Low-voltage area line loss anomaly identification method and device and computer equipment

Abstract

This application relates to a method, apparatus, computer equipment, storage medium, and computer program product for identifying abnormal line losses in low-voltage distribution areas. The method includes: acquiring the metering error of the intelligent terminal in the metering box; acquiring the clock value of the intelligent terminal and the clock value of the electricity meter, respectively, and calculating the clock deviation between the clock value of the intelligent terminal and the clock value of the electricity meter; acquiring the line loss value of the target phase at the metering box inlet; acquiring the cumulative count of hourly electricity data corresponding to the target phase, updating the cumulative count, and obtaining an updated cumulative count; proceeding to the step of acquiring the line loss value of the target phase at the metering box inlet if the clock deviation value does not exceed a second preset value, until the updated cumulative count is greater than or equal to a fourth preset value; and determining the abnormal line loss identification result of the electricity meter based on the calculated line loss coefficient. Using this method can improve the monitoring efficiency of abnormal line losses in low-voltage distribution areas.

Description

Technical Field

[0001] This application relates to the field of power grid technology, and in particular to a method, apparatus, computer equipment, storage medium and computer program product for identifying abnormal line losses in low-voltage distribution areas. Background Technology

[0002] With the rapid advancement and implementation of smart grid construction, the number of low-voltage metering boxes is growing rapidly, and the demand for daily operation and maintenance of metering boxes and prevention of electricity theft is also increasing.

[0003] In traditional technology, ordinary low-voltage metering boxes can only collect electricity meter data. Line loss results need to be calculated by other equipment using the collected electricity meter data, and then judged by humans based on the obtained line loss results and past experience to determine whether there are any abnormal line loss phenomena.

[0004] However, this method of judging abnormal line loss takes a long time and the whole process is quite complicated, resulting in low efficiency in monitoring abnormal line loss in low-voltage distribution areas. Summary of the Invention

[0005] Therefore, it is necessary to provide a method, device, computer equipment, computer-readable storage medium, and computer program product for identifying low-voltage distribution area line loss anomalies, which can improve the monitoring efficiency of low-voltage distribution area line loss anomalies, in response to the above-mentioned technical problems.

[0006] Firstly, this application provides a method for identifying abnormal line losses in low-voltage distribution areas. The method includes:

[0007] The metering error is obtained for the smart terminal of the metering box in the metering box; the metering box also includes an energy meter connected to the smart terminal of the metering box;

[0008] If the metering error does not exceed the first preset value, the clock value of the smart terminal of the metering box and the clock value of the electricity meter are obtained respectively, and the clock deviation value between the clock value of the smart terminal of the metering box and the clock value of the electricity meter is calculated.

[0009] If the clock deviation value does not exceed the second preset value, obtain the line loss value of the target phase at the metering box inlet; the target phase is any one of the phases at the metering box inlet.

[0010] If the line loss value of the target phase exceeds a third preset value, the cumulative number of times the hourly electricity data value corresponding to the target phase is obtained, and the cumulative number is updated to obtain the updated cumulative number.

[0011] If the updated cumulative number is less than the fourth preset value, the process jumps to the step of obtaining the line loss value of the target phase at the metering box inlet when the clock deviation value does not exceed the second preset value, until the updated cumulative number is greater than or equal to the fourth preset value;

[0012] If the updated cumulative number is greater than or equal to the fourth preset value, the line loss coefficient of each energy meter is determined based on the line loss value of the target phase and the hourly sequence energy data of each energy meter connected to the target phase of the metering box smart terminal. Based on the line loss coefficient, the line loss anomaly identification result of the energy meter is determined.

[0013] In one embodiment, before acquiring the clock value of the smart terminal of the metering box and the clock value of the energy meter connected to the smart terminal of the metering box, the method further includes:

[0014] Identify whether the topology of the metering box has changed;

[0015] If the topology of the metering box changes, the topology information of the metering box smart terminal is updated, and the hourly power data value of the target phase at the metering box inlet is cleared to zero.

[0016] The step of acquiring the clock value of the smart terminal of the metering box and the clock value of the energy meter connected to the smart terminal of the metering box includes:

[0017] Without changing the topology of the metering box, the clock value of the smart terminal of the metering box and the clock value of the energy meter connected to the smart terminal of the metering box are obtained respectively.

[0018] In one embodiment, obtaining the line loss value of the target phase at the metering box inlet includes:

[0019] The system acquires the first hour's electricity data value of the smart terminal in the metering box under the target phase at the metering box inlet, and the second hour's electricity data value of the energy meter connected to the target phase at the metering box inlet.

[0020] The first hour's power consumption data value and the second hour's power consumption data value are input into a pre-constructed phase line loss data processing model to obtain the line loss value of the target phase at the metering box inlet.

[0021] In one embodiment, determining the line loss coefficient of each energy meter based on the line loss value of the target phase and the hourly sequence energy consumption data of each energy meter connected to the target phase of the metering box smart terminal includes:

[0022] The line loss value of the target phase and the hourly serial electricity data of each electricity meter are input into the pre-built electricity meter line loss coefficient processing model.

[0023] If the electricity meter line loss coefficient processing model successfully outputs the electricity meter line loss coefficient processing result, the line loss coefficient of each electricity meter is determined based on the electricity meter line loss coefficient processing result.

[0024] In one embodiment, determining the line loss anomaly identification result of the energy meter based on the line loss coefficient includes:

[0025] If there is an abnormal line loss coefficient in the line loss coefficient of each of the energy meters, the energy meter corresponding to the abnormal line loss coefficient shall be identified as an energy meter with abnormal line loss.

[0026] Generate the electricity meter information corresponding to the electricity meter with abnormal line loss, and use it as the result of the electricity meter's abnormal line loss identification.

[0027] In one embodiment, after obtaining the measurement error for the smart terminal of the metering box, the method further includes:

[0028] If the measurement error exceeds the first preset value, an error over-tolerance alarm message is generated;

[0029] The error exceeding the tolerance alarm information is reported to the intelligent terminal of the distribution area.

[0030] Secondly, this application also provides a low-voltage distribution area line loss anomaly identification device. The device includes:

[0031] An information acquisition module is used to detect measurement errors in the smart terminal of the metering box; the metering box also includes an energy meter connected to the smart terminal of the metering box.

[0032] The data calculation module is used to acquire the clock value of the smart terminal of the metering box and the clock value of the electricity meter respectively, and calculate the clock deviation value between the clock value of the smart terminal of the metering box and the clock value of the electricity meter, provided that the metering error does not exceed a first preset value.

[0033] The data acquisition module is used to acquire the line loss value of the target phase at the metering box inlet when the clock deviation value does not exceed a second preset value; the target phase is any one of the phases at the metering box inlet.

[0034] A data update model is used to obtain the cumulative number of hourly electricity data values ​​corresponding to the target phase when the line loss value of the target phase exceeds a third preset value, and update the cumulative number to obtain the updated cumulative number.

[0035] The loop execution module is used to jump to the step of obtaining the line loss value of the target phase at the metering box inlet when the updated cumulative number is less than the fourth preset value, until the updated cumulative number is greater than or equal to the fourth preset value.

[0036] The result determination model is used to determine the line loss coefficient of each energy meter based on the line loss value of the target phase and the hourly sequence energy data of each energy meter connected to the target phase of the metering box smart terminal when the updated cumulative number is greater than or equal to the fourth preset value, and to determine the line loss anomaly identification result of the energy meter based on the line loss coefficient.

