Power distribution area management and control method based on multi-loop monitoring device and edge computing node

Abstract

The invention relates to a power distribution area management and control method based on a multi-loop monitoring device and an edge computing node. The method is applied to a multi-loop monitoring device in an edge computing node of a power distribution area. The method comprises the following steps: acquiring current impedance data of each power distribution line in the power distribution area under different preset frequencies; controlling injection equipment deployed in the target distribution line to inject a preset electric signal to the target distribution line; monitoring equipment deployed in each remaining distribution line is controlled to receive a preset electric signal, and current propagation information between the remaining distribution lines and the target distribution line is obtained; generating a current topological structure of the power distribution area according to the current impedance data of each power distribution line under different preset frequencies and the current propagation information between different residual power distribution lines and the target power distribution line; and managing and controlling the power distribution area according to the current topological structure. By adopting the method, cooperative management and control among multiple power distribution lines can be carried out on a power distribution area with a complex topological structure.

Description

Technical Field

[0001] This application relates to the field of smart grid technology, and in particular to a distribution area management method and edge computing node based on a multi-loop monitoring device. Background Technology

[0002] With the integration of a large number of distributed energy sources and new loads into distribution transformer areas, the topology of distribution transformer areas is becoming increasingly complex, and determining the topology is the basis for the management and control of distribution transformer areas.

[0003] However, the determination of the topology of a distribution transformer substation in related technologies relies on the analysis of the readings of smart meters in the distribution lines. Due to the influence of the synchronization between smart meters, the real-time performance and accuracy of the predicted topology are low. Therefore, it is difficult to meet the collaborative management and control requirements of distribution transformer substations with complex topologies. Summary of the Invention

[0004] Therefore, it is necessary to provide a distribution radio station area management method and edge computing node based on a multi-loop monitoring device to address the above-mentioned technical problems, which can improve the accuracy and real-time performance of determining the topology of the distribution radio station area.

[0005] In a first aspect, this application provides a method for managing and controlling a distribution radio station area based on a multi-loop monitoring device, applied to the edge computing nodes of a distribution radio station area, the method comprising:

[0006] Obtain the current impedance data of each power distribution line in the power distribution area at different preset frequencies;

[0007] Control the injection equipment deployed on the target power distribution line to inject a preset electrical signal into the target power distribution line;

[0008] The monitoring equipment deployed on each remaining power distribution line receives a preset electrical signal to obtain the current propagation information between the remaining power distribution line and the target power distribution line; wherein, the remaining power distribution line is the power distribution line in the power distribution area other than the target power distribution line;

[0009] Based on the current impedance data of each distribution line at different preset frequencies, and the current propagation information between different remaining distribution lines and the target distribution line, the current topology of the distribution substation is generated; wherein, the topology is used to characterize the connectivity between different distribution lines within the distribution substation and the branching of distribution lines within the distribution substation.

[0010] Based on the current topology, control the distribution radio area.

[0011] In one embodiment, the current topology of the distribution substation is generated based on the current impedance data of each distribution line at different preset frequencies and the current propagation information between different remaining distribution lines and the target distribution line. This includes: determining a first change information between the current impedance data and the previously acquired historical impedance data, and a second change information between the current propagation information and the previously acquired historical propagation information; determining the topology change status based on the first change information, the second change information, and a preset change threshold; and generating the current topology of the distribution substation based on the current impedance data of each distribution line at different preset frequencies and the current propagation information between different remaining distribution lines and the target distribution line when the topology change status indicates a change in the topology.

[0012] In one embodiment, the current topology of the distribution transformer area is generated based on the current impedance data of each distribution line at different preset frequencies and the current propagation information between different remaining distribution lines and the target distribution line. This includes: generating the impedance spectrum of the distribution line based on the current impedance data of each distribution line at different preset frequencies, and determining the abrupt change frequency and peak frequency corresponding to the distribution line based on the impedance spectrum; and generating the current topology of the distribution transformer area based on the abrupt change frequency and peak frequency corresponding to each distribution line and the current propagation information between different remaining distribution lines and the target distribution line.

[0013] In one embodiment, the current propagation information includes the current propagation delay and the current reception status of the preset electrical signal; the current topology of the distribution transformer area is generated based on the mutation frequency and peak frequency corresponding to each distribution line, and the current propagation information between different remaining distribution lines and the target distribution line, including: determining branch information and equipment access information in the distribution lines based on the mutation frequency and peak frequency corresponding to each distribution line; determining the connectivity between different distribution lines based on the current propagation delay and current reception status between different remaining distribution lines and the target distribution line; and generating the current topology of the distribution transformer area based on the branch information and equipment access information in each distribution line, and the connectivity between different distribution lines.

[0014] In one embodiment, the method further includes: acquiring the electrical signal of each power distribution line and performing frequency domain transformation on the electrical signal to obtain the harmonic components of the power distribution line; determining the propagation path of the harmonic components of each power distribution line according to the current topology; and performing harmonic compensation on the power distribution area according to the propagation path of the harmonic components of each power distribution line.

[0015] In one embodiment, managing the distribution radio area according to the current topology includes: performing fault detection on the distribution radio area according to the current topology to obtain fault information; wherein the fault information includes fault location and / or fault type.

[0016] In one embodiment, the fault information includes the fault location and fault type; based on the current topology, fault detection is performed on the distribution transformer area to obtain fault information, including: acquiring the electrical signal of each distribution line; detecting the distribution transformer area based on a preset fault threshold and the electrical signal of each distribution line to obtain detection results; if the detection results indicate that a fault has occurred in the distribution transformer area, determining the fault characteristics based on the electrical signal of each distribution line; determining the fault location based on the fault characteristics and the current topology, and determining the fault type based on the fault location and fault characteristics to obtain fault information.

[0017] In one embodiment, the preset electrical signal is represented by a pseudo-random sequence.

