase line in the same substation is high, while the voltage sequence correlation of the energy meter nodes on different phase lines in different substations is low, thereby inferring the energy meter nodes in the same substation as the concentrator. In some embodiments, the correlation calculation method uses the Pearson correlation coefficient method.

[0101] In some embodiments, based on the voltage sequence of each phase line in the substation and the voltage sequence of the electric energy meter nodes within each phase line, the electric energy meter nodes within the same phase line are determined, including: determining the correlation coefficient between the voltage sequence of each phase line in the substation and the voltage sequence of the electric energy meter nodes within each phase line; determining a target correlation coefficient greater than or equal to a preset coefficient from the correlation coefficients; and determining the electric energy meter node corresponding to the target correlation coefficient as the electric energy meter node within the same phase line and the same substation.

[0102] For example, taking the determination of the electric energy meter node within the phase A line of the current substation as an example, the voltage sequence of the phase A line of the current substation can be obtained, and the correlation coefficient between the voltage sequence of the phase A line of the current substation and the voltage sequence of all electric energy meter nodes within the phase A line can be determined. The electric energy meter node within the phase A line corresponding to the correlation coefficient being less than or equal to the preset coefficient is determined as the electric energy meter node within the phase A line of the current substation.

[0103] In some embodiments, the preset coefficient may be a fixed value, or the preset coefficient may be adaptively adjusted according to the station environment. For example, a larger preset coefficient may be set for a station with large load fluctuations, and a smaller preset coefficient may be set for a station with small load fluctuations.

[0104] In the technical solution provided in the embodiment of the present application, the correlation coefficient can comprehensively reflect the similarity of the voltage sequence in multiple dimensions such as amplitude, phase, and waveform, and effectively eliminate misjudgment caused by instantaneous interference or local anomalies. By calculating the correlation coefficient between the voltage sequence of each phase line in the substation and the voltage sequence of the electric energy meter node in the phase line, and screening out the target correlation coefficient greater than or equal to the preset coefficient, the ownership of the electric energy meter node is determined. This solution uses correlation analysis in statistics to quantify the degree of electrical correlation between the node and the phase line. Compared with the traditional judgment method based on a single feature or manual experience, it significantly improves the accuracy and robustness of node identification.

[0105] For example, the correlation coefficient may include a Pearson correlation coefficient. Pearson correlation, also known as product-moment correlation (or product-moment correlation), is a method for calculating linear correlation. Assuming there are two voltage sequences X and Y, and the number of voltages in both voltage sequences X and Y is N, then the Pearson correlation coefficient of the two voltage sequences X and Y is It can be calculated by any of the following formulas (1) to (4):

[0106] (1);

[0107] (2);

[0108] (3);

[0109] (4).

[0110] In the technical solution provided in the embodiment of the present application, by collecting the time-varying information of the voltage of each phase line and the electricity meter node in the substation, the voltage zero-crossing time and the voltage sequence are accurately determined, and based on this, the electricity meter nodes in the same phase line and the same substation are gradually screened out, thereby utilizing the strong correlation and regularity of the voltage characteristics to achieve accurate attribution judgment of the electricity meter nodes in the phase line and substation dimensions. Compared with the traditional method of relying on a single parameter or experience judgment, the accuracy and reliability of the node attribution judgment are significantly improved.

[0111] Figure 3 The third embodiment provides a method for identifying a topology of a station area based on a carrier communication network. The method is applied to a concentrator in a station area. Figure 3 Example compared to Figure 1 The difference between the embodiments is that S102 includes S1021 to S1022.

[0112] S1021. Using a carrier communication network, obtain the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation, the similarity of the signal-to-noise ratio sequence, and the signal attenuation.

[0113] In some embodiments, the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation is determined based on the sending time of the carrier signal sent by the concentrator in the substation using the carrier communication network and the receiving time of the carrier signal received by the electric energy meter nodes in the same phase line and the same substation.

[0114] For example, the difference between the receiving time and the sending time may be determined, and the difference may be multiplied by the signal propagation speed to obtain the distance between the concentrator and the electric energy meter node in the same phase line and the same substation.

[0115] In some embodiments, the similarity of the signal-to-noise ratio sequence is determined based on the signal-to-noise ratio sequence sent by the electric energy meter nodes in the same phase line and the same substation; wherein the signal-to-noise ratio sequence is obtained by the electric energy meter nodes measuring the carrier signal received in the carrier communication network.

[0116] Exemplarily, each electric energy meter node in the same phase line and the same substation can send a signal signal-to-noise ratio sequence to the concentrator. For example, for an electric energy meter node, the signal signal-to-noise ratio can be measured once every set time period, and the signal signal-to-noise ratios obtained in sequence within a certain time period can be determined as a signal signal-to-noise ratio sequence. Exemplarily, the concentrator can determine that different electric energy meter nodes correspond to different signal signal-to-noise ratio sequences based on the signal signal-to-noise ratio sequences sent by different electric energy meter nodes in the same phase line and the same substation. The different signal signal-to-noise ratio sequences include the same number of signal-to-noise ratios, and the different signal signal-to-noise ratio sequences correspond to the same acquisition time period. The similarity between the two signal signal-to-noise ratio sequences corresponding to each two electric energy meter nodes in the same phase line and the same substation can be determined as the similarity of the signal signal-to-noise ratio sequences.

[0117] Exemplarily, the carrier signal may be a measurement signal in a carrier communication network.

[0118] In some embodiments, the signal attenuation is determined based on the signal transmission strength of the carrier signal sent by the concentrator in the substation using the carrier communication network and the signal reception strength of the carrier signal sent by the electric energy meter node in the same phase line and the same substation.

