Method for monitoring an electric power supply line for an electric leakage fault and related products

Abstract

The application discloses a method for monitoring power supply line leakage fault and related products, and the method comprises the following steps: determining a same-phase electric energy meter related to a power supply line; obtaining branch currents of each branch of the power supply line according to sampling data of the same-phase electric energy meter at multiple sampling time points; calculating difference currents between total area total meter currents and total branch currents of the power supply line at the multiple sampling time points to obtain a difference current sequence; judging whether the power supply line has a leakage fault according to stability of the difference current sequence; wherein the same-phase electric energy meter comprises a user electric energy meter with the same phase sequence as the power supply line. The application realizes monitoring and analysis of the power supply line leakage fault in front of the total area meter through the combination of two dimensions of the total area current conservation and the leakage current characteristics.

Description

Technical Field

[0001] This application generally relates to the field of power system technology. More specifically, this application relates to a method and related products for monitoring leakage faults in power supply lines. Background Technology

[0002] With the intelligent transformation of power grids and the improvement of rural electrification, leakage fault monitoring in distribution transformer areas has become a key focus of power safety management. State Grid Corporation of China and other enterprises are vigorously promoting the construction of intelligent distribution transformer areas and driving the widespread application of leakage monitoring equipment and systems to improve power supply reliability, reduce line losses in distribution transformer areas, and ensure the safety of residents' electricity use.

[0003] By comparing the current of the main meter for a specific phase of a power supply line in a distribution area with the sum of the currents of each branch circuit, it is possible to determine whether there is a leakage fault in the upstream line of that phase. However, due to the inevitable deviations in the measurement results of metering equipment and the difficulty in maintaining complete consistency in the sampling times of multiple metering devices, the method of directly comparing the current of the main meter for the distribution area with the sum of the currents of each branch circuit has unreliable issues. In addition, in existing user energy meters, the phase sequence of the data collected by single-phase energy meters defaults to phase A of the main meter for the distribution area; the phases A, B, and C of the data collected by three-phase energy meters default to phases A, B, and C of the main meter for the distribution area, respectively. In reality, the phase sequence of the data collected by user energy meters does not necessarily conform to this default value. This mismatch between the phase sequence of the collected data and the actual physical phase lines makes it impossible to effectively determine which part of the power supply phase line in the power supply area has a fault, and it is also impossible to comprehensively use the data collected by multiple energy meters to monitor leakage faults in the upstream lines of the distribution area.

[0004] In view of this, this application provides a method and related products for monitoring leakage faults in power supply lines, so as to effectively utilize the data collected by smart meters during operation to accurately identify leakage faults in the lines before the meters in the distribution area. Summary of the Invention

[0005] In order to at least solve one or more of the technical problems mentioned above, this application proposes methods and related products for monitoring leakage faults in power supply lines in several aspects.

[0006] In a first aspect, this application provides a method for monitoring leakage faults in power supply lines, comprising: identifying in-phase energy meters associated with the power supply line; obtaining branch currents of each branch of the power supply line based on sampling data from the in-phase energy meters at multiple sampling time points; calculating the difference current between the total current of the transformer substation and the total current of the branches at multiple sampling time points to obtain a difference current sequence; and determining whether a leakage fault exists in the power supply line based on the stability of the difference current sequence; wherein the in-phase energy meters include user energy meters with the same phase sequence as the power supply line.

[0007] In a second aspect, this application provides an electronic device, including: a processor; and a memory having program code stored thereon for monitoring leakage faults in power supply lines, wherein when the program code is executed by the processor, the electronic device performs the method described in the first aspect.

[0008] In a third aspect, this application provides a non-transitory machine-readable storage medium having stored program code thereon for monitoring leakage faults in power supply lines, which, when executed by a processor, causes the method described in the first aspect to be implemented.

[0009] Using the methods and related products for monitoring leakage faults in power supply lines provided above, this application achieves the monitoring and analysis of leakage faults in the line before the meter in a distribution area by combining two dimensions: the conservation of current in the distribution area and the characteristics of leakage current. The method proposed in this application can monitor leakage faults in the line before the meter in a distribution area solely based on the load curve data of existing electricity meters in the Electricity Information Acquisition 2.0 system, without requiring additional hardware equipment. This reduces investment in hardware installation and fills the research gap in monitoring leakage faults in the line before the meter in a distribution area without relying on additional hardware equipment. Attached Figure Description

[0010] The above and other objects, features, and advantages of exemplary embodiments of this application will become readily understood by reading the following detailed description with reference to the accompanying drawings. In the drawings, several embodiments of this application are illustrated by way of example and not limitation, and the same or corresponding reference numerals denote the same or corresponding parts, wherein: Figure 1 An exemplary schematic diagram of a power supply area in some embodiments of this application is shown.

[0011] Figure 2 An exemplary schematic diagram of a power supply area in some embodiments of this application is shown.

[0012] Figure 3 An exemplary schematic diagram is shown in some embodiments of this application, illustrating a leakage fault in the pre-meter line of a power supply area.