[0037] Thirdly, this application also provides a computer device. The computer device includes a memory and a processor, the memory storing a computer program, and the processor executing the computer program to perform the following steps:

[0038] The metering error is obtained for the smart terminal of the metering box in the metering box; the metering box also includes an energy meter connected to the smart terminal of the metering box;

[0039] If the metering error does not exceed the first preset value, the clock value of the smart terminal of the metering box and the clock value of the electricity meter are obtained respectively, and the clock deviation value between the clock value of the smart terminal of the metering box and the clock value of the electricity meter is calculated.

[0040] If the clock deviation value does not exceed the second preset value, obtain the line loss value of the target phase at the metering box inlet; the target phase is any one of the phases at the metering box inlet.

[0041] If the line loss value of the target phase exceeds a third preset value, the cumulative number of times the hourly electricity data value corresponding to the target phase is obtained, and the cumulative number is updated to obtain the updated cumulative number.

[0042] If the updated cumulative number is less than the fourth preset value, the process jumps to the step of obtaining the line loss value of the target phase at the metering box inlet when the clock deviation value does not exceed the second preset value, until the updated cumulative number is greater than or equal to the fourth preset value;

[0043] If the updated cumulative number is greater than or equal to the fourth preset value, the line loss coefficient of each energy meter is determined based on the line loss value of the target phase and the hourly sequence energy data of each energy meter connected to the target phase of the metering box smart terminal. Based on the line loss coefficient, the line loss anomaly identification result of the energy meter is determined.

[0044] Fourthly, this application also provides a computer-readable storage medium. The computer-readable storage medium stores a computer program thereon, which, when executed by a processor, performs the following steps:

[0045] The metering error is obtained for the smart terminal of the metering box in the metering box; the metering box also includes an energy meter connected to the smart terminal of the metering box;

[0046] If the metering error does not exceed the first preset value, the clock value of the smart terminal of the metering box and the clock value of the electricity meter are obtained respectively, and the clock deviation value between the clock value of the smart terminal of the metering box and the clock value of the electricity meter is calculated.

[0047] If the clock deviation value does not exceed the second preset value, obtain the line loss value of the target phase at the metering box inlet; the target phase is any one of the phases at the metering box inlet.

[0048] If the line loss value of the target phase exceeds a third preset value, the cumulative number of times the hourly electricity data value corresponding to the target phase is obtained, and the cumulative number is updated to obtain the updated cumulative number.

[0049] If the updated cumulative number is less than the fourth preset value, the process jumps to the step of obtaining the line loss value of the target phase at the metering box inlet when the clock deviation value does not exceed the second preset value, until the updated cumulative number is greater than or equal to the fourth preset value;

[0050] If the updated cumulative number is greater than or equal to the fourth preset value, the line loss coefficient of each energy meter is determined based on the line loss value of the target phase and the hourly sequence energy data of each energy meter connected to the target phase of the metering box smart terminal. Based on the line loss coefficient, the line loss anomaly identification result of the energy meter is determined.

[0051] Fifthly, this application also provides a computer program product. The computer program product includes a computer program that, when executed by a processor, performs the following steps:

[0052] The metering error is obtained for the smart terminal of the metering box in the metering box; the metering box also includes an energy meter connected to the smart terminal of the metering box;

[0053] If the metering error does not exceed the first preset value, the clock value of the smart terminal of the metering box and the clock value of the electricity meter are obtained respectively, and the clock deviation value between the clock value of the smart terminal of the metering box and the clock value of the electricity meter is calculated.

[0054] If the clock deviation value does not exceed the second preset value, obtain the line loss value of the target phase at the metering box inlet; the target phase is any one of the phases at the metering box inlet.

[0055] If the line loss value of the target phase exceeds a third preset value, the cumulative number of times the hourly electricity data value corresponding to the target phase is obtained, and the cumulative number is updated to obtain the updated cumulative number.

[0056] If the updated cumulative number is less than the fourth preset value, the process jumps to the step of obtaining the line loss value of the target phase at the metering box inlet when the clock deviation value does not exceed the second preset value, until the updated cumulative number is greater than or equal to the fourth preset value;

[0057] If the updated cumulative number is greater than or equal to the fourth preset value, the line loss coefficient of each energy meter is determined based on the line loss value of the target phase and the hourly sequence energy data of each energy meter connected to the target phase of the metering box smart terminal. Based on the line loss coefficient, the line loss anomaly identification result of the energy meter is determined.

[0058] The aforementioned low-voltage distribution area line loss anomaly identification method, device, computer equipment, storage medium, and computer program product acquire the metering error of the smart terminal in the metering box; if the metering error does not exceed a first preset value, acquire the clock value of the smart terminal and the clock value of the energy meter respectively, and calculate the clock deviation value between the clock value of the smart terminal and the clock value of the energy meter; if the clock deviation value does not exceed a second preset value, acquire the line loss value of the target phase at the metering box inlet; if the line loss value of the target phase exceeds a third preset value, acquire the cumulative hourly electricity data value corresponding to the target phase. The system updates the cumulative count to obtain the updated cumulative count. If the updated cumulative count is less than the fourth preset value, it jumps to the step of obtaining the line loss value of the target phase at the metering box inlet, provided that the clock deviation value does not exceed the second preset value, until the updated cumulative count is greater than or equal to the fourth preset value. Finally, if the updated cumulative count is greater than or equal to the fourth preset value, the system determines the line loss coefficient of each energy meter based on the line loss value of the target phase and the hourly sequence energy data of each energy meter connected to the target phase of the metering box smart terminal. Based on the line loss coefficient, the system determines the line loss anomaly identification result of the energy meter.In this way, the metering error of the smart terminal in the metering box is first obtained, and further judgment can be made based on this metering error data. If the metering error does not exceed the first preset value, the clock values ​​of the smart terminal and the electricity meter are obtained respectively, so as to accurately calculate the clock deviation value between the clock values ​​of the smart terminal and the electricity meter. If the clock deviation value does not exceed the second preset value, the line loss value of the target phase at the metering box inlet is obtained, and subsequent judgments can be made based on this objective value of the line loss value of the target phase. If the line loss value of the target phase exceeds the third preset value, the cumulative number of hourly electricity data values ​​corresponding to the target phase is obtained, and the cumulative number is updated to obtain the updated cumulative number, thereby realizing the real-time update of the cumulative number of hourly electricity data values ​​corresponding to the target phase. If the updated cumulative number is less than the fourth preset value, the judgment is made based on the first preset value. If the clock deviation value does not exceed the second preset value, the process jumps to the step of obtaining the line loss value of the target phase at the metering box inlet, until the updated cumulative count is greater than or equal to the fourth preset value, thus establishing a cyclical process system. The cyclical system exits only when the target condition is met. Finally, if the updated cumulative count is greater than or equal to the fourth preset value, the line loss coefficient of each energy meter is determined based on the line loss value of the target phase and the hourly sequence electricity data of each energy meter connected to the target phase of the metering box smart terminal. Based on the line loss coefficient, the line loss anomaly identification result of the energy meter is determined. This realizes the real-time online monitoring and analysis function of the metering box line loss result, which greatly reduces the time spent identifying line loss anomalies in low-voltage distribution areas. Moreover, the whole process does not require manual intervention, thus avoiding the tedious process of manually judging whether there are line loss anomalies, thereby improving the monitoring efficiency of line loss anomalies in low-voltage distribution areas. Attached Figure Description

[0059] Figure 1 This is an application environment diagram of a low-voltage distribution area line loss anomaly identification method in one embodiment;

[0060] Figure 2 This is a flowchart illustrating a method for identifying abnormal line losses in low-voltage distribution areas in one embodiment.

