A total metering detection method, device, equipment and storage medium

Abstract

The application discloses a kind of total metering detection method, device, equipment and storage medium, the method includes: the running data of specified area is collected, transformer in area is equipped with total meter, running data includes current value, line loss rate;In at least one dimension of area, transformer and total meter, running data is cleaned and handled, eliminates interference, improves the quality of running data, to improve the reliability of detecting fault;If complete cleaning and handling, then according to the current value in the first time period, total meter is divided into fault category;According to the line loss rate in the second time period, total meter generates fault mark in the first time period, fault mark indicates whether total meter fails, and the second time period is divided into multiple first time periods;The metering state of total meter in the first time period is determined in combination with fault category and fault mark.This embodiment associates and calculates the change of current value, the situation of area line loss rate, judges the fault condition of area total meter current loop, can effectively improve the accuracy of detecting fault, strong usability, simple and convenient to calculate, easy to understand and master, less computing resources are occupied, more easily integrated into power system.

Description

TECHNICAL FIELD

[0001] The present application relates to the technical field of power grids, and in particular to a total metering detection method, device, equipment and storage medium. BACKGROUND

[0002] The current remote monitoring method for metering total metering of the distribution transformer installed in the public transformer area mainly has two kinds, one is to rely on the alarm function of the metering total metering, and the other is to rely on data diagnosis technology. These two ways are mainly preset setting rules to judge whether the voltage and current meet the rules, so as to diagnose and distinguish faults.

[0003] However, these rules are relatively fixed, while the situation of the transformer area is real-time change, so there is a certain deviation between the rules and the actual situation, resulting in low accuracy of fault discrimination. SUMMARY

[0004] The present application provides a total metering detection method, device, equipment and storage medium to solve the problem of how to improve the accuracy of fault discrimination of the metering total metering of the public transformer area transformer.

[0005] According to one aspect of the present application, a total metering detection method is provided, comprising:

[0006] Collecting operation data of a specified transformer area, wherein the transformer in the transformer area is configured with a total metering, and the operation data includes current value and line loss rate;

[0007] Cleaning the operation data under at least one dimension of the transformer area, the transformer and the total metering;

[0008] If the cleaning is completed, the total metering is divided into a fault category according to the current value in a first time period;

[0009] Generating a fault identification of the total metering in the first time period according to the line loss rate in a second time period, wherein the fault identification indicates whether the total metering has a fault, and the second time period is divided into a plurality of first time periods;

[0010] Combining the fault category and the fault identification to determine the metering state of the total metering in the first time period.

[0011] Optionally, the cleaning of the operation data under at least one dimension of the transformer area, the transformer and the total metering comprises:

[0012] Querying the reason for the abnormal line loss rate of the transformer in the second time period;

[0013] if the reason is that the transformer is light load, then the operation data related to the light load is eliminated;

[0014] inquire the power supply state of the transformer;

[0015] if the power supply state includes ring network power supply switching, then the operation data related to the ring network power supply switching is eliminated;

[0016] inquire the use state of the total meter in the second time period;

[0017] if the use state is replacement, then the operation data related to the replacement of the total meter is eliminated;

[0018] inquire the data state of the total meter in the second time period;

[0019] if the data state includes that at least one of the voltage value and the current value is 0, then the operation data when at least one of the voltage value and the current value is 0 is eliminated.

[0020] Optionally, the dividing the total meter into a fault category according to the current value in the first time period comprises:

[0021] count the total number of sampling points for collecting the current value in the first time period;

[0022] identify the current value that is abnormal under a certain phase;

[0023] in the first time period, count a first number of the current value that is abnormal;

[0024] in the same first time period, count a first proportion of the first number in the total number;

[0025] if the first proportion is greater than or equal to a preset first proportion threshold, then determine that the fault category of the total meter is current loop virtual connection;

[0026] in the first time period, count a second number of the current value of at least one phase that has been collected;

[0027] in the same first time period, count a second proportion of the second number in the total number;

[0028] if the second proportion is less than or equal to a preset second proportion threshold, then determine that the fault category of the total meter is current loop short circuit.

[0029] Optionally, the identifying the current value that is abnormal under a certain phase comprises:

[0030] if the current value of any phase is empty, then determine that the current value is abnormal;

[0031] for each phase, calculating an average value of the current value in a second time period;

[0032] if the absolute value of the average value takes a specified proportion as an abnormal threshold value;

[0033] if the absolute value of the current value of any phase is less than or equal to the abnormal threshold value corresponding to the phase, determining that the current value is abnormal.