[0018] Secondly, this application also provides an edge computing node, including a multi-loop monitoring device. The multi-loop monitoring device includes a memory and a processor. The memory stores a computer program, and the processor executes the computer program to perform the following steps:

[0019] Obtain the current impedance data of each power distribution line in the power distribution area at different preset frequencies;

[0020] Control the injection equipment deployed on the target power distribution line to inject a preset electrical signal into the target power distribution line;

[0021] The monitoring equipment deployed on each remaining power distribution line receives a preset electrical signal to obtain the current propagation information between the remaining power distribution line and the target power distribution line; wherein, the remaining power distribution line is the power distribution line in the power distribution area other than the target power distribution line;

[0022] Based on the current impedance data of each distribution line at different preset frequencies, and the current propagation information between different remaining distribution lines and the target distribution line, the current topology of the distribution substation is generated; wherein, the topology is used to characterize the connectivity between different distribution lines within the distribution substation and the branching of distribution lines within the distribution substation.

[0023] Based on the current topology, control the distribution radio area.

[0024] Thirdly, this application also provides a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, performs the following steps:

[0025] Obtain the current impedance data of each power distribution line in the power distribution area at different preset frequencies;

[0026] Control the injection equipment deployed on the target power distribution line to inject a preset electrical signal into the target power distribution line;

[0027] The monitoring equipment deployed on each remaining power distribution line receives a preset electrical signal to obtain the current propagation information between the remaining power distribution line and the target power distribution line; wherein, the remaining power distribution line is the power distribution line in the power distribution area other than the target power distribution line;

[0028] Based on the current impedance data of each distribution line at different preset frequencies, and the current propagation information between different remaining distribution lines and the target distribution line, the current topology of the distribution substation is generated; wherein, the topology is used to characterize the connectivity between different distribution lines within the distribution substation and the branching of distribution lines within the distribution substation.

[0029] Based on the current topology, control the distribution radio area.

[0030] The aforementioned distribution transformer area management method based on multi-loop monitoring devices and edge computing nodes relies on the local computing capabilities of edge computing nodes within the distribution transformer area to control injection devices deployed on the target distribution line to inject preset electrical signals into the target distribution line, and to control monitoring devices deployed on each remaining distribution line to receive the preset electrical signals, thereby obtaining the current propagation information between the remaining distribution lines and the target distribution line. Thus, regardless of the complexity of the topology, the current topology of the distribution transformer area can be determined based on the current impedance data of each distribution line in the distribution transformer area at different preset frequencies and the current propagation information between the remaining distribution lines and the target distribution line. Based on the determined current topology, collaborative management and control of each distribution line in the distribution transformer area can be achieved without the need for a remote operation and maintenance platform for the distribution transformer area. This breaks through the technical barrier that related technologies can only perform single-point management of faults in the distribution transformer area, and adapts to the complex management and control needs after distributed energy is connected to the distribution transformer area. Attached Figure Description

[0031] To more clearly illustrate the technical solutions in the embodiments of this application or related technologies, the drawings used in the description of the embodiments of this application or related technologies will be briefly introduced below. Obviously, the drawings described below are only some embodiments of this application. For those skilled in the art, other related drawings can be obtained based on these drawings without creative effort.

[0032] Figure 1 This is a flowchart illustrating a distribution area control method based on a multi-loop monitoring device in one embodiment.

[0033] Figure 2 This is a schematic diagram of the process for generating the current topology in one embodiment;

[0034] Figure 3 This is a flowchart illustrating the process of generating the current topology in yet another embodiment;

[0035] Figure 4 This is a schematic diagram illustrating the generation of the current topology in one embodiment;

[0036] Figure 5 This is a schematic diagram illustrating the process of controlling a distribution radio area in one embodiment;

[0037] Figure 6 This is a flowchart illustrating the process of controlling a distribution radio area in another embodiment;

[0038] Figure 7 This is a flowchart illustrating a distribution area control method based on a multi-loop monitoring device in yet another embodiment.

[0039] Figure 8 Here is a structural block diagram of an edge computing node in one embodiment;

[0040] Figure 9 This is a communication diagram of a communication protocol library in one embodiment. Detailed Implementation

[0041] To make the objectives, technical solutions, and advantages of this application clearer, the following detailed description is provided in conjunction with the accompanying drawings and embodiments. It should be understood that the specific embodiments described herein are merely illustrative and not intended to limit the scope of this application.

[0042] It should be noted that the terms "first," "second," etc., used in this application can be used to describe various elements, but these elements are not limited by these terms. These terms are only used to distinguish the first element from the second element. The terms "comprising" and "having," and any variations thereof, used in this application, are intended to cover non-exclusive inclusion. The term "multiple" used in this application refers to two or more. The term "and / or" used in this application refers to one of the embodiments, or any combination of multiple embodiments.

[0043] In one exemplary embodiment, such as Figure 1 As shown, a method for managing a distribution transformer area based on a multi-loop monitoring device is provided. The method is illustrated using an example of its application to a multi-loop monitoring device in an edge computing node of a distribution transformer area, and includes the following steps S101-S105. Wherein:

[0044] S101, obtain the current impedance data of each power distribution line in the power distribution area at different preset frequencies.

[0045] For example, a distribution substation can represent a distribution unit in a low-voltage distribution network that is centered on a single distribution device and covers a certain power supply range. A distribution substation includes multiple interconnected distribution lines (such as user power supply lines, distributed energy access lines, etc.).

[0046] Edge computing nodes are located within the distribution network area and have the capabilities for local data acquisition, local computation and analysis, and decision control.

[0047] Optionally, the process of obtaining the current impedance data of each distribution line within the distribution transformer area at different preset frequencies may include: performing a frequency sweep test on each distribution line within the distribution transformer area according to a preset scanning frequency band to obtain the impedance data of each distribution line within the distribution transformer area at different preset frequencies within the preset scanning frequency band, i.e., the current impedance data. For example, the preset scanning frequency band can be 0.1 Hz - 10 Hz.