[0013] Figure 4 An exemplary schematic diagram of the phase sequence identification results of the user electricity meter in a transformer substation is shown in some embodiments of this application.

[0014] Figure 5 A block diagram is shown illustrating a hardware configuration of an electronic device that can implement some embodiments of this application.

[0015] Figure 6 An exemplary schematic diagram illustrating the implementation effect of the method for monitoring leakage faults in power supply lines in this application is shown. Detailed Implementation

[0016] The technical solutions of the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some, not all, of the embodiments of this application. Based on the embodiments of this application, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this application.

[0017] It should be understood that the terms "comprising" and "including" used in the specification and claims of this application indicate the presence of the described features, integrals, steps, operations, elements and / or components, but do not exclude the presence or addition of one or more other features, integrals, steps, operations, elements, components and / or collections thereof.

[0018] It should also be understood that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to limit the application. As used in this specification and claims, the singular forms “a,” “an,” and “the” are intended to include the plural forms unless the context clearly indicates otherwise. It should also be understood that the term “and / or” as used in this specification and claims refers to any combination and all possible combinations of one or more of the associated listed items, and includes such combinations.

[0019] As used in this specification and claims, the term "if" may be interpreted, depending on the context, as "when," "once," "in response to determination," or "in response to detection." Similarly, the phrase "if determined" or "if [described condition or event] is detected" may be interpreted, depending on the context, as "once determined," "in response to determination," "once [described condition or event] is detected," or "in response to detection of [described condition or event]."

[0020] Furthermore, the terms "first" and "second" are used for descriptive purposes only and should not be construed as indicating or implying relative importance or implicitly specifying the number of technical features indicated. Thus, a feature defined as "first" or "second" may explicitly or implicitly include one or more of that feature. In the description of this application, "multiple" means two or more, unless otherwise expressly specified. "Several" means one or more, unless otherwise expressly specified.

[0021] The specific embodiments of this application will now be described in detail with reference to the accompanying drawings.

[0022] In a power system, a distribution area refers to a complete distribution unit centered around a single distribution transformer, covering its power supply range. It is also the basic unit for power companies to distribute electricity, perform metering statistics, and manage operation and maintenance. Distribution areas use transformers to step down high-voltage electricity from the upper-level power grid to low-voltage electricity, which is then distributed to individual users through pre-meter lines.

[0023] Figure 1 Exemplary schematic diagrams of power supply areas in some embodiments of this application are shown. For example... Figure 1 As shown, this could be a three-phase power supply from a three-phase generator or transformer, used to output stable and efficient three-phase electricity. The three-phase electricity consists of three alternating currents with the same frequency, equal amplitude, and phases differing by 120° sequentially, transmitted via live wires, each corresponding to a different phase. Figure 1 The A-phase live wire, B-phase live wire, and C-phase live wire are also called phase wires; the neutral wire, also called the neutral line, has a potential of zero under ideal conditions and is used to form a power supply circuit with the live wires.

[0024] like Figure 1 The power supply system shown includes a main meter for the entire distribution area and individual electricity meters. The main meter for the entire distribution area measures the electricity consumption, while individual electricity meters (such as...) Figure 1 In this power supply system, single-phase energy meters (A) and three-phase energy meters (B and C) are used to measure the electrical energy consumed by each or some users. A single-phase power supply can be drawn from any one phase line and neutral line to power a single-phase load; a three-phase power supply can be drawn from all three phase lines and neutral line to power a three-phase load. Corresponding to single-phase and three-phase loads, user energy meters can be classified as single-phase energy meters and three-phase energy meters.

[0025] continue Figure 1 In some embodiments, a single-phase power supply circuit consisting of any one phase wire and a neutral wire can be equipped with knife switches S1 and S2 and a single-phase energy meter A. In other embodiments, a three-phase power supply circuit consisting of three phase wires and a neutral wire can be equipped with knife switches S3 and S4 and a three-phase energy meter B. The knife switches are used to control the on / off state of the circuit, and can quickly cut off the power supply during equipment maintenance, troubleshooting, or emergencies, ensuring the safety of personnel and equipment. In some embodiments, a combined junction box can also be installed in both single-phase and three-phase power supply circuits. The combined junction box is used to reliably connect the energy meter, transformer, and power line together, ensuring accurate transmission of power signals and preventing external factors from affecting the metering equipment. In some embodiments, transformers can be installed in the three-phase power supply circuit. Transformers are divided into voltage transformers and current transformers, used to transform high voltage and large current into low voltage and small current to facilitate measurement and protect the safe operation of the equipment.

[0026] Within a power distribution area, electricity can be supplied to a large number of low-voltage users. For example, all residents in a community might share one distribution area, or all offices in an office building might share one distribution area. Each low-voltage user has a specific set of metering equipment to ensure accurate metering of all users' electricity consumption. Therefore, for example... Figure 1 The power supply system shown can be equipped with a specified number of metering devices according to actual needs and the number of low-voltage users.