[0119] The signal transmission strength of the carrier signal refers to the initial output signal power when the concentrator sends the carrier signal to the electric energy meter node through the carrier communication network. The signal reception strength of the carrier signal refers to the actual detected signal power when the electric energy meter node receives the carrier signal sent by the concentrator through the power line.

[0120] Exemplarily, the difference between the signal transmission strength and the signal reception strength may be determined as the signal attenuation magnitude.

[0121] Through the above method, the physical distance between the concentrator and the electricity meter node is calculated using the signal transmission time difference. Compared with the traditional estimation method based on signal strength, it effectively eliminates the errors caused by factors such as line impedance and environmental interference, making the topological relationship closer to the actual physical layout; by comparing the signal-to-noise ratio sequence of each node and identifying the similarity of the signal propagation path, the logical connection relationship between the nodes can be accurately judged; by calculating the attenuation rate by sending and receiving signal strength, the accuracy of determining the signal attenuation can be improved.

[0122] S1022: Determine the electric energy meter node in the lowest level cluster unit among the multiple cluster units based on the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation, the similarity of the signal-to-noise ratio sequence, and the signal attenuation.

[0123] In some embodiments, S1022 can be implemented in the following manner: determining the first affiliation relationship between the electric energy meter nodes in the same phase line and the same substation and the lowest-level cluster units based on the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation; adjusting the first affiliation relationship based on the similarity of the signal-to-noise ratio sequence to obtain the second affiliation relationship between the electric energy meter nodes in the same phase line and the same substation and the lowest-level cluster units; adjusting the second affiliation relationship based on the signal attenuation size to obtain the electric energy meter nodes in the lowest-level cluster units among multiple cluster units.

[0124] Exemplarily, the electric energy meter nodes in the same phase line and the same substation can be clustered according to the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation to obtain multiple clustering results, each clustering result corresponds to a cluster unit of the lowest level, and based on the multiple clustering results, the cluster units of the lowest level to which the electric energy meter nodes in the same phase line and the same substation belong are determined.

[0125] Exemplarily, if the similarity between two signal-to-noise ratio sequences is higher, then the probability that the two electric energy meter nodes corresponding to the two signal-to-noise ratio sequences belong to the same lowest-level cluster unit is higher. For example, through the above-mentioned first attribution relationship, the similarity of the two signal signal-to-noise ratio sequences corresponding to every two electric energy meter nodes in the first attribution relationship can be obtained. If the similarity is higher than the similarity threshold, it indicates that the attribution relationship of every two electric energy meter nodes is accurate. If, in the first attribution relationship, the similarity between the signal signal-to-noise ratio sequence corresponding to the first electric energy meter and the signal signal-to-noise ratio sequence corresponding to the second electric energy meter is lower than the similarity threshold, but the similarity between the signal signal-to-noise ratio sequence corresponding to the first electric energy meter and the signal signal-to-noise ratio sequences corresponding to most other electric energy meters is higher than the similarity threshold, while the similarity between the signal signal-to-noise ratio sequence corresponding to the second electric energy meter and the signal signal-to-noise ratio sequences corresponding to most other electric energy meters is still lower than the similarity threshold, it indicates that the second electric energy meter is incorrectly classified. If the similarity between the signal signal-to-noise ratio sequence corresponding to the second electric energy meter and the signal signal-to-noise ratio sequences corresponding to most electric energy meters in another lowest-level cluster unit is higher than the similarity threshold, the second electric energy meter should be adjusted to the classification of another lowest-level cluster unit.

[0126] For example, if the attenuation values ​​of two signals are closer, it indicates that the probability that the two electric energy meter nodes corresponding to the two signal attenuation values ​​belong to the same lowest-level cluster unit is higher. For example, through the above-mentioned second attribution relationship, the two signal attenuation sizes corresponding to every two electric energy meter nodes in the second attribution relationship can be obtained. If the absolute value of the difference between the two signal attenuation sizes is lower than the attenuation difference threshold, it indicates that the attribution relationship of every two electric energy meter nodes is accurate. If in the second attribution relationship, the absolute value of the difference between the signal attenuation size corresponding to the third electric energy meter and the signal attenuation size corresponding to the fourth electric energy meter is higher than the attenuation difference threshold, but the absolute value of the difference between the signal attenuation size corresponding to the third electric energy meter and the signal attenuation sizes corresponding to most other electric energy meters is lower than the attenuation difference threshold, and the absolute value of the difference between the signal attenuation size corresponding to the fourth electric energy meter and the signal attenuation sizes corresponding to most other electric energy meters is higher than the attenuation difference threshold, it indicates that the classification of the fourth electric energy meter is incorrect. If the absolute value of the difference between the signal attenuation size corresponding to the fourth electric energy meter and the signal attenuation sizes corresponding to most electric energy meters in another lowest-level cluster unit is lower than the attenuation difference threshold, the fourth electric energy meter should be adjusted to the classification of another lowest-level cluster unit.

[0127] Through the above method, by integrating the physical distance between the concentrator and the electricity meter node, the signal-to-noise ratio sequence similarity and the signal attenuation size multi-dimensional information, the affiliation relationship between the electricity meter node and the lowest-level cluster unit is constructed and iteratively optimized in sequence. This scheme realizes the high-precision determination of the topological affiliation of the electricity meter nodes in the substation area. The physical distance lays the foundation for spatial division, ensuring that the nodes are preliminarily clustered according to the distance from the line. The signal-to-noise ratio sequence similarity corrects the logical misjudgment caused by spatial distance by analyzing the signal interference pattern, and accurately identifies the nodes on the same path. The signal attenuation size further eliminates the affiliation deviation caused by abnormal factors such as poor line contact and aging. The three-layer mechanism is progressive, forming a three-dimensional verification system from spatial layout to logical path to line status, which greatly improves the node affiliation accuracy compared with the traditional single parameter method, significantly reduces the distortion of the topology map caused by node mismatch, and thus improves the accuracy of the determined substation area topology map.