[0061] Figure 3 This is a schematic diagram of the metering box in one embodiment;

[0062] Figure 4 This is a schematic diagram of the intelligent terminal for the metering box in one embodiment;

[0063] Figure 5 This is a schematic diagram of the low-voltage topology and power data collection in an existing residential community in one embodiment;

[0064] Figure 6This is a flowchart illustrating a low-voltage distribution area line loss anomaly identification method in another embodiment;

[0065] Figure 7 This is a flowchart illustrating the low-voltage distribution area line loss anomaly identification method in yet another embodiment;

[0066] Figure 8 This is a structural block diagram of a low-voltage distribution area line loss anomaly identification device in one embodiment;

[0067] Figure 9 This is an internal structural diagram of a computer device in one embodiment. Detailed Implementation

[0068] 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.

[0069] The low-voltage distribution area line loss anomaly identification method provided in this application embodiment can be applied to, for example... Figure 1 In the application environment shown, the intelligent terminal 101 of the metering box communicates with electricity meters A1, A2, A3, A4, B1, B2, C1, and C3 via signal lines. It should be noted that line loss is a shorthand term for power loss in the power supply line, and an electricity meter is a device installed on the power supply line.

[0070] Specifically, refer to Figure 1 The metering box smart terminal 101 acquires the metering error for the metering box smart terminal within the metering box; if the metering error does not exceed a first preset value, it acquires the clock value of the metering box smart terminal and the clock value of the energy meter, respectively, and calculates the clock deviation value between the clock value of the metering box smart terminal and the clock value of the energy meter; if the clock deviation value does not exceed a second preset value, it acquires the line loss value of the target phase at the metering box inlet; if the line loss value of the target phase exceeds a third preset value, it acquires the cumulative count of the hourly electricity data value corresponding to the target phase, and updates the cumulative count. Obtain the updated cumulative count; if the updated cumulative count is less than the fourth preset value, proceed to the step of obtaining the line loss value of the target phase at the meter box inlet if the clock deviation value does not exceed the second preset value, until the updated cumulative count is greater than or equal to the fourth preset value; if the updated cumulative count is greater than or equal to the fourth preset value, determine the line loss coefficient of each energy meter based on the line loss value of the target phase and the hourly sequence energy data of each energy meter connected to the target phase of the meter box smart terminal, and determine the line loss anomaly identification result of the energy meter based on the line loss coefficient.

[0071] Among them, the metering box intelligent terminal 101 is an intelligent integrated terminal device that integrates equipment status monitoring and communication networking, local analysis and decision-making, collaborative computing and other functions. It is used to collect and process various electrical parameters on the low-voltage side of the distribution transformer and transmit these parameters to the upper level. Its hardware adopts a platform design, supports edge computing framework, and can achieve flexible function expansion in a software-defined manner. Electricity meter A1, electricity meter A2, electricity meter A3, electricity meter A4, electricity meter B1, electricity meter B2, electricity meter C1, electricity meter C3 and electricity meter C3 are all instruments used to measure electrical energy, also known as electricity meters, kilowatt-hour meters, and refer to instruments that measure various electrical quantities.

[0072] In one embodiment, such as Figure 2 As shown, a method for identifying abnormal line losses in low-voltage distribution areas is provided, and this method is applied to... Figure 1 Taking the intelligent terminal of the metering box as an example, the explanation includes the following steps:

[0073] Step S201: Obtain the metering error for the smart terminal of the metering box in the metering box; the metering box also includes an energy meter connected to the smart terminal of the metering box.

[0074] Among them, such as Figure 3 As shown, the metering box (with a smart terminal installed in the lower left corner and an energy meter installed in the upper right corner) refers to the total set of metering instruments and auxiliary equipment necessary for measuring electrical energy, including energy meters, voltage and current transformers and their secondary circuits, energy metering panels, cabinets, boxes, etc.

[0075] Among them, such as Figure 4 As shown, the metering box intelligent terminal is an intelligent integrated terminal device that integrates functions such as equipment status monitoring and communication networking, local analysis and decision-making, and collaborative computing. It is used to collect and process various electrical parameters on the low-voltage side of the distribution transformer and transmit these parameters to the upper level.

[0076] Among them, the electricity meter is an instrument used to measure electrical energy, also known as an electricity meter, fire meter, or kilowatt-hour meter, which refers to an instrument that measures various electrical quantities.

[0077] Among them, the measurement error of the metering box intelligent terminal refers to the error value of the measurement data of the metering box intelligent terminal.

[0078] Specifically, in response to the electricity meter's request for abnormal line loss identification, the smart terminal of the metering box generates a metering error acquisition instruction and acquires the metering error for the smart terminal of the metering box based on the metering error acquisition instruction.

[0079] For example, the error self-monitoring function of the metering box smart terminal is turned on daily, and the calculated metering error for the metering box smart terminal is 0.2.

[0080] In step S202, if the metering error does not exceed the first preset value, the clock value of the smart terminal of the metering box and the clock value of the electricity meter are obtained respectively, and the clock deviation value between the clock value of the smart terminal of the metering box and the clock value of the electricity meter is calculated.

[0081] The first preset value is a pre-set value that can be set to twice the maximum permissible error value of the metering box smart terminal.

[0082] The clock value of the metering box smart terminal refers to the usage time reading of the metering box smart terminal.

[0083] The clock value of the electricity meter refers to the reading of the electricity meter during its usage time.

[0084] The clock deviation value refers to the difference between the usage time reading of the smart terminal of the metering box and the usage time reading of the electricity meter.

[0085] Specifically, when the metering error does not exceed the first preset value, the smart terminal of the metering box acquires the clock value of the smart terminal of the metering box and the clock value of each energy meter in the target phase, and then calculates the difference between the clock value of the smart terminal of the metering box and the clock value of each energy meter.

[0086] For example, if the metering error is 0.2 and the first preset value is 0.4, then the metering error does not exceed the first preset value. The clock value of the smart terminal of the metering box is 30 min, and the clock values ​​of each electricity meter are 30.1 min, 30.3 min, and 29.8 min, respectively. The clock deviation values ​​between the clock value of the smart terminal of the metering box and the clock value of the electricity meter are calculated to be 0.1 min, 0.3 min, and 0.2 min, respectively.

[0087] Step S203: If the clock deviation value does not exceed the second preset value, obtain the line loss value of the target phase at the metering box inlet; the target phase is any one of the phases at the metering box inlet.

[0088] The second preset value is a pre-set value, such as 1 minute.

[0089] Among them, the line loss value refers to the difference between the hourly electricity value of a certain phase measured by the terminal and the sum of the hourly electricity values ​​of all electricity meters connected to that phase.

[0090] It should be noted that the metering box inlet includes three phases: A, B, and C.

[0091] Specifically, when the clock deviation value does not exceed the second preset value, the smart terminal of the metering box obtains the hourly power consumption value of the target phase and the hourly power consumption value of each energy meter connected to the target phase, first calculates the sum of the hourly power consumption values ​​of each energy meter connected to the target phase, and then calculates the line loss value of the target phase at the metering box inlet.

[0092] For example, if the clock deviation value does not exceed the second preset value, the smart terminal of the metering box reads the hourly electricity consumption data from the electricity meter. Then, the formula for calculating the line loss value (i.e., the electricity difference) of phase X (phases A, B, and C) is C. x =D x -S x1 -S x2 -...-S xM C x The difference in electrical charge between phase X and phase D. x The hourly electricity consumption value of phase X for terminal metering, S x1 The terminal reads the hourly electricity consumption value of the electricity meter x1 connected to phase X.