[0027] A leakage fault before the meter in a distribution transformer area refers to a power fault in which, due to insulation damage, line aging, abnormal grounding, or other reasons, some current leaks into the ground or other non-consumer circuits through damaged areas or grounding electrodes, instead of flowing through the meter normally. Since these pre-meter lines are public power supply facilities exposed outdoors or in public areas, leakage can lead to energized grounding electrodes and discharge at damaged points, posing a risk of electric shock to pedestrians, construction workers, and residents. Currently, leakage faults in pre-meter lines are managed through a reactive, post-incident detection mechanism, resulting in significant economic losses and safety hazards. Therefore, research on leakage monitoring and analysis methods for pre-meter lines in distribution transformer areas is urgently needed to address this safety risk. This research aims to achieve early detection, prevention, and handling of leakage faults in pre-meter lines, thereby significantly reducing economic losses caused by these faults, mitigating safety risks in distribution transformer areas, improving the reliability and security of smart grid operation, and ensuring the safe and stable operation of the smart grid.

[0028] Currently, leakage current monitoring methods for transformer substations include two categories: on-site inspection and remote online monitoring. On-site inspection of leakage faults mainly relies on manual step-by-step power outages, pole climbing and disconnection, and door-to-door searches when a high line loss rate is detected in the substation. Methods such as branch power testing and clamp-on ammeter positioning are also used to detect the cause of the leakage. Only if a leakage fault in the pre-meter line causes a sudden high line loss in the substation will grassroots maintenance personnel pay attention to such substations, conduct on-site verification of the cause of the high loss, and measure whether there is leakage current in the transformer grounding wire. On-site inspection methods for leakage faults are susceptible to interference from factors such as metering failures and abnormal power consumption. If a leakage fault in the pre-meter line does not cause a high line loss index in the substation, it is difficult to detect in a timely manner, leading to prolonged power loss. The main method for remote online monitoring of leakage current in the line before the meter in a transformer substation relies on the installation of hardware equipment, such as installing a current transformer at the grounding flat iron position of the transformer to monitor the leakage current, or installing a measuring switch at the branch line or meter box position to monitor the leakage current. These methods can detect some leakage current faults in the line before the meter in a transformer substation, but they also increase the investment cost of the substation and are not suitable for large-scale promotion and application.

[0029] With the comprehensive upgrade of the Electricity Information Acquisition 2.0 system, it can collect 96-point curve data such as current and power, providing strong data support and technical foundation for intelligent monitoring of leakage faults in transformer substations. However, in terms of using multi-dimensional data features and deep correlation analysis to identify leakage faults in transformer substations, the domestic industry still lacks efficient and accurate analysis methods and technologies, and the potential in this field has not yet been fully released and explored.

[0030] Figure 2 Exemplary schematic diagrams of power supply areas in some embodiments of this application are shown. For example... Figure 2 As shown, in some embodiments, phase A of the transformer substation includes n power supply branches, phase B of the substation includes m power supply branches, and phase C of the substation includes h power supply branches. Let I be the phase A current in the substation's overall meter. A The equivalent resistance values ​​of the electrical loads of the equipment in each power supply branch of phase A are RA1~RA1. n The branch currents are IA1~IA. n Let the current of phase B in the transformer substation's main meter be I. B The equivalent resistance values ​​of the electrical loads of the equipment in each power supply branch of phase B are RB1~RB1. m The branch currents are IB1~IB1. m Let the current of phase C in the transformer substation's main meter be I. C The equivalent resistance of the electrical load of the equipment in the C-phase power supply branch is RC1~RC h The branch current is IC1~IC h Kirchhoff's Current Law states that at any node, the sum of the currents flowing into the node is equal to the sum of the currents flowing out of the node. For Figure 2 The example shown can be used to obtain the current for phase A according to Kirchhoff's current law. Similarly, phase B can be obtained It is possible to obtain the C phase. .

[0031] Figure 3 This illustration shows an exemplary schematic diagram of a leakage fault in the pre-meter line of a power supply area in some embodiments of this application. For example... Figure 3 As shown, in some embodiments, a leakage fault exists in the pre-meter line of phase A in the transformer substation, generating leakage current. At this point, according to Kirchhoff's current law, we can obtain: .

[0032] By comparing the total current of a specific phase of a power supply line in a transformer substation with the sum of the currents of each branch circuit, it is possible to determine whether there is a leakage fault in the upstream line of that phase. However, due to the inevitable deviations in the measurement results of electricity meters and the difficulty in maintaining perfect consistency in the sampling times of multiple electricity meters, the method of directly comparing the total current of the transformer substation with the sum of the currents of each branch circuit suffers from insufficient reliability. The inventors of this application discovered in practice that when the leakage fault contact point is stable, during the fault period... Approximately a constant value, the stability of the difference between the current in the main meter of a power supply line corresponding to a certain phase and the sum of the currents in each branch can be used to determine whether there is a leakage fault in the pre-meter line of that phase power supply line. However, in existing user energy meters, the phase sequence of the data collected by single-phase energy meters defaults to phase A of the main meter of the power supply line; the phases A, B, and C of the data collected by three-phase energy meters default to phases A, B, and C of the main meter of the power supply line, respectively. In reality, the phase sequence of the data collected by user energy meters does not necessarily correspond to this default value with the phase sequence of the main meter of the power supply line. This mismatch between the phase sequence of the collected data and the actual physical phase lines makes it impossible to effectively determine which part of the power supply phase line in the power supply area has a fault, and it is also impossible to comprehensively use the collected data from multiple energy meters to monitor leakage faults in the pre-meter line of the power supply area. In view of this, this application provides a method for monitoring leakage faults in power supply lines, so as to effectively utilize the data collected by smart energy meters during operation to accurately identify leakage faults in the pre-meter line of the power supply area.