[0048] In one embodiment, since the impedance characteristics of the power distribution line with line branch points and terminal equipment access points are significantly different from those of other power distribution lines, the location of the line branch points and the location of the terminal equipment access points in each power distribution line can be determined based on the current impedance data.

[0049] S102, control the injection device deployed on the target power distribution line to inject a preset electrical signal into the target power distribution line.

[0050] For example, the injection device can be a device deployed on the target power distribution line that has signal generation and injection capabilities, such as an existing end meter in the power distribution line, without the need for additional installation. The injection device is used to couple a preset electrical signal to the target power distribution line. The number of target power distribution lines can be one or more.

[0051] Optionally, the injection process of the preset electrical signal includes: the edge computing node sending an injection command to the injection device deployed on the target power distribution line, the injection command including the injection time and preset electrical signal information, and further, the preset electrical signal information may include the amplitude of the preset electrical signal.

[0052] For example, the preset electrical signal can be a voltage signal, and the amplitude of the preset electrical signal can be set according to the rated voltage of the distribution network, specifically 0.5V, which is much smaller than the rated voltage of the distribution network.

[0053] S103, control the monitoring equipment deployed on each remaining power distribution line to receive preset electrical signals and obtain the current propagation information between the remaining power distribution line and the target power distribution line.

[0054] The remaining distribution lines are those within the distribution area excluding the target distribution lines.

[0055] In one embodiment, a listening instruction can be sent to a listening device deployed on each remaining power distribution line to control each listening device to receive a preset electrical signal in the target power distribution line, thereby obtaining the listening information of each listening device on the preset electrical signal. The listening information may include the transmission time required to receive the preset electrical signal and whether the preset electrical signal has been received. Therefore, the listening information can be used to reflect the current propagation information between the remaining power distribution line and the target power distribution line.

[0056] S104. Based on the current impedance data of each distribution line at different preset frequencies, and the current propagation information between different remaining distribution lines and the target distribution line, generate the current topology of the distribution area.

[0057] The topology is used to characterize the connectivity between different power distribution lines within a power distribution area and the branching of power distribution lines within the power distribution area.

[0058] For example, the current propagation information obtained above can reflect the connectivity between different power distribution lines within the distribution area.

[0059] Therefore, based on the current impedance data of each distribution line at different preset frequencies, as well as the current propagation information between different remaining distribution lines and the target distribution line, the topology of the distribution area at the current injection time can be determined from different dimensions, that is, the current topology.

[0060] S105, manages the distribution radio area according to the current topology.

[0061] For example, based on the current topology, all distribution lines in the distribution area can be coordinated and managed according to the current topology. Specifically, this may include management actions such as fault tracing, load conditions, and harmonic mitigation.

[0062] Based on this, the management and control of distribution radio areas no longer needs to rely on remote operation and maintenance platforms for command issuance and decision allocation. It can be completed at the edge computing nodes within the distribution radio area, which speeds up the execution efficiency of the management and control strategies of the distribution radio area.

[0063] The aforementioned distribution transformer area management method based on multi-loop monitoring devices relies on the local computing power of edge computing nodes within the distribution transformer area to control injection devices deployed on the target distribution line to inject preset electrical signals into the target distribution line, and to control monitoring devices deployed on each remaining distribution line to receive the preset electrical signals, thereby obtaining the current propagation information between the remaining distribution lines and the target distribution line. Therefore, regardless of the complexity of the topology, the current topology of the distribution transformer area can be determined based on the current impedance data of each distribution line within the distribution transformer area at different preset frequencies and the current propagation information between the remaining distribution lines and the target distribution line. This allows for collaborative management of each distribution line within the distribution transformer area based on the determined current topology, eliminating the need for a remote operation and maintenance platform for the distribution transformer area. It also breaks through the technical barrier that related technologies can only perform single-point fault management within the distribution transformer area, adapting to the complex management needs after distributed energy resources are connected to the distribution transformer area.

[0064] In one exemplary embodiment, the preset electrical signal is represented by a pseudo-random sequence.

[0065] For example, a pseudo-random sequence can be a Gold code sequence, which is a binary code sequence where each bit is 0 or 1, and the code rate can be 1,000,000 bps (the number of bits transmitted per second).

[0066] Specifically, the pseudo-random sequences injected into different target power distribution lines can be different, and the different pseudo-random sequences and their matching relationships with the target power distribution lines can be pre-set and stored in the memory of the edge computing node.

[0067] For example, after receiving an injection command, the injection device in the target power distribution line can convert the pseudo-random sequence into an electrical signal and couple it into the target power distribution line, enabling signal transmission with the remaining power distribution lines.

[0068] This embodiment uses a pseudo-random sequence to represent the preset electrical signal. By utilizing the strong autocorrelation of the pseudo-random sequence, it ensures that the monitoring equipment deployed in the remaining power distribution lines can still accurately extract the preset electrical signal from the superimposed signal through correlation analysis, even when the received preset electrical signal is superimposed with noise signals. At the same time, by utilizing the low cross-correlation of the pseudo-random sequence, when injecting different pseudo-random sequences into different target power distribution lines or even different power distribution areas, the accuracy and reliability of the current propagation information will not be low due to signal confusion. This makes it suitable for power distribution areas with complex and varied topologies.

[0069] Based on the above embodiments, such as Figure 2 As shown, S104 above includes:

[0070] S201, determine the first change information between the current impedance data and the previously acquired historical impedance data, and the second change information between the current propagation information and the previously acquired historical propagation information.

[0071] For example, before acquiring the current impedance data and obtaining the preset time interval of the current propagation information, the above S101-S103 are also executed to acquire historical impedance data and obtain historical propagation information.