[0093] Step S204: If the line loss value of the target phase exceeds the third preset value, obtain the cumulative number of times the hourly power data value corresponding to the target phase is accumulated, update the cumulative number of times, and obtain the updated cumulative number of times.

[0094] It should be noted that the third preset value is the threshold K, where threshold K = K c × (Total power consumption of electricity meters connected to this phase line + Maximum line loss under operating conditions of highest operating temperature and maximum load current), where K c Margin factor (e.g., take 2).

[0095] Among them, the cumulative number of hourly electricity data values ​​refers to the cumulative number of times one active power value is transferred every hour.

[0096] Specifically, when the line loss value of the target phase exceeds the third preset value, the smart terminal of the metering box acquires the cumulative number of times the hourly electricity data value corresponding to the target phase is accumulated, adds 1 to the original cumulative number, and transfers the line loss value of the target phase, as well as the hourly serial electricity data of each electricity meter connected to the target phase.

[0097] For example, if the line loss value of the target phase exceeds the third preset value, the smart terminal of the metering box will acquire the hourly electricity data value corresponding to the target phase a cumulative number of times, add 1 to the original cumulative number, and transfer the line loss value of the target phase of 10 kWh, as well as the hourly electricity data of each electricity meter connected to the target phase of 180 kWh, 360 kWh and 720 kWh.

[0098] Step S205: If the updated cumulative count is less than the fourth preset value, proceed to the step of obtaining the line loss value of the target phase at the metering box inlet if the clock deviation value does not exceed the second preset value, until the updated cumulative count is greater than or equal to the fourth preset value.

[0099] The fourth preset value is numerically equal to the number of electricity meters connected to the target phase plus 1.

[0100] Specifically, the metering box intelligent terminal determines the relationship between the updated cumulative count and the fourth preset value. If the updated cumulative count is less than the fourth preset value, it jumps to the step of obtaining the line loss value of the target phase at the metering box inlet when the clock deviation value does not exceed the second preset value. This step is repeated until the updated cumulative count is greater than or equal to the fourth preset value.

[0101] For example, if the updated cumulative count is 2 and the fourth preset value is 4, and the updated cumulative count is less than the fourth preset value, the metering box smart terminal will jump to the step of obtaining the line loss value of the target phase at the metering box inlet when the clock deviation value does not exceed the second preset value, and will continue to repeat this step until the updated cumulative count is greater than or equal to the fourth preset value.

[0102] Step S206: If the updated cumulative number of times is greater than or equal to the fourth preset value, determine the line loss coefficient of each energy meter based on the line loss value of the target phase and the hourly sequence energy data of each energy meter connected to the target phase of the metering box smart terminal, and determine the line loss anomaly identification result of the energy meter based on the line loss coefficient.

[0103] Among them, the hourly sequence electricity consumption data of the electricity meter refers to the electricity consumption data of the previous hour recorded by the electricity meter.

[0104] Among them, the line loss coefficient is a numerical value that describes the degree of line loss.

[0105] Abnormal line loss refers to the phenomenon that the line loss coefficient of the electricity meter is significantly higher than normal.

[0106] Specifically, when the cumulative number of updates is greater than or equal to the fourth preset value, the smart terminal of the metering box obtains the line loss value of the target phase and the hourly serial electricity data of each electricity meter connected to the target phase of the smart terminal of the metering box. Based on the line loss value of the target phase and the hourly serial electricity data of each electricity meter, the line loss coefficient of each electricity meter is calculated. Based on the magnitude of the line loss coefficient, it is determined whether there is an abnormal line loss phenomenon of the electricity meter.

[0107] For example, if the updated cumulative count is 4 and the fourth preset value is 4, then the updated cumulative count is equal to the fourth preset value. The metering box smart terminal obtains the line loss value of the target phase and the hourly series power consumption data of each energy meter connected to the target phase of the metering box smart terminal. Based on the line loss value of the target phase and the hourly series power consumption data of each energy meter, the line loss coefficient of each energy meter is calculated to be 3, 3.1, or 6. Based on the magnitude of the line loss coefficient, the energy meter with a line loss coefficient of 6 is identified as an energy meter with abnormal line loss.

[0108] In the aforementioned method for identifying abnormal line losses in low-voltage distribution areas, the metering error of the smart terminal in the metering box is first obtained. Further judgment can be made based on this metering error data. If the metering error does not exceed a first preset value, the clock values ​​of the smart terminal and the electricity meter are obtained respectively, thereby accurately calculating the clock deviation between them. If the clock deviation does not exceed a second preset value, the line loss value of the target phase at the metering box inlet is obtained, and subsequent judgments can be made based on this objective value. If the line loss value of the target phase exceeds a third preset value, the cumulative count of the hourly electricity consumption data corresponding to the target phase is obtained, and the cumulative count is updated to obtain the updated cumulative count, thus achieving real-time updating of the cumulative count of the hourly electricity consumption data corresponding to the target phase. If the number of occurrences is less than the fourth preset value, the process jumps to the step of obtaining the line loss value of the target phase at the metering box inlet, provided that the clock deviation value does not exceed the second preset value. This process continues until the updated cumulative count is greater than or equal to the fourth preset value, thus establishing a cyclical workflow. The loop exits only when the target condition is met. Finally, if the updated cumulative count is greater than or equal to the fourth preset value, the line loss coefficient of each energy meter is determined based on the line loss value of the target phase and the hourly sequence electricity data of each energy meter connected to the target phase of the metering box's smart terminal. Based on the line loss coefficient, the line loss anomaly identification result of the energy meter is determined. This achieves real-time online monitoring and analysis of the metering box's line loss results, greatly reducing the time required to identify line loss anomalies in low-voltage distribution areas. The entire process requires no manual intervention, thus avoiding the tedious process of manually judging whether line loss anomalies exist, thereby improving the monitoring efficiency of line loss anomalies in low-voltage distribution areas.

[0109] In one embodiment, before obtaining the clock value of the smart terminal of the metering box and the clock value of the energy meter connected to the smart terminal of the metering box, step S202 above also includes the following: identifying whether the topology of the metering box has changed; if the topology of the metering box has changed, updating the topology information of the smart terminal of the metering box and clearing the hourly power data value of the target phase at the metering box inlet to zero.

[0110] Step S202 above involves obtaining the clock value of the smart terminal of the metering box and the clock value of the electricity meter connected to the smart terminal of the metering box, specifically including the following: without changing the topology of the metering box, obtaining the clock value of the smart terminal of the metering box and the clock value of the electricity meter connected to the smart terminal of the metering box.

[0111] Topology refers to the physical layout that connects various devices such as computers to each other using transmission media. It refers to the geometric shape formed during the interconnection process and can represent the network configuration of network servers and workstations and their interconnection relationships.

[0112] Topological information refers to information used to describe the number of components constituting the device and their interconnections.

[0113] Specifically, the smart terminal of the metering box activates the topology recognition function to identify whether the topology of the metering box has changed; if the topology of the metering box has changed, the topology information of the smart terminal of the metering box is updated, and the target phase hourly power data value at the metering box inlet that has changed is reset to 0; if the topology of the metering box has not changed, the clock value of the smart terminal of the metering box and the clock value of the energy meter connected to the smart terminal of the metering box are obtained respectively.