[0033] In some embodiments, the method for monitoring leakage faults in power supply lines proposed in this application includes: identifying in-phase energy meters associated with the power supply line; obtaining the branch current of each branch of the power supply line based on the sampling data of the in-phase energy meters at multiple sampling time points; calculating the difference current between the total current of the transformer substation and the total current of the branches at multiple sampling time points to obtain a difference current sequence; and determining whether a leakage fault exists in the power supply line based on the stability of the difference current sequence; wherein, the in-phase energy meters include user energy meters with the same phase sequence as the power supply line.

[0034] In a power supply area, the A-phase, B-phase, and C-phase live wires can each form a power supply line with the neutral wire. The area is equipped with a main meter and multiple user energy meters. These meters periodically collect electrical parameters such as voltage, current, and power. Based on the data collected from the user energy meters and the main meter, the phase sequence of the user energy meters can be determined. This determines whether a single-phase user energy meter is connected to an A-phase, B-phase, or C-phase power supply line, or the correspondence between the three phase wires of a three-phase user energy meter and the A, B, and C phases. After determining the phase sequence of all user energy meters in the power supply area, the corresponding energy meters for each of the A, B, and C phase power supply lines can be identified.

[0035] The power supply lines drawn from the transformer can supply power to multiple users, thus each power supply line can include multiple branches. The main transformer meter records the current flowing from the transformer at each sampling time point, and the user's electricity meter records the current flowing through that meter at each sampling time point. In some embodiments, the main transformer meter and the user's electricity meter sample at the same time point; for example, the main transformer meter and the user's electricity meter can sample once or multiple times per second. In these embodiments, multiple sampling time points within a week or a month can be selected to analyze whether there is a leakage fault in the power supply line before the meter. The branch current can be obtained based on the data recorded by the user's electricity meter on each branch, and the total branch current can be obtained by summing the currents of all branches.

[0036] At each sampling time point, the difference between the total current of the transformer substation and the total current of the branch circuit can be used to obtain the differential current corresponding to that time point. Thus, the differential currents corresponding to multiple sampling time points constitute a differential current sequence. In some embodiments, the transformer substation meter and the user's energy meter are mutual inductance energy meters. The original current data collected are multiplied by the transformation ratio coefficient to obtain the current data of the transformer substation meter and the user's energy meter. The differential current is then calculated based on the current data of the transformer substation meter and the user's energy meter. The causes of differential current include slight differences in the sampling time of the transformer substation meter and the user's energy meter, energy meter measurement errors, and leakage current faults in the upstream lines. To determine whether the differential current is caused by a leakage current fault in the upstream lines, based on the characteristic that the leakage current is approximately a constant value during the fault period when the contact point of the upstream line leakage fault is stable, this application uses the stability of the differential current sequence to determine whether a leakage current fault exists in the power supply line.

[0037] Understandably, this application combines the two dimensions of transformer area current conservation and leakage current characteristics to achieve the monitoring and analysis of leakage faults in the line before the transformer meter. The method proposed in this application can monitor leakage faults in the line before the transformer meter using only the load curve data of the existing electricity meter in the electricity information acquisition 2.0 system, without the need for additional hardware equipment. This reduces the investment in installing hardware equipment and fills the research gap in monitoring leakage faults in the line before the transformer meter without relying on additional hardware equipment.

[0038] In some embodiments, the method for monitoring leakage faults in power supply lines proposed in this application includes: identifying the number of time points in the differential current sequence that exceed a first current difference threshold to obtain a first abnormal time point number; identifying the number of time points in the differential current sequence that exceed a second current difference threshold to obtain a second abnormal time point number; and in response to the ratio of the second abnormal time point number to the first abnormal time point number exceeding a preset ratio threshold, initiating an operation to determine whether there is a leakage fault in the power supply line based on the stability of the differential current sequence; wherein the second current difference threshold is greater than the first current difference threshold.

[0039] In some embodiments, the first current difference threshold can be 1A, the second current difference threshold can be 2A, and the preset ratio threshold can be 90%. Each difference current in the difference current sequence corresponds to a sampling time point. The number of first abnormal time points (N0) and the number of second abnormal time points (N1) can be calculated based on the difference current value at each sampling time point. Both the first and second abnormal time points have a significant difference current, with the difference current at the second abnormal time point being larger than that at the first abnormal time point. In these embodiments, by calculating the ratio of N1 / N0 and comparing it with the preset ratio threshold, the operation of determining whether there is a leakage fault in the power supply line based on the stability of the difference current sequence is initiated only when the ratio of N1 / N0 exceeds the preset ratio threshold. If the ratio of N1 / N0 does not reach the preset ratio threshold, the operation of determining whether there is a leakage fault in the power supply line based on the stability of the difference current sequence is not initiated. This effectively filters out the moments when there is a possible leakage fault, thereby accurately identifying leakage faults in the upstream lines.