[0128] In the technical solution provided in the embodiment of the present application, multi-dimensional data such as the distance between the concentrator and the electric energy meter node, the signal-to-noise ratio sequence similarity, and the signal attenuation size are collected through the carrier communication network, and the electric energy meter nodes in the lowest-level cluster unit are determined based on this. The solution constructs a precise identification mechanism for substation nodes that integrates physical topology, signal characteristics, and line status. This multi-parameter collaborative judgment mode can greatly reduce the node attribution error rate and significantly improve the accuracy of substation topology modeling.

[0129] Figure 4 The fourth embodiment provides a method for identifying a topology of a station area based on a carrier communication network. The method is applied to a concentrator in a station area. Figure 4 Example compared to Figure 1 The difference between the embodiments is that S103 includes S1031 to S1032.

[0130] S1031. Determine the distance between each non-lowest-level cluster unit and the cluster unit of the next level based on the sending time of the carrier signal by the monitoring device corresponding to each non-lowest-level cluster unit and the receiving time of the carrier signal by the monitoring device corresponding to the cluster unit of the next level of each non-lowest-level cluster unit.

[0131] Exemplarily, the monitoring device corresponding to each non-lowest level cluster unit can send a carrier signal and record the sending time of the carrier signal, and the monitoring device corresponding to the cluster unit of the next level records the receiving time of the carrier signal, and the monitoring device corresponding to each non-lowest level cluster unit sends the receiving time, and the monitoring device corresponding to each non-lowest level cluster unit can send the sending time and the receiving time to the concentrator.

[0132] The concentrator can determine the distance between each non-lowest-level cluster unit and the next-level cluster unit according to each pair of sending time and receiving time and according to the signal propagation speed.

[0133] S1032: Determine the levels of the plurality of cluster units according to the distance between each non-lowest level cluster unit and the next level cluster unit.

[0134] Among them, because the concentrator receives the transmission time of the carrier signal sent by the monitoring device corresponding to each non-lowest level cluster unit, the monitoring device corresponding to the cluster unit of the next level obtains the reception time of the carrier signal, so that the concentrator can obtain all cluster units in the station area and the distance between each non-lowest level cluster unit and the cluster unit of the next level, and then determine the level of the cluster units in the station area through the minimum spanning tree algorithm. For example, an undirected graph model G can be constructed, where G=(V,E), V represents the vertex set, that is, the set of all cluster units, and E represents the distance set between each non-lowest level cluster unit and the cluster unit of the next level. The minimum spanning tree algorithm can be used to generate a minimum spanning tree so that all vertices are connected by the least number of edges, thereby obtaining the level of multiple cluster units.

[0135] The hierarchy of the plurality of cluster units includes a connection relationship between each cluster unit in a non-lowest level and a cluster unit in a next level.

[0136] In the technical solution provided in the embodiment of the present application, the distance between the non-lowest level cluster unit and the next level cluster unit is accurately calculated by the time difference between the sending and receiving of the carrier signal, and the hierarchy and connection relationship of multiple cluster units are determined based on this, which effectively solves the technical problem that the traditional substation topology structure identification relies on manual mapping or a single signal feature that is prone to errors. Through the quantitative conversion of time difference and distance, the objective and automatic judgment of the hierarchical relationship of cluster units is achieved. Compared with empirical judgment or single signal strength analysis, the accuracy of hierarchical identification is greatly improved, and the constructed hierarchical topology model intuitively presents the logical connection between each cluster unit in the power network, and then intuitively presents the multi-level affiliation of the distribution room cluster unit, the branch box cluster unit, and the meter box cluster unit, thereby improving the accuracy of the hierarchy of the determined multiple cluster units.

[0137] Figure 5 FIG. 1 is a flow chart of a method for determining a corresponding relationship between incoming and outgoing lines of a branch box cluster unit in a plurality of cluster units in some embodiments. Figure 5 The embodiment is a further explanation of S104. The method is applied to a concentrator in a station area. The method includes S1041 to S1046.

[0138] S1041. Determine the power characteristic sequence of each branch box according to the power data sent by the monitoring device corresponding to each branch box in each branch box cluster unit at fixed time intervals.

[0139] The upper cluster unit of each branch box cluster unit is the power distribution room cluster unit, and the lower cluster unit is the meter box cluster unit. However, each branch box cluster unit corresponds to at least one branch box, so the outgoing and incoming line correspondence relationship of each branch box cluster unit also needs to be obtained. For example, for a branch box cluster unit, it includes four branch boxes, the lower level of branch box 1 is connected to branch box 2 and branch box 3, the lower level of branch box is connected to branch box 4, the upper level of branch box 1 is connected to the power distribution room cluster unit, the lower level of branch box 2 is connected to meter box cluster unit 1, and the lower level of branch box 3 is connected to meter box cluster unit 2. Then, the connection relationship between the branch boxes, the connection relationship between the branch box and the power distribution room cluster unit, and the connection relationship between the branch box and the meter box cluster unit are determined as the outgoing and incoming line correspondence relationship of the branch box cluster units in multiple cluster units.

[0140] For example, the monitoring devices corresponding to branch boxes 1 to 4 can all send power data, and the power characteristic sequence of each branch box can be the power data sent within a set period arranged according to time, and the number of power data in the power characteristic sequence of different branch boxes is the same.

[0141] S1042. Determine the power characteristic sequence of the power distribution room unit and the power characteristic sequence of each meter box unit based on the power data sent at fixed time intervals by the monitoring devices corresponding to the power distribution room unit above each branch box cluster unit and the multiple meter box units below.