[0072] Optionally, for each distribution line, a first change information can be determined based on the difference between the current impedance data and the historical impedance data, and for each remaining distribution line, a second change information can be determined based on the difference between the current propagation information and the historical propagation information.

[0073] The first change information reflects the increase or decrease of branches and connected equipment in the corresponding power distribution line. The second change information reflects the changes in the connectivity between the remaining power distribution lines and the target power distribution line.

[0074] S202, determine the topology change based on the first change information, the second change information, and the preset change threshold.

[0075] Optionally, the first change information and the second change information can quantify the changes in the branch additions and subtractions, the additions and subtractions of connected equipment, and the changes in the connectivity between the remaining power distribution lines and the target power distribution lines by means of change or change rate.

[0076] Based on this, preset change thresholds can be set according to control requirements. The numerical values ​​between the preset change threshold and the first change information and / or between the preset change threshold and the second change information are compared, and the topology change status is determined based on the comparison results. For example, the range of the preset change threshold can be 5%-15%. The topology change status can indicate whether the topology has changed or not.

[0077] S203, In the case of a change in topology, the current topology of the distribution area is generated based on the current impedance data of each distribution line at different preset frequencies and the current propagation information between the remaining distribution lines and the target distribution line.

[0078] In one embodiment, if the first change information and / or the second change information exceed a preset change threshold, it indicates that the change corresponding to the first change information and / or the second change information reflects the addition or reduction of branches in the distribution line, the addition or reduction of access equipment, and / or the change in the connectivity between the remaining distribution line and the target distribution line. That is, the determined topology change indicates that the topology has changed. At this time, based on the current impedance data of each distribution line at different preset frequencies and the current propagation information between different remaining distribution lines and the target distribution line, the current topology of the distribution area is generated and the topology is updated in the memory of the edge computing node.

[0079] S204, In the case of a change in topology, the previously generated historical topology is used as the current topology.

[0080] In one embodiment, if neither the first change information nor the second change information exceeds a preset change threshold, it indicates that the change situation corresponding to the first change information and the second change information reflects that there is no increase or decrease of branches or access devices in the power distribution line, and the connection relationship between the remaining power distribution line and the target power distribution line has not changed. That is, the determined topology change situation indicates that the topology has not changed. At this time, there is no need to regenerate the topology, and the historical topology generated last time can be directly used.

[0081] In this embodiment, changes in the topology are determined by continuously monitoring the changes in impedance and propagation information. When the topology changes, the current topology is regenerated, realizing real-time updates of the distribution radio area's topology within the edge computing node. This provides a reliable and accurate data source for subsequent management and control of the distribution radio area.

[0082] For example, the process of generating the current topology of a distribution transformer area may include: generating the impedance spectrum of the distribution line based on the current impedance data of each distribution line at different preset frequencies, and determining the abrupt change frequency and peak frequency of the distribution line based on the impedance spectrum; generating the current topology of the distribution transformer area based on the abrupt change frequency and peak frequency of each distribution line, as well as the current propagation information between different remaining distribution lines and the target distribution line.

[0083] In one embodiment, the current impedance data obtained in S101 can be impedance values ​​corresponding to different preset frequencies, i.e., discrete impedance data. To determine the branch locations and connection equipment locations in the power distribution line based on the changes in impedance data, the discrete impedance data can be converted into a continuous impedance spectrum. Optionally, the generated impedance spectrum can be analyzed to extract abrupt change frequencies and peak frequencies.

[0084] The mutation frequency is the frequency of the impedance data in the impedance spectrum that causes a significant change (such as a sudden increase or a sudden decrease). The change in impedance data is caused by the branches or connected equipment in the power distribution line changing the electrical structure of the power distribution line. Therefore, the branch situation or connected equipment situation in the power distribution line can be determined based on the mutation frequency.

[0085] The value of the peak frequency is related to the number, type, and number of branches of the equipment connected to the power distribution line. Therefore, the number, type, and number of branches of the equipment connected to the power distribution line can be determined based on the peak frequency.

[0086] Based on the above embodiments, such as Figure 3 As shown, the process of generating the current topology of a distribution substation based on the mutation frequency and peak frequency corresponding to each distribution line, as well as the current propagation information between different remaining distribution lines and the target distribution line, may include:

[0087] S301, determine the branch information and equipment access information in the power distribution line based on the sudden change frequency and peak frequency corresponding to each power distribution line.

[0088] Optionally, the branch information includes the existence and location of branches in the power distribution line, and the equipment access information may include the equipment access status and location, wherein the equipment may be a charging pile, electricity meter, etc.

[0089] Specifically, the number of branches in a power distribution line can be determined based on the number of frequency points corresponding to the sudden frequency change, and the branch locations in the power distribution line can be determined based on the value of the sudden frequency change. The equipment connection type and equipment connection location can be determined based on the value of the peak frequency.

[0090] The current propagation information includes the current propagation delay and the current reception status of the preset electrical signal.

[0091] S302, determine the connectivity between different power distribution lines based on the current propagation delay and current reception status between different remaining power distribution lines and the target power distribution line.

[0092] In one embodiment, the current reception status can characterize the connectivity between the corresponding remaining power distribution line and the target power distribution line. For example, if the current reception status indicates that a preset electrical signal has been received, it can be determined that the corresponding remaining power distribution line and the target power distribution line are connected; conversely, if the current reception status indicates that a preset electrical signal has not been received, it can be determined that the corresponding remaining power distribution line and the target power distribution line are not connected.

[0093] Furthermore, based on determining the connectivity between the remaining distribution lines and the target distribution line according to the current reception status, the upstream and downstream relationships between different remaining distribution lines can be determined according to the current propagation delay corresponding to different remaining distribution lines.

[0094] For example, the current propagation delay can be determined based on the reception results of preset electrical signals received multiple times by the monitoring devices in the remaining power distribution lines.