[0114] In this embodiment, the topology of the metering box is identified to determine if it has changed. If the topology of the metering box has changed, the topology information of the metering box's smart terminal is updated, and the hourly electricity data value of the target phase at the metering box's inlet is cleared. If the topology of the metering box has not changed, the clock value of the metering box's smart terminal and the clock value of the electricity meter connected to the metering box's smart terminal are obtained respectively. This effectively eliminates the interference of the metering box's topology and accurately obtains the clock value of the metering box's smart terminal and the clock value of the electricity meter connected to the metering box's smart terminal.

[0115] In one embodiment, step S203 above, obtaining the line loss value of the target phase at the metering box inlet, specifically includes the following: obtaining the first hour's electricity data value of the smart terminal of the metering box under the target phase at the metering box inlet, and the second hour's electricity data value of the electricity meter connected to the target phase at the metering box inlet; inputting the first hour's electricity data value and the second hour's electricity data value into a pre-built phase line loss data processing model to obtain the line loss value of the target phase at the metering box inlet.

[0116] The first hour's electricity data value refers to the hourly electricity data value of the target phase at the metering box inlet.

[0117] The second hour's electricity data value refers to the hourly electricity data value of each electricity meter connected to the target phase at the metering box inlet.

[0118] Specifically, the smart terminal of the metering box reads the first hour's electricity data value of the target phase at the metering box inlet and the second hour's electricity data value of the electricity meter connected to the target phase at the metering box inlet; the first hour's electricity data value and the second hour's electricity data value of the electricity meter are respectively input into a pre-built phase line loss data processing model for fusion calculation to obtain the line loss value of the target phase at the metering box inlet.

[0119] For example, when the smart terminal of the metering box reads the electricity data value of the first hour under the target phase at the metering box inlet, the formula for calculating the line loss value (i.e., electricity difference) of phase X (phases A, B, and C) is C. x =D x -S x1 -S x2 -...-S xM C x The difference in electrical charge between phase X and phase D. x The hourly electricity consumption data value of phase X for terminal metering, S x1 The terminal reads the hourly electricity consumption data of the electricity meter x1 connected to phase X.

[0120] In this embodiment, the first hour's electricity data value of the target phase at the metering box inlet is obtained by the smart terminal of the metering box, and the second hour's electricity data value of the electricity meter connected to the target phase at the metering box inlet is obtained. The first hour's electricity data value and the second hour's electricity data value are then input into a pre-built phase line loss data processing model, so as to accurately calculate the line loss value of the target phase at the metering box inlet.

[0121] In one embodiment, step S206, which determines the line loss coefficient of each energy meter based on the line loss value of the target phase and the hourly serial energy data of each energy meter connected to the target phase of the metering box smart terminal, specifically includes the following: inputting the line loss value of the target phase and the hourly serial energy data of each energy meter into a pre-built energy meter line loss coefficient processing model; and, if the energy meter line loss coefficient processing model successfully outputs the energy meter line loss coefficient processing result, determining the line loss coefficient of each energy meter based on the energy meter line loss coefficient processing result.

[0122] It should be noted that the model for handling the line loss coefficient of electricity meters is a system of equations consisting of multiple equations, in the following form:

[0123] C xM =Y1S x1 +Y2S x2 +Y3S x3+...+Y M S xM +E

[0124] In the equation, C represents the line loss value of the target phase calculated at a specified time, Y represents the line loss coefficient (unknown) of a certain energy meter, and S represents the hourly electricity consumption data of a certain energy meter (e.g., S = 13:00-14:00). x1 180kWh, ...S xM (720kWh is one sequence), E is the inherent line loss of the metering box (unknown).

[0125] The result of processing the line loss coefficient of the electricity meter is the solution to the system of equations.

[0126] Specifically, the smart terminal of the metering box acquires the line loss value of the target phase and the hourly series power consumption data of each power meter, and inputs the line loss value of the target phase and the hourly series power consumption data of each power meter into a pre-built power meter line loss coefficient processing model to solve the system of equations; if the system of equations has a solution, the line loss coefficient of each power meter is determined based on the solution of the system of equations.

[0127] In this embodiment, the line loss value of the target phase and the hourly serial electricity data of each electricity meter are input into a pre-constructed electricity meter line loss coefficient processing model. The equation system is then solved by the calculation model, avoiding the manual calculation process. When the electricity meter line loss coefficient processing model successfully outputs the electricity meter line loss coefficient processing result, the line loss coefficient of each electricity meter is determined based on the electricity meter line loss coefficient processing result, thereby accurately obtaining the line loss coefficient of each electricity meter.

[0128] In one embodiment, step S206 above, which determines the line loss anomaly identification result of the electricity meter based on the line loss coefficient, specifically includes the following: if there is an abnormal line loss coefficient in the line loss coefficient of each electricity meter, the electricity meter corresponding to the abnormal line loss coefficient is identified as an electricity meter with abnormal line loss; and electricity meter information corresponding to the electricity meter with abnormal line loss is generated as the line loss anomaly identification result of the electricity meter.

[0129] Among them, the abnormal line loss coefficient refers to line loss data that is significantly too high.

[0130] Among them, an energy meter with abnormal line loss refers to an energy meter that exhibits abnormal line loss, where the line loss data of the energy meter is significantly higher than normal.

[0131] Specifically, the smart terminal of the metering box determines whether there is an abnormal line loss coefficient in the line loss coefficient of each electricity meter. If there is an abnormal line loss coefficient, the electricity meter corresponding to the abnormal line loss coefficient is identified as an electricity meter with abnormal line loss. For the electricity meter with abnormal line loss, the corresponding electricity meter information is generated and reported as the line loss abnormality identification result of the electricity meter.

[0132] In this embodiment, when there is an abnormal line loss coefficient in the line loss coefficient of each electricity meter, the electricity meter corresponding to the abnormal line loss coefficient is identified as an electricity meter with abnormal line loss, and electricity meter information corresponding to the electricity meter with abnormal line loss is generated as the line loss abnormality identification result of the electricity meter, thereby accurately screening out electricity meters with abnormal line loss and effectively obtaining the electricity meter information corresponding to the electricity meter with abnormal line loss.

[0133] In one embodiment, after obtaining the measurement error for the smart terminal of the metering box, step S201 further includes the following: if the measurement error exceeds a first preset value, generating an error over-tolerance alarm message; and reporting the error over-tolerance alarm message to the smart terminal of the distribution area.

[0134] Among them, such as Figure 5 As shown in the figure (which includes multiple transformer area smart terminals), a transformer area smart terminal refers to a terminal device that is positioned at the core of the low-voltage power distribution Internet of Things, adopts a platform-based hardware design and edge computing architecture, and supports local data storage and decision analysis.

[0135] Specifically, the intelligent terminal of the metering box determines whether the metering error exceeds the first preset value. If the metering error exceeds the first preset value, it generates an error over-tolerance alarm and reports the error over-tolerance alarm to the intelligent terminal of the distribution area.

[0136] For example, if the measurement error is 0.5 and the first preset value is 0.4, and the measurement error exceeds the first preset value, the intelligent terminal of the metering box will generate an error over-tolerance alarm message and report the error over-tolerance alarm message to the intelligent terminal of the distribution area.

[0137] In this embodiment, when the measurement error exceeds a first preset value, an error over-tolerance alarm is generated and reported to the smart terminal in the distribution area; thereby accurately identifying measurement errors with excessively large error values ​​and avoiding interference from excessively large measurement errors.