[0040] In some embodiments, the method for monitoring leakage faults in power supply lines proposed in this application includes: in response to determining that there is a leakage fault in the power supply line based on the stability of the differential current sequence, verifying the correctness of the determination result based on the leakage current and the power loss of the power supply line.

[0041] Understandably, since the leakage point is located before the user's electricity meter, the leakage current flows through the main meter of the distribution area but not into the user's electricity meter. The current detected by the main meter includes the leakage current of the line before the meter, while the current detected by the user's electricity meter does not. A portion of the electrical energy output by the transformer is not utilized by the user, resulting in power loss. In some embodiments, when a leakage fault is determined in the power supply line based on the stability of the differential current sequence, the correctness of the judgment is further verified by combining the leakage current with the power loss of the power supply line. Here, leakage current refers to the electrical energy lost due to the leakage fault in the line before the meter. When the leakage current and the power loss are approximately equal, it can be considered that a leakage fault does exist in the power supply line, and the judgment based on the stability of the differential current sequence is also correct.

[0042] In some embodiments, verifying the correctness of the judgment result based on the leakage current and the power loss of the power supply line includes: obtaining the leakage current of the first day and the power loss of the power supply line of the first day; determining the difference between the maximum and minimum daily power loss of the power supply line in a month to obtain the daily power loss range; and determining that the judgment result is correct in response to the first day leakage current being less than the first day power loss and the ratio of the first day leakage current to the daily power loss range being within a first preset ratio range.

[0043] In some embodiments, the leakage current generated on the same day (denoted as Day 1) and the daily power loss of the power supply line are obtained to obtain the leakage current and power loss of the first day. In these embodiments, the maximum and minimum daily power loss values ​​in the month containing Day 1 are obtained, and the difference between the maximum and minimum daily power loss values ​​is used to obtain the range of daily power loss. It is understood that the leakage current caused by the leakage fault in the line before the meter should be less than the daily power loss and approximately equal to the range of daily power loss within a month; based on this, when the leakage current of the first day is less than the daily power loss and the ratio of the leakage current of the first day to the range of daily power loss is within a first preset ratio range, the judgment result is determined to be correct. The first preset ratio range can be [90%, 100%] or [85%, 100%].

[0044] In some embodiments, the leakage current at each sampling time is calculated based on the current data recorded by the main meter of the distribution area for the power supply line and the current data recorded by the user's energy meter with the same phase sequence as the power supply line in Day 1, to obtain the daily leakage current data; the leakage amount for the first day is calculated based on the daily current data. For example, based on... To calculate the leakage current at each sampling time in Day 1, where, This represents the leakage current at time t. This represents the total meter current of the transformer substation corresponding to the power supply line at time t. This represents the branch current of the i-th branch at time t; then according to To calculate the leakage power on the first day, where This indicates the leakage power on the first day, and its unit is kWh. This indicates the starting sampling time in Day 1. This indicates the last sampling time in Day 1.

[0045] In some embodiments, verifying the correctness of the judgment result based on the leakage current and the power loss of the power supply line includes: obtaining the leakage current of the first day and the leakage current of the second day, as well as the power loss of the power supply line of the first day and the power loss of the second day; determining the difference between the maximum and minimum daily power loss of the power supply line in a month to obtain the daily power loss range; and determining that the judgment result is correct in response to the following: the leakage current of the first day is less than the power loss of the first day, the leakage current of the second day is less than the power loss of the second day, the ratio of the leakage current of the first day to the daily power loss range is within a first preset ratio range, the ratio of the leakage current of the second day to the daily power loss range is within a first preset ratio range, and the ratio of the leakage current of the first day to the leakage current of the second day is within a second preset ratio range.

[0046] In some embodiments, the leakage current and the daily power loss of the power supply line are obtained on the same day (denoted as Day 1) to obtain the leakage current and power loss of the first day; the leakage current and the daily power loss of the power supply line are obtained on another day (denoted as Day 2) to obtain the leakage current and power loss of the second day. In these embodiments, the maximum and minimum daily power loss values ​​in the month containing Day 1 or Day 2 are obtained, and the difference between the maximum and minimum daily power loss values ​​is used to obtain the daily power loss range.