[0142] Through the hierarchy of the above-mentioned multiple cluster units, the upper distribution room unit and the lower multiple meter box units of each branch box cluster unit can be obtained, so that the power data sent by the monitoring devices corresponding to the upper distribution room unit and the lower multiple meter box units at fixed time intervals can be obtained.

[0143] Among them, the power characteristic sequence of the distribution room unit and the power characteristic sequence of each meter box unit are also the time arrangement of the power data sent within the set time period. The number of power data in the power characteristic sequence of the distribution room unit, the power characteristic sequence of each meter box unit and the power characteristic sequence of the branch box is the same.

[0144] S1043. Determine the branch box connected to the distribution room unit according to the power characteristic sequence of each branch box and the power characteristic sequence of the distribution room unit.

[0145] In some embodiments, the standard deviation between the power distribution room unit characteristic sequence and the power distribution room unit characteristic sequence can be obtained, and the branch box with the smallest standard deviation can be determined as the branch box connected to the power distribution room unit. In other embodiments, the standard deviation between the power distribution room unit characteristic sequence and the power distribution room unit characteristic sequence can be obtained, and at least one branch box with a standard deviation less than a standard deviation threshold can be determined as the branch box connected to the power distribution room unit.

[0146] S1044. Determine the connection relationship between the branch boxes according to the branch boxes connected to the power distribution room unit and the power characteristic sequence of each branch box.

[0147] For example, if a branch box is connected to a branch box, the power characteristic sequences of the two branch boxes are the same or differ very little; if multiple branch boxes are connected to a branch box, the power characteristic sequence of one branch box is the same as or differs very little from the sum of the power characteristic sequences of multiple branch boxes. Based on this principle, the connection relationship of each branch box can be determined according to the branch box connected to the distribution room unit and the power characteristic sequence of each branch box.

[0148] S1045. Determine the branch box connected to each meter box unit based on the power characteristic sequence of the last branch box in the connection relationship of each branch box and the power characteristic sequence of each meter box unit.

[0149] In some embodiments, the standard deviation between the power characteristic sequence of each last-level branch box and the power characteristic sequence of each meter box unit can be obtained, and at least one meter box with a standard deviation less than or equal to the standard deviation threshold is determined as at least one meter box connected to each last-level branch box, thereby obtaining the branch box connected to each meter box unit.

[0150] S1406: Determine the corresponding relationship between the incoming and outgoing lines of the branch box cluster units in the plurality of cluster units according to the branch box connected to the power distribution room unit, the connection relationship between the branch boxes, and the branch boxes connected to the meter box units.

[0151] In the technical solution provided by the embodiment of the present application, by collecting and analyzing the power characteristic sequences of the distribution room units, branch box cluster units and meter box units, a set of power network connection relationship derivation systems from macro to micro are constructed. Based on the power data collected at fixed time intervals, sequence analysis is used to mine the correlation of power transmission between each unit, accurately identifying the connection relationship between the distribution room and the branch box, the branch box and the branch box, and the branch box and the meter box, avoiding the problems of wrong connection and missed connection that are prone to occur in traditional manual mapping or single signal judgment. Through step-by-step deduction, the corresponding relationship between the incoming and outgoing lines of the branch box cluster units is finally determined, forming a complete power topology logic chain, which greatly improves the accuracy of identifying the power network connection relationship.

[0152] In some embodiments, phase identification is the basis of topology identification. Since the HPLC carrier signal can be transmitted across the phase line through spatial coupling. Therefore, before starting topology identification, it is very necessary for us to perform node phase line identification first. Phase identification principle: The local communication module of the concentrator at the starting end of the substation can collect the voltage-time information of the a-phase outgoing line, the b-phase outgoing line, and the c-phase outgoing line at the starting end of the three-phase voltage power supply of the substation, and obtain the voltage zero-crossing time of the a-phase line, the b-phase line, and the c-phase line at the starting end of the three-phase voltage power supply of the substation. In the same substation, the voltage zero-crossing time of each node is compared with the voltage zero-crossing time of the a-phase line, the b-phase line, and the c-phase line. According to the principle that the voltage zero-crossing time between nodes on the same phase line is the same and the voltage zero-crossing time between nodes on non-same phase lines is different, the phase line where each node is located is identified.

[0153] In some embodiments, substation identification is a prerequisite for topology identification. If there are errors in the substation file, these erroneous nodes will have a significant impact on the computational complexity and accuracy of topology identification. For example, in the subsequent calculation of the power characteristic similarity method, the power consumption of these nodes cannot actually be included in the power consumption of the substation's total meter. Therefore, their power characteristics will inevitably cause errors in the power characteristic similarity method calculation. Therefore, before topology identification, it is very necessary to clarify the household-transformer relationship in the substation (that is, the relationship between the electricity meter node and the transformer).

[0154] Substation identification works by comparing the voltage-time information of each phase line of the concentrator with the voltage-time information of the same-phase line nodes. Based on the principle that the voltage-time information of the same-phase line nodes in the same substation is highly correlated, while the voltage-time information of different-phase line nodes in different substations is less correlated, the node belonging to the same substation as the concentrator is inferred. For example, the correlation calculation method uses the Pearson correlation coefficient method.

[0155] In some embodiments, the main clustering manifestations (external characteristics and manifestations of the clustering process or clustering results) at the distribution network site are distribution room cluster units, branch box cluster units, and meter box cluster units. In the substation topology identification, cluster unit affiliation identification is required for all nodes.

[0156] In the cluster identification method, parameters such as distance, similarity of PLC / RF signal noise ratio sequences, and PLC / RF signal attenuation between nodes can be used to identify whether nodes belong to the same cluster unit, thereby dividing different cluster units.