[0138] In one embodiment, such as Figure 6 As shown, another method for identifying abnormal line losses in low-voltage distribution areas is provided, which specifically includes the following steps:

[0139] Step S601: Obtain the metering error for the smart terminal of the metering box in the metering box; the metering box also includes an energy meter connected to the smart terminal of the metering box.

[0140] Step S602: If the measurement error exceeds the first preset value, generate an error over-tolerance alarm message; and report the error over-tolerance alarm message to the smart terminal of the distribution area.

[0141] Step S603: If the metering error does not exceed the first preset value, identify whether the topology of the metering box has changed; if the topology of the metering box has changed, update the topology information of the metering box smart terminal and clear the hourly power data value of the target phase at the metering box inlet.

[0142] Step S604: Obtain the clock value of the smart terminal of the metering box and the clock value of the energy meter connected to the smart terminal of the metering box, and calculate the clock deviation value between the clock value of the smart terminal of the metering box and the clock value of the energy meter.

[0143] Step S605: If the clock deviation value does not exceed the second preset value, obtain the first hour's power consumption data value of the smart terminal of the metering box under the target phase at the metering box inlet, and the second hour's power consumption data value of the energy meter connected to the target phase at the metering box inlet.

[0144] Step S606: Input the first hour's power consumption data value and the second hour's power consumption data value into the pre-constructed phase line loss data processing model to obtain the line loss value of the target phase at the metering box inlet; the target phase is any one of the phases at the metering box inlet.

[0145] Step S607: If the line loss value of the target phase exceeds the third preset value, obtain the cumulative number of times the hourly power data value corresponding to the target phase is accumulated, update the cumulative number of times, and obtain the updated cumulative number of times.

[0146] Step S608: If the updated cumulative number of times is less than the fourth preset value, proceed to the step of obtaining the line loss value of the target phase at the metering box inlet if the clock deviation value does not exceed the second preset value, until the updated cumulative number of times is greater than or equal to the fourth preset value.

[0147] Step S609: If the updated cumulative number of times is greater than or equal to the fourth preset value, input the line loss value of each electricity meter at the current moment and the hourly series electricity data of each electricity meter into the pre-built electricity meter line loss coefficient processing model.

[0148] Step S610: If the electricity meter line loss coefficient processing model successfully outputs the electricity meter line loss coefficient processing result, determine the line loss coefficient of each electricity meter based on the electricity meter line loss coefficient processing result.

[0149] Step S611: If there is an abnormal line loss coefficient in the line loss coefficient of each electricity meter, the electricity meter corresponding to the abnormal line loss coefficient is identified as an abnormal line loss electricity meter; generate the electricity meter information corresponding to the abnormal line loss electricity meter as the line loss abnormal identification result of the electricity meter.

[0150] In the aforementioned method for identifying abnormal line losses in low-voltage distribution areas, the metering error of the smart terminal in the metering box is first obtained. Further judgment can be made based on this metering error data. If the metering error exceeds a first preset value, an error over-tolerance alarm is generated and reported to the distribution area smart terminal, thus accurately identifying excessively large metering errors and avoiding interference from such errors. If the metering error does not exceed the first preset value and the topology remains unchanged, the clock values ​​of the smart terminal and the energy meter are obtained, respectively, to accurately calculate the clock deviation between them. If the clock deviation does not exceed a second preset value, the line loss value of the target phase at the metering box inlet is calculated using a pre-built phase line loss data processing model, allowing for subsequent judgment based on this objective value. If the line loss value of the target phase exceeds a third preset value, the cumulative count of the hourly electricity data corresponding to the target phase is obtained and updated to obtain the updated cumulative count. This system enables real-time updates of the cumulative count of hourly electricity consumption data corresponding to the target phase. If the updated cumulative count is less than a fourth preset value, the system jumps to the step of obtaining the line loss value of the target phase at the metering box inlet, provided the clock deviation value does not exceed a second preset value. This process continues until the updated cumulative count is greater than or equal to the fourth preset value, thus establishing a cyclical workflow. The system exits the loop only when the target condition is met. Finally, if the updated cumulative count is greater than or equal to the fourth preset value, the system determines the line loss coefficient of each electricity meter based on the line loss value of the target phase and the hourly electricity consumption data of each electricity meter connected to the target phase of the metering box's intelligent terminal. If an abnormal line loss coefficient exists in the line loss coefficient of each electricity meter, the electricity meter corresponding to the abnormal line loss coefficient is identified as a line loss abnormality electricity meter. This system enables real-time online monitoring and analysis of the metering box's line loss results, significantly reducing the time required to identify abnormal line loss phenomena in low-voltage distribution areas. The entire process requires no manual intervention, thus avoiding the tedious process of manually judging whether abnormal line loss phenomena exist, thereby improving the monitoring efficiency of abnormal line loss phenomena in low-voltage distribution areas.

[0151] To more clearly illustrate the low-voltage distribution area line loss anomaly identification method provided in this application, the following specific embodiment will be used to describe the line loss anomaly identification of the electricity meter. In one embodiment, such as Figure 7 As shown, this application also provides another method for identifying abnormal line losses in low-voltage distribution areas, specifically including the following steps:

[0152] Step 1: The meter's smart terminal error self-monitoring function is turned on daily to calculate and determine whether the metering error of the smart terminal exceeds the threshold.

[0153] Step 2: When the metering error of the smart terminal exceeds the threshold, an error over-tolerance alarm message is reported to the smart terminal in the distribution area; when the metering error of the smart terminal does not exceed the threshold, the topology recognition function of the smart terminal is activated to identify whether there is a change in the topology of the metering box.

[0154] Step 3: If the topology has changed, update the topology information in the smart terminal and set the Nx meter of the changed meter box X phase (A, B, C phases) hourly electricity consumption (one active power value is transferred every hour) to 0; if the topology has not changed, read the clock values ​​of the terminal and the electricity meter and calculate the clock deviation value between the terminal and the electricity meter.

[0155] Step 4: When the clock deviation between the terminal and the electricity meter exceeds the threshold, the smart terminal starts the time synchronization function of the electricity meter to complete the time synchronization; when the clock deviation between the terminal and the electricity meter does not exceed the threshold, the terminal's X-phase (A, B, C phases) hourly electricity consumption (one active power value is transferred every hour) data meter Nx is activated.

[0156] Step 5: The smart terminal reads the hourly electricity consumption data from the electricity meter and then calculates the line loss value of phase X (phases A, B, and C).

[0157] Step 6: If the line loss value of phase X (phases A, B, and C) does not exceed the threshold K, continue to step 5; if the line loss value of phase X (phases A, B, and C) exceeds the threshold, increment the terminal phase X (phases A, B, and C) hourly electricity consumption (storing 1 active power value every hour) data meter Nx by 1, and transfer the terminal metered hourly electricity consumption data and the read electricity meter hourly electricity consumption data.

[0158] Step 7: If the terminal X-phase hourly electricity consumption data meter Nx < (Mx+1) (where Mx is the number of electricity meters connected to phase X), then continue to step 5; if the terminal X-phase hourly electricity consumption data meter Nx ≥ (Mx+1), then use the following formula and the transferred hourly electricity consumption data to solve the system of equations (a total of Mx+1 equations form the system of equations, solving for Y1...Y). M There are M+1 unknowns in total, E, and M is generally no greater than 6, depending on the actual configuration of the meter box, as follows:

[0159] C xM =Y1S x1 +Y2S x2 +Y3S x3 +...+Y M S xM +E

[0160] Explanation: C represents the line loss value calculated at a specified moment, Y represents the line loss coefficient (unknown) of a specific energy meter, and S represents the hourly electricity consumption data of a specific energy meter (e.g., 13:00-S). x1 180kWh, ...S xM (720kWh is one sequence), E is the inherent line loss of the metering box (unknown).