[0095] For example, the current propagation delay corresponding to each remaining distribution line. It can be determined according to the following formula (1).

[0096] (1)

[0097] Where N represents the total number of samples taken by the monitoring device, i represents the index of the target power distribution line, and j represents the index of the remaining power distribution lines. Let T represent the propagation time obtained from the k-th sample, where T is the sampling period.

[0098] S303 generates the current topology of the distribution substation based on the branch information and equipment access information in each distribution line, as well as the connectivity between different distribution lines.

[0099] For example, the longer the propagation delay, the farther the corresponding remaining power distribution line is from the target power distribution line. Therefore, the upstream and downstream relationship between different remaining power distribution lines can be determined based on the current propagation information between the remaining power distribution lines and the target power distribution line.

[0100] Based on the above embodiments, the current topology of the power distribution area can be generated according to the branch locations and equipment access locations in each power distribution line, as well as the connectivity and upstream and downstream relationships between different power distribution lines.

[0101] Figure 4 This is a schematic diagram illustrating the process of determining the current topology of a distribution radio station.

[0102] like Figure 4 As shown, LTU (Line Terminal Unit) 1 represents the injection terminal of the target power distribution line, and LTU2-LTU8 are the monitoring terminals of the remaining power distribution lines in the distribution area, respectively. Based on the current propagation information corresponding to LTU6 and LTU3, it can be known that the remaining power distribution lines corresponding to LTU6 and LTU3 are connected to the target power distribution line, and LTU6 is located upstream of LTU3. Furthermore, based on the current impedance data of the power distribution lines corresponding to LTU1-LTU8, the status of the remaining power distribution lines other than those corresponding to LTU6 and LTU3 in the remaining power distribution lines corresponding to LTU2-LTU8 can be determined.

[0103] It should be noted that the above Figure 4 The number of distribution lines is only illustrative. In other embodiments of this application, the distribution station may have any other number of target distribution lines and remaining distribution lines, and this application does not limit this.

[0104] This embodiment determines the branch information and equipment access information of the power distribution line based on the corresponding mutation frequency and peak frequency. At the same time, it determines the connectivity between different power distribution lines based on the current propagation delay and current reception status between different remaining power distribution lines and the target power distribution line. Thus, based on the branch information and equipment access information in each power distribution line, as well as the connectivity between different power distribution lines, the current topology of the power distribution area is generated. The time required to generate the current topology is controlled within 30 seconds, which solves the technical problems of high implementation cost and low accuracy in determining the topology in related technologies, and provides a reliable basis for subsequent management and control of the power distribution area.

[0105] For example, such as Figure 5 As shown, the control methods for the aforementioned distribution radio areas also include:

[0106] S501 acquires the electrical signal of each power distribution line and performs frequency domain transformation on the electrical signal to obtain the harmonic components of the power distribution line.

[0107] For example, the electrical signal can be a voltage signal or a current signal, and the harmonic components can include the current component and the voltage component of the harmonics.

[0108] Specifically, for each power distribution line, after acquiring the electrical signal of the power distribution line, the electrical signal can be converted from digital to analog, and the obtained analog time-domain signal can be Fourier transformed to obtain the frequency domain signal, from which the corresponding harmonic components can be extracted.

[0109] S502, Based on the current topology, determine the propagation path of the harmonic components of each distribution line.

[0110] Optionally, the pollution source of each harmonic component can be located based on the acquired electrical signals and harmonic components of each power distribution line, and the propagation path of each harmonic component can be determined based on the current topology and the pollution source of each harmonic component.

[0111] S503 performs harmonic compensation for the distribution transformer area based on the propagation path of the harmonic components of each distribution line.

[0112] For example, for the propagation path of each harmonic component, an impedance matrix can be constructed based on the current impedance data of the distribution lines through which the propagation path flows. The harmonic compensation current can be determined based on the inverse operation result of the impedance matrix and the extracted harmonic components. The harmonic compensation current can be output by controlling the reactive power compensation device to compensate for the harmonic components.

[0113] In one embodiment, equipment such as motors and charging piles (inductive loads) in a power distribution line consume reactive power. Excessive reactive power can lead to unstable line voltage, low power factor, and excessive line losses. Therefore, it is necessary to use capacitor banks in a reactive power compensation device to provide reactive power compensation for these inductive loads. However, reactive power compensation in related technologies suffers from technical problems such as slow response speed and low adaptability.

[0114] Based on this, this application, after determining the current topology, calculates real-time reactive power, power factor, and voltage deviation rate according to the obtained electrical parameters. This allows for the determination of the average voltage of the previous compensation cycle (e.g., 15 minutes) and the historical optimal operating voltage based on the voltage deviation rate and real-time reactive power of the distribution line. A mapping relationship between voltage and reactive power compensation is constructed, and different compensation sensitivity coefficients are set for different voltage ranges to adjust the constructed mapping relationship. This results in a steeper slope and a faster compensation response in areas with higher voltage risk. For example, the compensation sensitivity coefficient is K1 for the first voltage range below 210V, K2 for the second voltage range of 210V-230V, and K3 for the third voltage range, with K1 having the largest value.

[0115] Furthermore, based on the equipment access information of different power distribution lines reflected in the current topology and the harmonic components extracted by S501 above, the importance of compensation for each power distribution line can be judged, and corresponding weighting coefficients can be generated based on the judgment results to assist in determining the reactive power compensation amount.

[0116] In one embodiment, the reactive power compensation for each distribution line can be calculated based on the following formula (2). To be determined.

[0117] (2)

[0118] in, This represents the mapping relationship between voltage and reactive power compensation constructed above, where U represents the real-time voltage. The reference voltage is calculated based on the average voltage of the previous compensation cycle and the historical optimal operating voltage. This represents the compensation sensitivity coefficient. This refers to the weighting coefficients generated based on the judgment results. This indicates real-time reactive power.