[0157] Distance is primarily determined by the proximity of nodes within the distribution room cluster, branch box cluster, and meter box cluster. These nodes are typically very close together, with no cluster being particularly large. (Of course, special circumstances may exist on-site, such as two meter boxes being too close to be distinguished by distance and initially classified as the same cluster. This can be addressed using a large-scale data analysis of the meter box switch power series and the node power series within the cluster.) Distance measurement uses ranging to calculate the distance between nodes. The ranging formula is: S = V × T. Where S is the distance in meters; V is the speed, or the speed of electrons traveling through the circuit; and T is the time, or the transmission time from the sending node to the receiving node, representing the time difference between the sending and receiving signals at the sending and receiving nodes. To improve ranging accuracy, bidirectional ranging and multiple ranging methods can be used.

[0158] In some embodiments, distance measurement can be performed on nodes in the same area and phase. This ensures that the distances between these nodes are sufficiently accurate. Branch box nodes and meter box nodes are also selected as key nodes. Distance measurement is then performed between each of these key nodes to obtain actual line length information. The distance measurement method uses the distance measurement formula described above for calculation. Based on the distance measurement results, the minimum spanning tree method is used for hierarchical identification. The input of the minimum spanning tree algorithm is an undirected graph G = (V, E), and the output is a minimum weight tree (i.e., the minimum spanning tree described above).

[0159] In some embodiments, a power signature similarity method is used to calculate the correspondence between outgoing and incoming lines. Similarity calculations are performed between the distribution room switches and branch box switches, and between the branch box switches and meter box switches, to determine the parent-child relationship between branch lines. At fixed intervals (e.g., 15-minute intervals), each switch simultaneously collects and stores power usage, forming a power signature sequence. The power signature matching values ​​between each parent node switch and each child node switch are calculated to ultimately determine the parent-child relationship.

[0160] For example, the power characteristic sequence collected by switch A is a(i), and the power characteristic sequence collected by switch B is b(i); then the power characteristic matching feature S (the standard deviation of the difference sequence) is: . n is the number of power data in the sequence.

[0161] Based on the same inventive concept, the embodiments of the present application also provide a carrier communication network-based substation topology identification device for implementing the above-mentioned carrier communication network-based substation topology identification method. The implementation solution provided by the device is similar to the implementation solution described in the above-mentioned method. Therefore, the specific limitations of one or more embodiments of the carrier communication network-based substation topology identification device provided below can be found in the above-mentioned limitations of the carrier communication network-based substation topology identification method, and will not be repeated here.

[0162] In an exemplary embodiment, Figure 6 A schematic diagram of a structure of a station area topology identification device based on a carrier communication network provided in some embodiments, such as Figure 6 As shown, the carrier communication network-based station area topology identification device 600 includes:

[0163] Phase line substation area determination module 601, used to determine the electric energy meter nodes in the same phase line and the same substation area based on the collected information on the change of the voltage of each phase line in the substation area over time and the information on the change of the voltage over time sent by each electric energy meter node;

[0164] The cluster unit determination module 602 is configured to determine the electric energy meter node in the lowest level cluster unit among the multiple cluster units based on the distance between the concentrator and the electric energy meter node in the same phase line and the same substation area obtained using the carrier communication network;

[0165] The cluster level determination module 603 is configured to perform level identification on the plurality of cluster units using a carrier communication network to obtain levels of the plurality of cluster units;

[0166] Incoming and outgoing line determination module 604, configured to determine the correspondence between incoming and outgoing lines of branch box cluster units in the multiple cluster units based on the power data transmitted at regular time intervals by the monitoring device corresponding to each branch box cluster unit in the multiple cluster units, and the power data transmitted at regular time intervals by the monitoring devices corresponding to the power distribution room unit above and the multiple meter box units below each branch box cluster unit;

[0167] The forming module 605 is used to form a substation topology map according to the electric energy meter nodes in the same phase line and the same substation, the electric energy meter nodes in each cluster unit, the hierarchy of multiple cluster units, and the correspondence between the incoming and outgoing lines.

[0168] In some embodiments, the phase line substation determination module 601 includes a feature determination unit, a phase line determination unit, and a phase line substation determination unit. The feature determination unit is used to determine the zero-crossing time of the voltage in each phase line in the substation, the zero-crossing time of the voltage in each electric meter node, the voltage sequence of each phase line in the substation, and the voltage sequence of each electric meter node based on the change information of the voltage of each phase line in the substation over time and the change information of the voltage of each electric meter node over time; the phase line determination unit is used to determine the electric meter nodes in the same phase line according to the zero-crossing time of the voltage in each phase line in the substation and the zero-crossing time of the voltage in each electric meter node; the phase line substation determination unit is used to determine the electric meter nodes in the same phase line and the same substation based on the voltage sequence of each phase line in the substation and the voltage sequence of the electric meter nodes in each phase line.

[0169] In some embodiments, the phase line substation determination unit is also used to determine the correlation coefficient between the voltage sequence of each phase line in the substation and the voltage sequence of the electric energy meter node in each phase line; determine a target correlation coefficient greater than or equal to a preset coefficient from the correlation coefficient; and determine the electric energy meter node corresponding to the target correlation coefficient as the electric energy meter node in the same phase line and the same substation.

[0170] In some embodiments, the cluster unit determination module 602 includes a feature determination unit and a cluster unit determination unit. The feature determination unit is used to use a carrier communication network to obtain the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation, the similarity of the signal signal-to-noise ratio sequence, and the signal attenuation size; the cluster unit determination unit is used to determine the electric energy meter nodes in the lowest-level cluster unit among multiple cluster units based on the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation, the similarity of the signal signal-to-noise ratio sequence, and the signal attenuation size.