[0161] Step 8: If the system of equations has a solution and the line loss coefficient of a certain energy meter is significantly larger, then the energy meter is determined to be an energy meter with abnormal line loss, and the terminal reports the information of the energy meter with abnormal line loss; if the system of equations has no solution or has a solution but the line loss coefficient is not significantly different, then the information of the energy meter with abnormal line loss is not reported (at this time, it is impossible to identify).

[0162] Step 9: Set the hourly power consumption (one active power value is transferred every hour) data meter Nx of phase X (phases A, B, and C) to 0, and continue to step 4.

[0163] In the above-mentioned method for identifying abnormal line loss in low-voltage distribution areas, the metering error of the smart terminal is first calculated and judged to see if it exceeds a threshold. If the metering error exceeds the threshold, an error over-tolerance alarm is generated and reported to the smart terminal in the distribution area, thereby accurately identifying metering errors with excessively large error values ​​and avoiding interference from such errors. If the metering error does not exceed the threshold and the topology has not changed, the clock values ​​of the smart terminal in the metering box and the electricity meter are read separately to accurately calculate the clock deviation between them. If the clock deviation does not exceed the threshold, the line loss value of phase X at the metering box inlet is calculated, allowing for subsequent judgments based on this objective value. If the line loss value of phase X exceeds the threshold, the hourly electricity data meter Nx for phase X is obtained, and the meter Nx is incremented by 1 to obtain the processed hourly electricity data meter Nx, thus achieving real-time updates to the hourly electricity data meter Nx corresponding to phase X. If the hourly electricity consumption data meter Nx is less than the fourth preset value, the process jumps to the step of obtaining the line loss value of phase X at the meter box inlet, provided that the clock deviation value does not exceed the second preset value. This continues until the hourly electricity consumption data meter Nx is greater than or equal to the fourth preset value, thus establishing a cyclical process. The process exits the cyclical system only when the target condition is met. Finally, when the hourly electricity consumption data meter Nx is greater than or equal to the fourth preset value, the line loss value of phase X and the hourly sequence electricity consumption data of each electricity meter connected to phase X of the meter box smart terminal are used to construct... The system of equations is solved to determine the line loss coefficient of each electricity meter. If the system of equations has a solution and the line loss coefficient of a certain electricity meter is significantly higher than normal, then the electricity meter is identified as having abnormal line loss, and the terminal reports the information of the electricity meter with abnormal line loss. This realizes the function of real-time online monitoring and analysis of the line loss results of the metering box, which greatly reduces the time required to identify abnormal line loss phenomena in low-voltage distribution areas. Moreover, the whole process does not require manual intervention, thus avoiding the tedious process of manually judging whether there are abnormal line loss phenomena, thereby improving the monitoring efficiency of abnormal line loss in low-voltage distribution areas.

[0164] 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 of other steps.

[0165] Based on the same inventive concept, this application also provides a low-voltage distribution area line loss anomaly identification device for implementing the aforementioned low-voltage distribution area line loss anomaly identification method. The solution provided by this device is similar to the implementation scheme described in the above method; therefore, the specific limitations of one or more low-voltage distribution area line loss anomaly identification device embodiments provided below can be found in the limitations of the low-voltage distribution area line loss anomaly identification method described above, and will not be repeated here.

[0166] In one embodiment, such as Figure 8 As shown, a low-voltage distribution area line loss anomaly identification device is provided, including: an information acquisition module 801, a data calculation module 802, a data acquisition module 803, a data update model 804, a loop execution module 805, and a result determination model 806, wherein:

[0167] The information acquisition module 801 is used to address the metering error of the metering box smart terminal in the metering box; the metering box also includes an energy meter connected to the metering box smart terminal.

[0168] The data calculation module 802 is used to acquire the clock value of the smart terminal of the metering box and the clock value of the electricity meter respectively, and calculate the clock deviation value between the clock value of the smart terminal of the metering box and the clock value of the electricity meter, provided that the metering error does not exceed the first preset value.

[0169] The data acquisition module 803 is used to acquire the line loss value of the target phase at the metering box inlet when the clock deviation value does not exceed the second preset value; the target phase is any one of the phases at the metering box inlet.

[0170] Data update model 804 is used to obtain the cumulative number of hours of electricity data corresponding to the target phase when the line loss value of the target phase exceeds the third preset value, update the cumulative number of hours of electricity data corresponding to the target phase, and obtain the updated cumulative number of hours of electricity data.

[0171] The loop execution module 805 is used to jump to the step of obtaining the line loss value of the target phase at the metering box inlet when the updated cumulative number is less than the fourth preset value and the clock deviation value does not exceed the second preset value, until the updated cumulative number is greater than or equal to the fourth preset value.

[0172] The result determines model 806, which is used to determine the line loss coefficient of each energy meter based on the line loss value of the target phase and the hourly sequence energy data of each energy meter connected to the target phase of the smart terminal of the metering box when the updated cumulative number is greater than or equal to the fourth preset value. Based on the line loss coefficient, the line loss anomaly identification result of the energy meter is determined.

[0173] In one embodiment, the low-voltage distribution area line loss anomaly identification device further includes a topology module for identifying whether the topology of the metering box has changed; if the topology of the metering box has changed, the topology information of the metering box smart terminal is updated, and the hourly power data value of the target phase at the metering box inlet is cleared to zero.

[0174] The data calculation module 802 is also used to acquire the clock value of the smart terminal of the metering box and the clock value of the energy meter connected to the smart terminal of the metering box, respectively, without changing the topology of the metering box.

[0175] In one embodiment, the data acquisition module 803 is further configured to acquire the first hour's electricity data value of the smart terminal of the metering box under the target phase at the metering box inlet, and the second hour's electricity data value of the electricity meter connected to the target phase at the metering box inlet; and input the first hour's electricity data value and the second hour's electricity data value into a pre-built phase line loss data processing model to obtain the line loss value of the target phase at the metering box inlet.

[0176] In one embodiment, the result determination model 806 is further used to input the line loss value of the target phase and the hourly series power consumption data of each power meter into a pre-built power meter line loss coefficient processing model; if the power meter line loss coefficient processing model successfully outputs the power meter line loss coefficient processing result, the line loss coefficient of each power meter is determined based on the power meter line loss coefficient processing result.

[0177] In one embodiment, the result determination model 806 is further used to identify the energy meter corresponding to the abnormal line loss coefficient as an abnormal line loss energy meter when there is an abnormal line loss coefficient in the line loss coefficient of each energy meter; and to generate energy meter information corresponding to the abnormal line loss energy meter as the line loss abnormality identification result of the energy meter.

[0178] In one embodiment, the low-voltage distribution area line loss anomaly identification device further includes an error alarm module, which is used to generate an error over-tolerance alarm message when the metering error exceeds a first preset value; and to report the error over-tolerance alarm message to the distribution area smart terminal.

[0179] Each module in the aforementioned low-voltage distribution area line loss anomaly identification device can be implemented entirely or partially through software, hardware, or a combination thereof. These modules can be embedded in the processor of a computer device in hardware form or independent of it, or stored in the memory of a computer device in software form, so that the processor can call and execute the corresponding operations of each module.