[0119] For example, the optimal capacitor bank switching combination can be determined based on the calculation results (numerical value and sign) of the above formula (2) and the current switching status of the capacitor bank, and a compensation instruction corresponding to the determined optimal capacitor bank switching combination can be generated and sent to the reactive power compensation device of the corresponding power distribution line to perform reactive power compensation according to the optimal capacitor bank switching combination.

[0120] Based on the above embodiments, and given the current topology, the power demand of each distribution line can be allocated. Optionally, a target power allocation scheme for each distribution line... It can be expressed as the following formula (3).

[0121] (3)

[0122] in, Indicates the cost of electricity. , This represents the real-time power at time t. The real-time electricity price at time t represents the price of electricity, and α represents the weight corresponding to the cost of electricity, which is usually 0.6. This represents the maximum demand cost. , Let q represent the maximum demand, q represent the demand electricity price, and β represent... The corresponding weight is usually 0.4.

[0123] For example, the operating power of the controllable load connected to the power distribution line can be controlled so that the power distribution line meets the target power allocation scheme of the above formula (3) and the electricity cost is reduced.

[0124] Based on the above embodiments, short-term forecasts of load changes connected to distribution lines can be made based on a determined current topology. Specifically, frozen energy data at a target time can be obtained, where the target time can include the hour, the end of the day, or the end of the month. Then, a time series model or an initial model combining a time series model and a machine learning model can be constructed based on the frozen energy data at the target time to train the load forecasting model.

[0125] In an exemplary embodiment, S105 includes: performing fault detection on the distribution radio area according to the current topology to obtain fault information; wherein the fault information includes fault location and / or fault type.

[0126] Fault detection in distribution transformer areas can include arc fault detection, overcurrent detection, zero-sequence current detection, temperature detection, and insulation detection.

[0127] For example, such as Figure 6As shown, based on the current topology, fault detection is performed on the distribution transformer area to obtain fault information, including:

[0128] S601 acquires the electrical signals of each power distribution line.

[0129] The electrical signal can be a current signal and / or a voltage signal.

[0130] S602 detects the distribution area based on preset fault thresholds and electrical signals of each distribution line, and obtains the detection results.

[0131] For example, the preset fault threshold can be a preset voltage threshold and / or a preset current threshold.

[0132] The detection of a distribution transformer area based on a preset fault threshold and the electrical signal of each distribution line can include detecting faults in the distribution transformer area based on the electrical signal and the preset current threshold corresponding to the electrical signal, or it can be to calculate judgment parameters based on the electrical signal and detect faults in the distribution transformer area based on the judgment parameters and the preset fault threshold corresponding to the judgment parameters.

[0133] For example, for overcurrent detection, a fault can be identified in the distribution area if the current exceeds the preset fault threshold for the corresponding load type; for zero-sequence current detection, a fault can be identified in the distribution area if the zero-sequence current exceeds the preset fault threshold or the three-phase imbalance exceeds the preset fault threshold; for insulation detection, a fault can be identified in the distribution area if the dielectric constant deviation exceeds the preset fault threshold or the dielectric loss tangent exceeds the preset fault threshold.

[0134] S603, when the detection results indicate a fault in the distribution substation area, determines the fault characteristics based on the electrical signals of each distribution line.

[0135] For example, for arc fault detection, fault characteristics can include the energy distribution of the current signal in different frequency bands; for overcurrent detection, fault characteristics can include the current of a certain phase / multiple phases, phase difference, and harmonic content; for zero-sequence detection, fault characteristic quantities can be zero-sequence current and unbalance; for temperature detection, fault characteristics can be the temperature and current of the target area in the power distribution line; for insulation detection, fault characteristics can be the change in dielectric constant and the tangent of dielectric loss angle within the target frequency band.

[0136] S604 determines the fault location based on the fault characteristics and the current topology, and determines the fault type based on the fault location and fault characteristics, thus obtaining fault information.

[0137] For example, based on determining the fault characteristics and the current topology, the location of the fault can be determined, i.e., the fault location. Further, the device access information corresponding to the fault location can be determined based on the fault location, and the fault type can be determined in combination with the device access information. Thus, fault information can be obtained based on the fault type and fault category.

[0138] This implementation achieves precise safety protection, real-time decision-making and response, and optimized energy costs for distribution transformer areas through local closed-loop management of edge computing nodes. It improves the accuracy of arc fault detection to over 99.7% and the error of overcurrent protection action to <2%. Combined with an autonomous topology discovery mechanism, it reduces the fault location error to within 1 meter and compresses the fault response time to 5-20ms. Through dynamic demand control and load forecasting algorithms, it balances energy costs and demand costs, reducing the overall electricity cost of the transformer area by 15%-25%. With the addition of distributed fiber optic temperature measurement, frequency domain insulation monitoring and other functions, it provides early warning of potential hazards such as line overheating and insulation aging, improving operation and maintenance efficiency by 40% and enhancing the collaborative management efficiency of distribution transformer areas.

[0139] Based on the above embodiments, in an exemplary embodiment, an optional distribution area management method based on a multi-loop monitoring device is provided, such as... Figure 7 As shown, it may include:

[0140] S701, obtains the current impedance data of each power distribution line in the power distribution area at different preset frequencies.

[0141] S702 controls the injection device deployed on the target power distribution line to inject a preset electrical signal into the target power distribution line.

[0142] S703 controls the monitoring equipment deployed on each remaining power distribution line to receive a preset electrical signal and obtain the current propagation information between the remaining power distribution line and the target power distribution line.

[0143] S704, determine the first change information between the current impedance data and the previously acquired historical impedance data, and the second change information between the current propagation information and the previously acquired historical propagation information.

[0144] S705, determine the topology change based on the first change information, the second change information, and the preset change threshold.