[0171] In some embodiments, the feature determination unit is also used to determine the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation based on the sending time of the carrier signal sent by the concentrator in the substation using the carrier communication network and the receiving time of the carrier signal received by the electric energy meter nodes in the same phase line and the same substation; determine the similarity of the signal signal-to-noise ratio sequence based on the signal signal-to-noise ratio sequence sent by the electric energy meter nodes in the same phase line and the same substation; wherein the signal signal-to-noise ratio sequence is obtained by the electric energy meter node measuring the carrier signal received in the carrier communication network; determine the signal attenuation based on the signal sending strength of the carrier signal sent by the concentrator in the substation using the carrier communication network and the signal receiving strength of the carrier signal sent by the electric energy meter nodes in the same phase line and the same substation.

[0172] In some embodiments, the cluster unit determination unit is also used to determine the first affiliation relationship between the electric energy meter nodes in the same phase line and the same substation and the cluster units of each lowest level based on the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation; adjust the first affiliation relationship based on the similarity of the signal-to-noise ratio sequence to obtain the second affiliation relationship between the electric energy meter nodes in the same phase line and the same substation and the cluster units of each lowest level; adjust the second affiliation relationship based on the signal attenuation size to obtain the electric energy meter nodes in the cluster units of the lowest level among multiple cluster units.

[0173] In some embodiments, the cluster level determination module 603 includes a distance determination unit and a cluster level determination unit. The distance determination unit is used to determine the distance between each non-lowest level cluster unit and the cluster unit of the next level based on the sending time of the carrier signal sent by the monitoring device corresponding to each non-lowest level cluster unit and the receiving time of the carrier signal received by the monitoring device corresponding to the cluster unit of the next level of each non-lowest level cluster unit; the cluster level determination unit is used to determine the level of multiple cluster units based on the distance between each non-lowest level cluster unit and the cluster unit of the next level.

[0174] In some embodiments, the incoming and outgoing line determination module 604 includes an electric quantity characteristic sequence determination unit, a connection determination unit, and an incoming and outgoing line determination unit; wherein the electric quantity characteristic sequence determination unit is used to determine the electric quantity characteristic sequence of each branch box according to the electric quantity data sent at fixed time intervals by the monitoring device corresponding to each branch box in each branch box cluster unit; determine the electric quantity characteristic sequence of the distribution room unit and the electric quantity characteristic sequence of each meter box unit according to the electric quantity data sent at fixed time intervals by the monitoring device corresponding to the upper distribution room unit and the lower multiple meter box units of each branch box cluster unit; the connection determination unit is used to determine the electric quantity characteristic sequence of the distribution room unit and the electric quantity characteristic sequence of each meter box unit based on the electric quantity data sent at fixed time intervals by the monitoring device corresponding to the upper distribution room unit and the lower multiple meter box units of each branch box cluster unit; According to the power characteristic sequence of each branch box and the power characteristic sequence of the distribution room unit, the branch box connected to the distribution room unit is determined; according to the power characteristic sequence of the branch box connected to the distribution room unit and each branch box, the connection relationship of each branch box is determined; according to the power characteristic sequence of the last-level branch box in the connection relationship of each branch box and the power characteristic sequence of each meter box unit, the branch box connected to each meter box unit is determined; the incoming and outgoing line determination unit is used to determine the corresponding relationship between the incoming and outgoing lines of the branch box cluster units in multiple cluster units according to the branch box connected to the distribution room unit, the connection relationship of each branch box and the branch box connected to each meter box unit.

[0175] The description of the above device embodiment is similar to the description of the above method embodiment and has similar beneficial effects as the method embodiment. For technical details not disclosed in the device embodiment of this application, please refer to the description of the method embodiment of this application for understanding.

[0176] Each module in the aforementioned carrier communication network-based substation topology identification device can be implemented in whole or in part through software, hardware, or a combination thereof. Each module can be embedded in or independent of a processor in a concentrator in hardware form, or can be stored in a memory in the concentrator in software form, so that the processor can call and execute the corresponding operations of each module.

[0177] In an exemplary embodiment, Figure 7A schematic diagram of the structure of a concentrator provided in some embodiments includes a processor, memory, an input / output interface, a communication interface, a display unit, and an input device. The processor, memory, and input / output interface are connected via a system bus, while the communication interface, display unit, and input device are connected to the system bus via the input / output interface. The processor of the concentrator provides computing and control capabilities. The memory of the concentrator includes a non-volatile storage medium and internal memory. The non-volatile storage medium stores an operating system and computer programs. The internal memory provides an environment for the operating system and computer programs stored in the non-volatile storage medium. The input / output interface of the concentrator is used to exchange information between the processor and external devices. The communication interface of the concentrator is used to communicate with external terminals via wired or wireless communication. The wireless communication method can be implemented via wireless fidelity (Wi-Fi), mobile cellular networks, near-field communication (NFC), or other technologies. When executed by the processor, the computer program implements a method for identifying a substation topology based on a carrier communication network. The display unit of the concentrator forms a visual display and can be a display screen, a projection device, or a virtual reality imaging device. The display screen can be a liquid crystal display screen or an electronic ink display screen, and the input device of the concentrator can be a touch layer covering the display screen, or a button, trackball or touchpad set on the concentrator housing, or an external keyboard, touchpad or mouse.

[0178] Those skilled in the art will understand that Figure 7 The structure shown in the figure is only a block diagram of a part of the structure related to the solution of the present application, and does not constitute a limitation on the concentrator to which the solution of the present application is applied. The specific concentrator may include more or fewer components than shown in the figure, or combine certain components, or have a different component arrangement.