[0180] In one embodiment, a computer device is provided, which may be a terminal, and its internal structure diagram may be as follows: Figure 9 As shown, the computer device includes a processor, memory, input / output interface, communication interface, display unit, and input device. The processor, memory, and input / output interface are connected via a system bus, and the communication interface, display unit, and input device are also connected to the system bus via the input / output interface. The processor provides computing and control capabilities. The memory includes non-volatile storage media and internal memory. The non-volatile storage media stores the operating system and computer programs. The internal memory provides an environment for the operation of the operating system and computer programs in the non-volatile storage media. The input / output interface is used for exchanging information between the processor and external devices. The communication interface is used for wired or wireless communication with external terminals; wireless communication can be achieved through Wi-Fi, mobile cellular networks, NFC (Near Field Communication), or other technologies. When executed by the processor, the computer program implements a method for identifying abnormal line loss in low-voltage distribution areas. The display unit is used to form a visually visible image and can be a display screen, projection device, or virtual reality imaging device. The display screen can be an LCD screen or an e-ink screen. The input device of the computer device can be a touch layer covering the display screen, or buttons, trackballs, or touchpads set on the casing of the computer device, or external keyboards, touchpads, or mice, etc.

[0181] Those skilled in the art will understand that Figure 9 The structure shown is merely a block diagram of a portion of the structure related to the present application and does not constitute a limitation on the computer device to which the present application is applied. Specific computer devices may include more or fewer components than those shown in the figure, or combine certain components, or have different component arrangements.

[0182] In one embodiment, a computer device is also provided, including a memory and a processor, wherein the memory stores a computer program, and the processor executes the computer program to implement the steps in the above method embodiments.

[0183] 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.

[0184] 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.

[0185] It should be noted that the user information (including but not limited to user device information, user personal information, etc.) and data (including but not limited to data used for analysis, data stored, data displayed, etc.) involved in this application are all information and data authorized by the user or fully authorized by all parties, and the collection, use and processing of the relevant data shall comply with the relevant laws, regulations and standards of the relevant countries and regions.

[0186] 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 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, etc., and are not limited to these.

[0187] 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 specification.

[0188] 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 identifying abnormal line losses in low-voltage distribution areas, characterized in that, The method includes: The metering error is obtained for the smart terminal of the metering box in the metering box; the metering box also includes an energy meter connected to the smart terminal of the metering box; If the metering error does not exceed the first preset value, the clock value of the smart terminal of the metering box and the clock value of the electricity meter connected to the smart terminal of the metering box are obtained respectively, and the clock deviation value between the clock value of the smart terminal of the metering box and the clock value of the electricity meter is calculated. If the clock deviation value does not exceed the second preset value, obtain the line loss value of the target phase at the metering box inlet; the target phase is any one of the phases at the metering box inlet. If the line loss value of the target phase exceeds a third preset value, the cumulative number of times the hourly electricity data value corresponding to the target phase is obtained, and the cumulative number is updated to obtain the updated cumulative number. If the updated cumulative number is less than the fourth preset value, the process jumps to the step of obtaining the line loss value of the target phase at the metering box inlet when the clock deviation value does not exceed the second preset value, until the updated cumulative number is greater than or equal to the fourth preset value; If the updated cumulative number of times is greater than or equal to the fourth preset value, the line loss value of the target phase and the hourly sequence electricity data of each electricity meter are input into a pre-constructed electricity meter line loss coefficient processing model; if the electricity meter line loss coefficient processing model successfully outputs the electricity meter line loss coefficient processing result, the line loss coefficient of each electricity meter is determined according to the electricity meter line loss coefficient processing result; if there is an abnormal line loss coefficient among the line loss coefficients of each electricity meter, the electricity meter corresponding to the abnormal line loss coefficient is identified as an abnormal line loss electricity meter; electricity meter information corresponding to the abnormal line loss electricity meter is generated as the line loss anomaly identification result of the electricity meter; the electricity meter line loss coefficient processing model is... , where C xM To calculate the line loss value of the target phase at a specified time, Y is the line loss coefficient of a certain energy meter, S is the hourly series of energy data of a certain energy meter, and E is the inherent line loss of the metering box.

2. The method according to claim 1, characterized in that, Before acquiring the clock value of the smart terminal of the metering box and the clock value of the energy meter connected to the smart terminal of the metering box, the process further includes: Identify whether the topology of the metering box has changed; If the topology of the metering box changes, the topology information of the metering box smart terminal is updated, and the hourly power data value of the target phase at the metering box inlet is cleared to zero. The step of acquiring the clock value of the smart terminal of the metering box and the clock value of the energy meter connected to the smart terminal of the metering box includes: Without changing the topology of the metering box, the clock value of the smart terminal of the metering box and the clock value of the energy meter connected to the smart terminal of the metering box are obtained respectively.

3. The method according to claim 1, characterized in that, The step of obtaining the line loss value of the target phase at the metering box inlet includes: The system acquires the first hour's electricity data value of the smart terminal in the metering box under the target phase at the metering box inlet, and the second hour's electricity data value of the energy meter connected to the target phase at the metering box inlet. The first hour's power consumption data value and the second hour's power consumption data value are respectively input into a pre-constructed phase line loss data processing model to obtain the line loss value of the target phase at the metering box inlet.

4. The method according to any one of claims 1 to 3, characterized in that, After obtaining the measurement error for the smart terminal of the metering box, the following is also included: If the measurement error exceeds the first preset value, an error over-tolerance alarm message is generated; The error exceeding the tolerance alarm information is reported to the intelligent terminal of the distribution area.

5. A low-voltage distribution area line loss anomaly identification device, characterized in that, The device includes: An information acquisition module is used to acquire the metering error of the metering box smart terminal in the metering box; the metering box also includes an energy meter connected to the metering box smart terminal; The data calculation module is used to acquire the clock value of the smart terminal of the metering box and the clock value of the energy meter connected to the smart terminal of the metering box respectively, and calculate the clock deviation value between the clock value of the smart terminal of the metering box and the clock value of the energy meter, when the metering error does not exceed the first preset value. The data acquisition module is used to acquire the line loss value of the target phase at the metering box inlet when the clock deviation value does not exceed a second preset value; the target phase is any one of the phases at the metering box inlet. A data update model is used to obtain the cumulative number of hourly electricity data values ​​corresponding to the target phase when the line loss value of the target phase exceeds a third preset value, and update the cumulative number to obtain the updated cumulative number. The loop execution module is used to jump to the step of obtaining the line loss value of the target phase at the metering box inlet when the updated cumulative number is less than the fourth preset value, until the updated cumulative number is greater than or equal to the fourth preset value. The result determination model is used to input the line loss value of the target phase and the hourly sequence electricity data of each electricity meter into a pre-constructed electricity meter line loss coefficient processing model when the updated cumulative number is greater than or equal to the fourth preset value; when the electricity meter line loss coefficient processing model successfully outputs the electricity meter line loss coefficient processing result, the line loss coefficient of each electricity meter is determined according to the electricity meter line loss coefficient processing result; when there is an abnormal line loss coefficient among the line loss coefficients of each electricity meter, the electricity meter corresponding to the abnormal line loss coefficient is identified as an abnormal line loss electricity meter; electricity meter information corresponding to the abnormal line loss electricity meter is generated as the line loss anomaly identification result of the electricity meter; the electricity meter line loss coefficient processing model is... , where C xM To calculate the line loss value of the target phase at a specified time, Y is the line loss coefficient of a certain energy meter, S is the hourly series of energy data of a certain energy meter, and E is the inherent line loss of the metering box.

6. A computer device comprising a memory and a processor, wherein the memory stores 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 to 4.

7. 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 to 4.

8. A computer program product, comprising a computer program, 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 to 4.

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