[0145] S706, In the case of a change in topology, the previously generated historical topology is used as the current topology.

[0146] S707 generates the impedance spectrum of each power distribution line based on its current impedance data at different preset frequencies, and determines the corresponding abrupt change frequency and peak frequency of the power distribution line based on the impedance spectrum.

[0147] S708 determines the branch information and equipment access information in the power distribution line based on the sudden change frequency and peak frequency corresponding to each power distribution line.

[0148] S709, determine the connectivity between different power distribution lines based on the current propagation delay and current reception status between different remaining power distribution lines and the target power distribution line.

[0149] S710 generates the current topology of the distribution substation based on the branch information and equipment access information in each distribution line, as well as the connectivity between different distribution lines.

[0150] S711 manages and controls the distribution radio area based on the current topology.

[0151] Based on the current topology, control the distribution transformer area, including: performing fault detection on the distribution transformer area based on the current topology to obtain fault information; wherein, the fault information includes fault location and / or fault type.

[0152] The fault information includes the fault location and fault type. Based on the current topology, fault detection is performed on the distribution transformer area to obtain fault information, including: acquiring the electrical signals of each distribution line; detecting the distribution transformer area based on a preset fault threshold and the electrical signals of each distribution line to obtain detection results; if the detection results indicate that a fault has occurred in the distribution transformer area, the fault characteristics are determined based on the electrical signals of each distribution line; the fault location is determined based on the fault characteristics and the current topology, and the fault type is determined based on the fault location and fault characteristics to obtain fault information.

[0153] The above method also includes: acquiring the electrical signal of each power distribution line, performing frequency domain transformation on the electrical signal to obtain the harmonic components of the power distribution line; determining the propagation path of the harmonic components of each power distribution line according to the current topology; and performing harmonic compensation on the power distribution area according to the propagation path of the harmonic components of each power distribution line.

[0154] The specific processes of S701-S711 described above can be found in the description of the above method embodiments. Their implementation principles and technical effects are similar, and will not be repeated here.

[0155] It should be understood that although the steps in the flowcharts of the embodiments described above are shown sequentially according to the arrows, these steps are not necessarily executed in the order indicated by the arrows. Unless explicitly stated herein, there is no strict order restriction on the execution of these steps, and they can be executed in other orders. Moreover, at least some steps in the flowcharts of the embodiments described above may include multiple steps or multiple stages. These steps or stages are not necessarily completed at the same time, but can be executed at different times. The execution order of these steps or stages is not necessarily sequential, but can be performed alternately or in turn with other steps or at least some of the steps or stages in other steps. It is understood that the steps in different embodiments can be freely combined as needed, and all non-contradictory solutions formed by such combinations are within the scope of protection of this application.

[0156] Based on the same inventive concept, this application also provides an edge computing node for implementing the above-mentioned method for controlling distribution areas based on multi-loop monitoring devices. The solution provided by this edge computing node is similar to the implementation scheme described in the above method. Therefore, the specific limitations of one or more edge computing node embodiments provided below can be found in the limitations of the method for controlling distribution areas based on multi-loop monitoring devices described above, and will not be repeated here.

[0157] In one exemplary embodiment, such as Figure 8 As shown, an edge computing node is provided, including: a multi-loop monitoring device, which integrates a digital-to-analog converter, a transceiver interface, a communication bus, a power supply, a digital signal processor, a communication protocol library, a data bus, a memory, and a display unit. Wherein:

[0158] Multi-channel analog signal transformers collect electrical signals (analog signals) from power distribution lines and send them to digital-to-analog converters in edge computing nodes for digital-to-analog conversion. The resulting digital signals are then sent to digital signal processors, which calculate parameters such as reactive power and harmonic components, providing data for load forecasting, reactive power compensation, and fault detection.

[0159] The charging pile matches the communication protocol library through the transceiver interface, the inverter matches the communication protocol library through the communication bus, and the mains power supplies the edge computing node.

[0160] The data bus connects the digital signal processor, communication protocol library, memory, and display unit to realize the transmission of data or instructions between the modules.

[0161] The memory includes a non-volatile storage medium and internal memory. The non-volatile storage medium stores the operating system, computer programs, and a database. The internal memory provides the environment for the operation of the operating system and computer programs stored in the non-volatile storage medium. The database of the computer device is used to store historical and current topologies.

[0162] The display unit is used to enable interaction between the distribution radio area and the user, and can display the current topology, fault information, etc. of the distribution radio area in real time.

[0163] Figure 9 This is a communication diagram of the communication protocol library. For example... Figure 9 As shown, the transceiver interface includes a data receiving interface and a data sending interface. The communication protocol library is used to determine the protocol type of the message received by the data receiving interface, and distribute the message to the corresponding protocol interface for message integrity checking and message parsing. The parsed information is then uploaded to the data center. On the other hand, the communication protocol library can also receive messages distributed by the data center, distribute the messages to the corresponding protocol interfaces, package the messages into message frames, and send them to the corresponding devices via the data sending interface.

[0164] The aforementioned communication protocol library can simultaneously adapt to different types of protocols such as DL / T645 and IEC61850, enabling seamless collaborative management and control between heterogeneous devices such as charging piles, energy storage, and inverters.

[0165] In one embodiment, a computer-readable storage medium is provided having a computer program stored thereon that, when executed by a processor, implements the steps in the above method embodiments.

[0166] In one embodiment, a computer program product is provided, including a computer program that, when executed by a processor, implements the steps in the above method embodiments.