[0179] For example, the concentrator includes a memory and a processor, the memory stores a computer program, and the processor implements the steps of the method of any of the above embodiments when executing the computer program.

[0180] In one embodiment, a computer-readable storage medium is provided, and when a computer program is executed by a processor, the computer program implements the steps of the method provided in any of the above embodiments.

[0181] In one embodiment, a computer program product is provided, including a computer program. When the computer program is executed by a processor, the steps of the method provided in any of the above embodiments are implemented.

[0182] Those skilled in the art will understand that all or part of the processes in the above-mentioned embodiment methods can be implemented by instructing related hardware through a computer program. The computer program can be stored in a non-volatile computer-readable storage medium. When the computer program is executed, it can include the processes of the embodiments of the above-mentioned methods.

[0183] The processor, each functional module or each functional unit in any embodiment of the present application may include any one or more of the following integrations: a general-purpose processor, an application-specific integrated circuit (ASIC), a digital signal processor (DSP), a digital signal processing device (DSPD), a programmable logic device (PLD), a field programmable gate array (FPGA), a central processing unit (CPU), a graphics processing unit (GPU), an embedded neural network processing unit (NPU), a controller, a microcontroller, a microprocessor, a programmable logic device, a discrete gate or transistor logic device, a discrete hardware component, a data processing logic based on quantum computing, an artificial intelligence (AI) processor, etc. The general-purpose processor may be a microprocessor or the processor may also be any conventional processor, etc.

[0184] The memory or computer-readable storage medium in any embodiment of the present application may include at least one of a non-volatile memory and a volatile memory. Non-volatile memory includes the integration of one or more of the following: Read Only Memory (ROM), Programmable Read-Only Memory (PROM), Erasable Programmable Read-Only Memory (EPROM), Electrically Erasable Programmable Read-Only Memory (EEPROM), Ferromagnetic Random Access Memory (FRAM), Flash Memory, Magnetic Surface Storage, Optical Disc, Compact Disc Read-Only Memory (CD-ROM), Magnetic Tape, Floppy Disk, Flash Memory, Optical Storage, High-density Embedded Non-volatile Memory, Resistive Random Access Memory (ReRAM), Magnetoresistive Random Access Memory (MRAM), Ferroelectric Random Access Memory (FRAM), Phase Change Memory (PCM), Graphene Memory, Volatile Memory, etc. Volatile memory includes one or more of the following: random access memory (RAM) or external cache memory. By way of illustration and not limitation, RAM can come in various forms, such as static random access memory (SRAM) or dynamic random access memory (DRAM).

[0185] The technical features of the above embodiments can be combined arbitrarily. In order to make the description concise, not all possible combinations of the technical features in the above embodiments are described. However, as long as there is no contradiction in the combination of these technical features, they should be considered to be within the scope of this application.

[0186] The above-described embodiments merely represent several implementation methods of the present application. While the descriptions are relatively specific and detailed, they should not be construed as limiting the scope of the present application. It should be noted that a person of ordinary skill in the art may make various modifications and improvements without departing from the spirit of the present application, and these modifications and improvements fall within the scope of protection of the present application. Therefore, the scope of protection of the present application shall be determined by the appended claims.

Claims

1. A method for identifying station area topology based on a carrier communication network, characterized in that: The method is applied to a concentrator in a station area, and the method includes: Determine the electric energy meter nodes in the same phase line and the same substation based on the collected information on the change of the voltage of each phase line in the substation over time and the information on the change of the voltage sent by each electric energy meter node over time; Determining an electric energy meter node in a lowest-level cluster unit among a plurality of cluster units based on the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation obtained using the carrier communication network; Using the carrier communication network to perform hierarchical identification on the plurality of cluster units to obtain hierarchies of the plurality of cluster units; Determine the correspondence between the incoming and outgoing lines of the branch box cluster units in the multiple cluster units based on the power data sent at fixed time intervals by the monitoring device corresponding to each branch box cluster unit in the multiple cluster units, and the power data sent at fixed time intervals by the monitoring devices corresponding to the power distribution room unit above and the multiple meter box units below each branch box cluster unit; A substation topology map is formed according to the electric energy meter nodes in the same phase line and the same substation, the electric energy meter nodes in each cluster unit, the hierarchy of the multiple cluster units, and the correspondence between the outgoing and incoming lines.

2. The method according to claim 1, characterized in that The step of determining the electric energy meter nodes in the same phase line and the same substation according to the collected information on the change of the voltage of each phase line in the substation over time and the information on the change of the voltage sent by each electric energy meter node over time includes: Determine, based on information on changes in the voltage of each phase line in the substation over time and information on changes in the voltage of each electric energy meter node over time, a zero-crossing time of the voltage in each phase line in the substation, a zero-crossing time of the voltage in each electric energy meter node, a voltage sequence of each phase line in the substation, and a voltage sequence of each electric energy meter node; Determining the electric energy meter nodes within the same phase line according to the zero-crossing time of the voltage in each phase line in the substation and the zero-crossing time of the voltage in each electric energy meter node; The electric energy meter nodes in the same phase line and the same substation are determined according to the voltage sequence of each phase line in the substation and the voltage sequence of the electric energy meter nodes in each phase line.

3. The method according to claim 2, characterized in that The step of determining the electric energy meter nodes in the same phase line and the same substation according to the voltage sequence of each phase line in the substation and the voltage sequence of the electric energy meter nodes in each phase line comprises: Determining the correlation coefficient between the voltage sequence of each phase line in the substation and the voltage sequence of the electric energy meter node in each phase line; determining a target correlation coefficient greater than or equal to a preset coefficient from the correlation coefficients; The electric energy meter node corresponding to the target correlation coefficient is determined to be the electric energy meter node in the same phase line and the same substation.