[0047] In some embodiments, Day 1 and Day 2 are two consecutive days. It is understood that the leakage current caused by a current leakage fault in the pre-meter line should be less than the daily power loss and approximately equal to the range of daily power loss within a month. Furthermore, due to the stability of the leakage current, the leakage current over two consecutive days should be approximately equal. The judgment is considered correct when the leakage current on the first day is less than the power loss on the first day, the leakage current on the second day is less than the power loss on the second day, the ratio of the leakage current on the first day to the range of daily power loss is within a first preset ratio range, the ratio of the leakage current on the second day to the range of daily power loss is within a first preset ratio range, and the ratio of the leakage current on the first day to the leakage current on the second day is within a second preset ratio range. The second preset ratio range can be [90%, 110%]. The leakage current on the first day has already been given above. The same calculation method can be used to calculate the leakage current on the second day. This will not be elaborated upon here.

[0048] In some embodiments, determining the in-phase energy meter associated with a power supply line includes: acquiring voltage time-series data of a user's energy meter to obtain first voltage time-series data; acquiring voltage time-series data of the transformer substation corresponding to the power supply line to obtain second voltage time-series data; acquiring voltage time-series data of the transformer substation corresponding to a first candidate power supply line to obtain third voltage time-series data; acquiring voltage time-series data of the transformer substation corresponding to a second candidate power supply line to obtain fourth voltage time-series data; calculating a correlation coefficient between the first voltage time-series data and the second voltage time-series data to obtain a first correlation coefficient; calculating a correlation coefficient between the first voltage time-series data and the third voltage time-series data to obtain a second correlation coefficient; calculating a correlation coefficient between the first voltage time-series data and the fourth voltage time-series data to obtain a third correlation coefficient; and determining the power supply line in phase sequence with the user's energy meter based on the first correlation coefficient, the second correlation coefficient, and the third correlation coefficient.

[0049] The power supply line can be an A-phase power supply line or a B / C phase power supply line. When the power supply line is an A-phase power supply line, the first candidate power supply line and the second candidate power supply line can be B / C phase power supply lines, respectively. When the power supply line is a B-phase power supply line, the first candidate power supply line and the second candidate power supply line can be A / C phase power supply lines, respectively. When the power supply line is a C-phase power supply line, the first candidate power supply line and the second candidate power supply line can be B / A phase power supply lines, respectively. In these embodiments, voltage timing data from the user's electricity meter is obtained to obtain first voltage timing data; voltage timing data corresponding to the power supply line, the first candidate power supply line, and the second candidate power supply line are obtained from the distribution area meter to obtain second, third, and fourth voltage timing data, respectively, and the obtained voltage timing data correspond to the same sampling time; the correlation coefficient between the user's electricity meter's voltage timing data and the voltage timing data of the distribution area meter for the three-phase power supply line is calculated, and then the phase sequence corresponding to the power supply line with the highest correlation to the user's electricity meter's voltage timing data is taken as the phase sequence of the user's electricity meter. After determining the phase sequence of all users' electricity meters in the distribution area, the electricity meters in the same phase related to the power supply line can be obtained.

[0050] In some embodiments, the first correlation coefficient, the second correlation coefficient, and the third correlation coefficient are Pearson correlation coefficients.

[0051] In these embodiments, according to the formula To calculate the first correlation coefficient, where This represents the first correlation coefficient. x represents the second voltage timing data, and x represents the first voltage timing data. Indicates to Calculate the covariance with b. They represent respectively to Calculate the variance. According to the formula... To calculate the second correlation coefficient, where This represents the second correlation coefficient. This represents the timing data of the third voltage. According to the formula... To calculate the third correlation coefficient, where This represents the third correlation coefficient. This represents the fourth voltage timing data. Further, select... , as well as The phase sequence of the power supply line corresponding to the maximum value in the value is used as the phase sequence of the user's electricity meter.

[0052] Figure 4 An exemplary schematic diagram of the phase sequence identification results of the user's electricity meter in a transformer substation is shown in some embodiments of this application. For example... Figure 4 As shown, among a total of 52 user energy meters, 18 user energy meters (corresponding to orange) are identified as phase A, 15 user energy meters (corresponding to green) are identified as phase B, and 19 user energy meters (corresponding to red) are identified as phase C. Based on the above user energy meter phase sequence identification method, energy meters with the same phase related to the power supply line can be effectively screened out, thereby improving the accuracy of leakage fault detection results in the upstream line.

[0053] In some embodiments, determining whether a power supply line has a leakage fault based on the stability of the differential current sequence includes: calculating the standard deviation of the differential current sequence; determining that the power supply line has a leakage fault in response to the standard deviation being less than a standard deviation threshold; and determining that the power supply line has no leakage fault in response to the standard deviation being greater than the standard deviation threshold.

[0054] In these embodiments, by To calculate the differential current of the power supply line at multiple sampling time points, in order to obtain the differential current sequence. Then according to To calculate the standard deviation of the difference current series, where n represents the number of time points in the difference current series. This represents the average value in the differential current sequence. This represents the standard deviation of the differential current sequence. In some embodiments, the standard deviation threshold can be 0.3 or 0.2. When the calculated standard deviation of the differential current sequence is less than the standard deviation threshold, it can be considered that there is a leakage fault in the power supply line.

[0055] Corresponding to the aforementioned application function implementation method embodiments, this application also provides an electronic device and corresponding embodiments.