[0167] Those skilled in the art will understand that all or part of the processes in the methods of the above embodiments can be implemented by a computer program instructing related hardware. The computer program can be stored in a non-volatile computer-readable storage medium, and when executed, it can include the processes of the embodiments of the above methods. Any references to memory, databases, or other media used in the embodiments provided in this application can include at least one of non-volatile memory and volatile memory. Non-volatile memory can include read-only memory (ROM), magnetic tape, floppy disk, flash memory, optical memory, high-density embedded non-volatile memory, resistive random access memory (ReRAM), magnetic random access memory (MRAM), ferroelectric random access memory (FRAM), phase change memory (PCM), graphene memory, etc. Volatile memory can include random access memory (RAM) or external cache memory, etc. By way of illustration and not limitation, RAM can take many forms, such as Static Random Access Memory (SRAM) or Dynamic Random Access Memory (DRAM). The databases involved in the embodiments provided in this application may include at least one type of relational database and non-relational database. Non-relational databases may include, but are not limited to, blockchain-based distributed databases. The processors involved in the embodiments provided in this application may be general-purpose processors, central processing units, graphics processing units, digital signal processors, programmable logic devices, quantum computing-based data processing logic devices, artificial intelligence (AI) processors, etc., and are not limited to these.

[0168] The technical features of the above embodiments can be combined in any way. For the sake of brevity, 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.

[0169] The embodiments described above are merely illustrative of several implementation methods of this application, and while the descriptions are specific and detailed, they should not be construed as limiting the scope of this patent application. It should be noted that those skilled in the art can make various modifications and improvements without departing from the concept of this application, and these all fall within the protection scope of this application. Therefore, the protection scope of this application should be determined by the appended claims.

Claims

1. A method for controlling distribution radio areas based on a multi-loop monitoring device, characterized in that, A multi-loop monitoring device applied to edge computing nodes in a power distribution area, the method comprising: Obtain the current impedance data of each power distribution line in the power distribution area at different preset frequencies; Control the injection device deployed on the target power distribution line to inject a preset electrical signal into the target power distribution line; The monitoring equipment deployed on each remaining power distribution line receives the preset electrical signal to obtain the current propagation information between the remaining power distribution line and the target power distribution line; wherein, the remaining power distribution line is the power distribution line within the power distribution area other than the target power distribution line; Based on the current impedance data of each distribution line at different preset frequencies, and the current propagation information between different remaining distribution lines and the target distribution line, the current topology of the distribution substation is generated; wherein, the topology is used to characterize the connectivity between different distribution lines within the distribution substation and the branching of the distribution lines in the distribution substation. Based on the current topology, manage the distribution radio area.

2. The method according to claim 1, characterized in that, The step of generating the current topology of the distribution substation based on the current impedance data of each distribution line at different preset frequencies and the current propagation information between different remaining distribution lines and the target distribution line includes: Determine the first change information between the current impedance data and the previously acquired historical impedance data, and the second change information between the current propagation information and the previously acquired historical propagation information; Based on the first change information, the second change information, and the preset change threshold, the topology change situation is determined; When the topology change condition indicates that the topology has changed, the current topology of the distribution substation is generated based on the current impedance data of each distribution line at different preset frequencies and the current propagation information between different remaining distribution lines and the target distribution line.

3. The method according to claim 2, characterized in that, The step of generating the current topology of the distribution substation based on the current impedance data of each distribution line at different preset frequencies and the current propagation information between different remaining distribution lines and the target distribution line includes: Based on the current impedance data of each power distribution line at different preset frequencies, the impedance spectrum of the power distribution line is generated, and the abrupt change frequency and peak frequency of the power distribution line are determined based on the impedance spectrum. The current topology of the distribution substation is generated based on the mutation frequency and peak frequency of each distribution line, as well as the current propagation information between different remaining distribution lines and the target distribution line.

4. The method according to claim 3, characterized in that, The current propagation information includes the current propagation delay and the current reception status of the preset electrical signal; generating the current topology of the distribution substation based on the sudden change frequency and peak frequency corresponding to each distribution line, and the current propagation information between different remaining distribution lines and the target distribution line includes: Based on the mutation frequency and peak frequency corresponding to each power distribution line, determine the branch information and equipment access information in the power distribution line; The connectivity between different power distribution lines is determined based on the current propagation delay and current reception status between different remaining power distribution lines and the target power distribution line; The current topology of the power distribution area is generated based on the branch information and equipment access information in each power distribution line, as well as the connectivity between different power distribution lines.

5. The method according to claim 1, characterized in that, The method further includes: The electrical signal of each power distribution line is acquired, and the electrical signal is frequency domain transformed to obtain the harmonic components of the power distribution line. Based on the current topology, determine the propagation path of the harmonic components of each power distribution line; Harmonic compensation is performed on the distribution transformer area based on the propagation path of the harmonic components of each distribution line.

6. The method according to claim 1, characterized in that, The step of managing the distribution radio area according to the current topology includes: Based on the current topology, fault detection is performed on the distribution radio area to obtain fault information; wherein, the fault information includes fault location and / or fault type.

7. The method according to claim 6, characterized in that, The fault information includes the fault location and fault type; the step of performing fault detection on the distribution transformer area according to the current topology to obtain fault information includes: Acquire the electrical signals of each power distribution line; The distribution area is detected based on a preset fault threshold and the electrical signal of each distribution line, and the detection results are obtained. If the detection results indicate that a fault has occurred in the distribution area, the fault characteristics are determined based on the electrical signals of each distribution line. Based on the fault characteristics and the current topology, the fault location is determined, and based on the fault location and the fault characteristics, the fault type is determined to obtain fault information.

8. The method according to claim 1, characterized in that, The preset electrical signal is represented by a pseudo-random sequence.

9. An edge computing node, comprising a multi-loop monitoring device, the multi-loop monitoring device including a memory and a processor, the memory storing a computer program, characterized in that, When the processor executes the computer program, it implements the steps of the method according to any one of claims 1-8.

10. A computer-readable storage medium having a computer program stored thereon, characterized in that, When the computer program is executed by a processor, it implements the steps of the method according to any one of claims 1-8.

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