4. The method according to any one of claims 1 to 3, characterized in that The step of determining the electric energy meter node in the lowest-level cluster unit among the plurality of cluster units based on the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation obtained by using the carrier communication network includes: Using the carrier communication network, obtaining the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation, the similarity of the signal-to-noise ratio sequence, and the signal attenuation; The electric energy meter node in the lowest level cluster unit among the multiple cluster units is determined according to the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation, the similarity of the signal-to-noise ratio sequence, and the signal attenuation.

5. The method according to claim 4, characterized in that The method of using the carrier communication network to obtain the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation, the similarity of the signal-to-noise ratio sequence, and the signal attenuation includes: Determine the distance between the concentrator and the electric energy meter nodes in the same phase line and the same area based on the time when the concentrator in the area sends the carrier signal using the carrier communication network and the time when the electric energy meter nodes in the same phase line and the same area receive the carrier signal; Determining the similarity of the signal-to-noise ratio sequences based on the signal-to-noise ratio sequences sent by the electric energy meter nodes in the same phase line and the same substation; wherein the signal-to-noise ratio sequences are obtained by the electric energy meter nodes by measuring the carrier signals received in the carrier communication network; The signal attenuation is determined based on the signal transmission strength of the carrier signal sent by the concentrator in the substation using the carrier communication network and the signal reception strength of the carrier signal sent by the electric energy meter node in the same phase line and the same substation.

6. The method according to claim 4, characterized in that The determining, based on the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation, the similarity of the signal-to-noise ratio sequences, and the signal attenuation, of the electric energy meter nodes in the lowest level of the multiple cluster units includes: Determining, based on the distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation, a first affiliation relationship between the electric energy meter nodes in the same phase line and the same substation and each of the lowest-level cluster units; Adjusting the first affiliation relationship according to the similarity of the signal-to-noise ratio sequence to obtain a second affiliation relationship between the electric energy meter nodes in the same phase line and the same substation and each of the lowest-level cluster units; The second affiliation relationship is adjusted according to the signal attenuation magnitude to obtain the electric energy meter node in the lowest-level cluster unit among the multiple cluster units.

7. The method according to any one of claims 1 to 3, characterized in that The performing hierarchical identification on the plurality of cluster units to obtain the hierarchies of the plurality of cluster units includes: Determining the distance between each non-lowest-level cluster unit and the cluster unit at the next level based on a transmission time of a carrier signal by a monitoring device corresponding to each non-lowest-level cluster unit and a reception time of the carrier signal by a monitoring device corresponding to a cluster unit at a next level below each non-lowest-level cluster unit; The levels of the plurality of cluster units are determined according to the distance between each of the non-lowest level cluster units and the cluster unit of the next level.

8. The method according to any one of claims 1 to 3, characterized in that The determining of the correspondence between the incoming and outgoing lines of the branch box cluster units in the multiple cluster units based on the power data sent at fixed time intervals by the monitoring device corresponding to each branch box cluster unit in the multiple cluster units and the power data sent at fixed time intervals by the monitoring devices corresponding to the power distribution room unit above and the multiple meter box units below each branch box cluster unit includes: Determine the power characteristic sequence of each branch box according to the power data sent by the monitoring device corresponding to each branch box in each branch box cluster unit at the fixed time interval; Determine the power characteristic sequence of the power distribution room unit and the power characteristic sequence of each meter box unit according to the power data sent by the monitoring devices corresponding to the power distribution room unit above each branch box cluster unit and the multiple meter box units below using the fixed time interval; Determine the branch box connected to the power distribution room unit according to the power characteristic sequence of each branch box and the power characteristic sequence of the power distribution room unit; Determine the connection relationship of each branch box according to the branch box connected to the power distribution room unit and the power characteristic sequence of each branch box; Determining the branch box connected to each of the meter box units based on the power characteristic sequence of the last branch box in the connection relationship of each of the branch boxes and the power characteristic sequence of each of the meter box units; The correspondence between the incoming and outgoing lines of the branch box cluster units in the plurality of cluster units is determined according to the branch box connected to the power distribution room unit, the connection relationship between the branch boxes, and the branch boxes connected to the meter box units.

9. A device for identifying substation topology based on a carrier communication network, characterized in that: The area topology identification device includes: Phase line substation area determination module, used to determine the electric energy meter nodes in the same phase line and the same substation area based on the collected information on the change of the voltage of each phase line in the substation area over time and the information on the change of the voltage over time sent by each electric energy meter node; a cluster unit determination module, configured to determine an electric energy meter node in a lowest-level cluster unit among the plurality of cluster units based on a distance between the concentrator and the electric energy meter nodes in the same phase line and the same substation area obtained using the carrier communication network; a cluster level determination module, configured to perform level identification on the plurality of cluster units using the carrier communication network to obtain levels of the plurality of cluster units; an incoming and outgoing line determination module, configured to determine the corresponding relationship between the incoming and outgoing lines of the branch box cluster units in the multiple cluster units based on the power data sent at fixed time intervals by the monitoring device corresponding to each branch box cluster unit in the multiple cluster units, and the power data sent at fixed time intervals by the monitoring devices corresponding to the power distribution room unit above and the multiple meter box units below each branch box cluster unit; A forming module is used to form a substation topology map according to the electric energy meter nodes in the same phase line and the same substation, the electric energy meter nodes in each cluster unit, the hierarchy of the multiple cluster units and the corresponding relationship between the outgoing and incoming lines.

10. A concentrator comprising a memory and a processor, wherein the memory stores a computer program, characterized in that: When the processor executes the computer program, the steps of the method according to any one of claims 1 to 8 are implemented.

Images