[0056] Figure 5 A block diagram illustrating a hardware configuration that can implement some embodiments of the electronic device 500 of this application is shown. Figure 5 As shown, the electronic device 500 may include a processor 510 and a memory 520. Figure 5 In the electronic device 500, only the components relevant to this embodiment are shown. Therefore, it will be apparent to those skilled in the art that the electronic device 500 may also include components related to... Figure 5 The following are common components with different constituent elements. For example, a fixed-point arithmetic unit.

[0057] Electronic device 500 can correspond to a computing device with various processing functions, such as functions for generating neural networks, training or learning neural networks, quantizing floating-point neural networks into fixed-point neural networks, or retraining neural networks. For example, electronic device 500 can be implemented as various types of devices, such as personal computers (PCs), server devices, mobile devices, etc.

[0058] The processor 510 controls all functions of the electronic device 500. For example, the processor 510 controls all functions of the electronic device 500 by executing programs stored in the memory 520 on the electronic device 500. The processor 510 can be implemented by a central processing unit (CPU), graphics processing unit (GPU), application processor (AP), artificial intelligence processor chip (IPU), etc., provided in the electronic device 500. However, this application is not limited to this.

[0059] In some embodiments, the processor 510 may include an input / output (I / O) unit 511 and a computing unit 512. The I / O unit 511 may be used to receive various types of data, such as electricity meter readings. Exemplarily, the computing unit 512 may be used to process the electricity meter readings received via the I / O unit 511, and the processing result may be output by the I / O unit 511. The output data may be provided to a memory 520 for use by other devices (not shown), or it may be directly provided to other devices.

[0060] Memory 520 is hardware used to store various data processed in electronic device 500. For example, memory 520 can store processed data and data to be processed in electronic device 500. Furthermore, memory 520 can store applications, drivers, etc., to be driven by electronic device 500. For example, memory 520 can store various programs related to a method for monitoring power line leakage faults, which will be executed by processor 510. Memory 520 can be DRAM, but this application is not limited to it. Memory 520 can include at least one of volatile memory or non-volatile memory. Non-volatile memory can include read-only memory (ROM), programmable ROM (PROM), electrically programmable ROM (EPROM), electrically erasable programmable ROM (EEPROM), flash memory, phase-change RAM (PRAM), magnetic RAM (MRAM), resistive RAM (RRAM), ferroelectric RAM (FRAM), etc. Volatile memory can include dynamic RAM (DRAM), static RAM (SRAM), synchronous DRAM (SDRAM), PRAM, MRAM, RRAM, ferroelectric RAM (FeRAM), etc. In an embodiment, the memory 520 may include at least one of a hard disk drive (HDD), a solid-state drive (SSD), a high-density flash memory (CF), a secure digital card (SD), a micro-secure digital card (Micro-SD), a mini-secure digital card (Mini-SD), an extreme digital card (xD), caches, or a memory stick.

[0061] In summary, the specific functions implemented by the memory 520 and processor 510 of the electronic device 500 provided in this specification can be explained in comparison with the aforementioned embodiments in this specification, and can achieve the technical effects of the aforementioned embodiments. Therefore, they will not be repeated here.

[0062] In this embodiment, the processor 510 can be implemented in any suitable manner. For example, the processor 510 can take the form of a microprocessor or processor and a computer-readable medium storing computer-readable program code (e.g., software or firmware) that can be executed by the (micro)processor, logic gates, switches, application-specific integrated circuits (ASICs), programmable logic controllers, and embedded microcontrollers, etc.

[0063] It should also be understood that any module, unit, component, server, computer, terminal, or device that executes the instructions executorized herein may include or otherwise access computer-readable media, such as storage media, computer storage media, or data storage devices (removable) and / or non-removable) such as disks, optical discs, or magnetic tapes. Computer storage media may include volatile and non-volatile, removable and non-removable media implemented in any method or technology for storing information, such as computer-readable instructions, data structures, program modules, or other data.

[0064] The method for monitoring leakage faults in power supply lines proposed in this application can identify power supply lines with leakage faults before the meter. After on-site verification, the accuracy rate of the proposed method can reach more than 80%. Compared with installing hardware equipment in the distribution area to monitor leakage faults, it has the outstanding advantages of low investment and quick results. It helps the grassroots employees of the power company solve the actual pain points in the low-voltage distribution area through information technology.

[0065] Figure 6 An exemplary schematic diagram illustrating the implementation effect of the method for monitoring leakage faults in power supply lines according to this application is shown. Figure 6 As shown, the XX distribution area has a capacity of 315kVA, a transformer comprehensive ratio of 100, and a marketing system covering 294 households. Daily power supply is approximately 1845kWh, and daily power sales are approximately 1653kWh, resulting in a daily power loss of approximately 191kWh. The daily high-loss rate for this area is approximately 10.37%. The area has 100% coverage and a 100% data collection success rate. After diagnosis using leakage current monitoring and analysis methods, it was initially determined that there was an abnormal leakage current in the high-loss area, requiring further on-site location of the actual leakage point. By checking the leakage current of the transformer grounding wire and gradually measuring the leakage in each branch line, the actual location and specific cause of the leakage anomaly were finally found. After insulation treatment of the leakage point, the high-loss anomaly in the area returned to normal.

[0066] While numerous embodiments of this application have been shown and described herein, it will be apparent to those skilled in the art that such embodiments are provided by way of example only. Many modifications, alterations, and alternatives will arise for those skilled in the art without departing from the spirit and intent of this application. It should be understood that various alternatives to the embodiments of this application described herein may be employed in the practice of this application. The appended claims are intended to define the scope of protection of this application and therefore cover equivalents or alternatives within the scope of these claims.

Claims

1. A method for monitoring a leakage fault of a power supply line, characterized in that, include: Identify the in-phase energy meters associated with the power supply line; For multiple sampling time points, the branch current of each branch of the power supply line is obtained based on the sampling data of the same-phase energy meter; For multiple sampling time points, calculate the difference current between the total meter current of the transformer area and the total current of the branch of the power supply line to obtain the difference current sequence. The stability of the differential current sequence is used to determine whether there is a leakage fault in the power supply line; The in-phase energy meter includes a user energy meter that is in the same phase sequence as the power supply line; The number of time points in the differential current sequence that exceed the first current difference threshold is identified to obtain the number of first abnormal time points; The number of time points in the differential current sequence that exceed the second current difference threshold is identified to obtain the number of second abnormal time points; In response to the ratio of the number of the second abnormal time points to the number of the first abnormal time points exceeding a preset ratio threshold, an operation is initiated to determine whether there is a leakage fault in the power supply line based on the stability of the differential current sequence. Wherein, the second current difference threshold is greater than the first current difference threshold; In response to determining that there is a leakage fault in the power supply line based on the stability of the differential current sequence, the correctness of the determination result is verified based on the leakage current and the power loss of the power supply line. The accuracy of the judgment result is verified based on the leakage current and the power loss of the power supply line, including: The leakage current generated on the first day and the power loss of the power supply line on the first day are obtained. The difference between the maximum and minimum daily power loss of the power supply line in a month is determined to obtain the daily power loss range. If the leakage power on the first day is less than the loss power on the first day and the ratio of the difference between the leakage power on the first day and the loss power on the first day is within a first preset ratio range, the judgment result is determined to be correct.

2. The method of claim 1, wherein, The accuracy of the judgment result is verified based on the leakage current and the power loss of the power supply line, including: The leakage current on the first day and the leakage current on the second day, as well as the power loss on the first day and the power loss on the second day of the power supply line, are obtained. The difference between the maximum and minimum daily power loss of the power supply line in a month is determined to obtain the daily power loss range. In response to the following conditions: the leakage power on the first day is less than the power loss on the first day; the leakage power on the second day is less than the power loss on the second day; the ratio of the leakage power on the first day to the range of the power loss on the second day is within a first preset ratio range; the ratio of the leakage power on the second day to the range of the power loss on the second day is within a first preset ratio range; and the ratio of the leakage power on the first day to the leakage power on the second day is within a second preset ratio range, the judgment result is determined to be correct.

3. The method according to claim 1, characterized in that, Determining the in-phase energy meters associated with the power supply line includes: Obtain the voltage timing data of the user's electricity meter to obtain the first voltage timing data; Obtain the voltage timing data of the transformer substation corresponding to the power supply line to obtain the second voltage timing data; Obtain the voltage timing data of the transformer substation corresponding to the first candidate power supply line to obtain the third voltage timing data; Obtain the voltage timing data of the transformer substation corresponding to the second candidate power supply line to obtain the fourth voltage timing data; Calculate the correlation coefficient between the first voltage time series data and the second voltage time series data to obtain the first correlation coefficient; Calculate the correlation coefficient between the first voltage time series data and the third voltage time series data to obtain the second correlation coefficient; Calculate the correlation coefficient between the first voltage time series data and the fourth voltage time series data to obtain the third correlation coefficient; The power supply line with the same phase sequence as the user's electricity meter is determined based on the first correlation coefficient, the second correlation coefficient, and the third correlation coefficient.

4. The method according to claim 3, characterized in that, include: The first correlation coefficient, the second correlation coefficient, and the third correlation coefficient are Pearson correlation coefficients.

5. The method according to claim 1, characterized in that, Determining whether there is a leakage fault in the power supply line based on the stability of the differential current sequence includes: Calculate the standard deviation of the difference current sequence; In response to the standard deviation being less than the standard deviation threshold, it is determined that there is a leakage fault in the power supply line; In response to the standard deviation being greater than the standard deviation threshold, it is determined that there is no leakage fault in the power supply line.

6. An electronic device, characterized in that, include: processor; as well as A memory storing program code for monitoring leakage faults in power supply lines, wherein when the program code is executed by the processor, the electronic device implements the method as described in any one of claims 1-5.

7. A non-transitory machine-readable storage medium, characterized in that, It stores program code for monitoring leakage faults in power supply lines, which, when executed by a processor, enables the implementation of the method as described in any one of claims 1-5.

Images