[0034] Optionally, the generating of the fault mark of the total table in the first time period according to the line loss rate in the second time period comprises:

[0035] inquiring a change state of the line loss rate of the transformer in each first time period in a second time period;

[0036] if the change state is that the line loss rate of the transformer in each first time period tends to be stable in the second time period and belongs to positive line loss, searching for the line loss rate of the transformer in the first time period which is abrupt relative to the change state;

[0037] if the line loss rate is found, generating a fault mark indicating that a fault occurs for the total table in the first time period.

[0038] Optionally, the searching for the line loss rate of the transformer in the first time period which is abrupt relative to the change state comprises:

[0039] comparing the line loss rate of the transformer in each first time period with a preset line loss threshold value, the line loss threshold value being a negative number;

[0040] inquiring an attribute of the line loss rate of the transformer in each first time period;

[0041] if the line loss rate of the transformer in a certain first time period is less than the line loss threshold value and the attribute is negative line loss, determining that the line loss rate of the transformer in the first time period is abrupt relative to the change state.

[0042] Optionally, the determining of the metering state of the total table in the first time period in combination with the fault category and the fault mark comprises:

[0043] if the fault category is current loop virtual connection and the fault mark indicates that the total table has a fault, inquiring a first time period in which the current loop virtual connection is located as a first time range and inquiring a first time period in which the fault mark is located as a second time range, respectively;

[0044] If the first time range is the same as the second time range, it is determined that the metering state of the total meter is a short-time current loop short circuit.

[0045] If the fault category is a current loop short circuit and the fault identifier indicates that the total meter is faulty, the first time period in which the current loop short circuit occurs is queried as a third time range, and the first time period in which the fault identifier occurs is queried as a fourth time range.

[0046] If the third time range is the same as the fourth time range, it is determined that the metering state of the total meter is a short-time current loop short circuit.

[0047] According to another aspect of the present application, a total meter metering detection device is provided, comprising:

[0048] An operation data collection module is configured to collect operation data of a designated transformer area, wherein a transformer in the transformer area is configured with a total meter, and the operation data includes a current value and a line loss rate.

[0049] A data cleaning module is configured to clean the operation data in at least one dimension of the transformer area, the transformer, and the total meter.

[0050] A fault category division module is configured to divide a fault category of the total meter according to the current value in a first time period if the cleaning is completed.

[0051] A fault identifier generation module is configured to generate a fault identifier of the total meter in the first time period according to the line loss rate in a second time period, wherein the fault identifier indicates whether the total meter is faulty, and the second time period is divided into a plurality of first time periods.

[0052] A metering state determination module is configured to determine a metering state of the total meter in the first time period in combination with the fault category and the fault identifier.

[0053] Optionally, the data cleaning module comprises:

[0054] A light load elimination module is configured to query a reason for abnormality of the line loss rate of the transformer in the second time period, and eliminate the operation data related to light load of the transformer if the reason is light load of the transformer.

[0055] A transferred power elimination module is configured to query a power supply state of the transformer, and eliminate the operation data related to ring network transferred power if the power supply state includes ring network transferred power off.

[0056] a replacement elimination module configured to query a use state of the total meter in the second time period, and eliminate the operation data related to replacement of the total meter if the use state is replacement;

[0057] a null value elimination module configured to query a data state of the total meter in the second time period, and eliminate the operation data in which at least one of the voltage value and the current value is 0 if the data state includes at least one of the voltage value and the current value being 0.

[0058] Optionally, the fault category division module includes:

[0059] a total quantity counting module configured to count a total quantity of sampling points for collecting the current value in a first time period;

[0060] an abnormal current value identification module configured to identify the current value that is abnormal at a certain phase;

[0061] a first quantity counting module configured to count a first quantity of the current value that is abnormal in the first time period;

[0062] a first proportion counting module configured to count a first proportion of the first quantity in the total quantity in the same first time period;

[0063] a current loop virtual connection determination module configured to determine that a fault category of the total meter is current loop virtual connection if the first proportion is greater than or equal to a preset first proportion threshold;

[0064] a second quantity counting module configured to count a second quantity of the current value of at least one phase that has been collected in the first time period;

[0065] a second proportion counting module configured to count a second proportion of the second quantity in the total quantity in the same first time period;

[0066] a current loop short circuit determination module configured to determine that a fault category of the total meter is current loop short circuit if the second proportion is less than or equal to a preset second proportion threshold.

[0067] Optionally, the abnormal current value identification module includes:

[0068] a null value abnormality determination module configured to determine that the current value is abnormal if the current value of any phase is null;

[0069] a current average value calculation module configured to calculate an average value of the current value in a second time period for each phase of the current value;

[0070] an abnormal threshold generating module configured to generate an abnormal threshold according to an absolute value of the average value;

[0071] a threshold abnormality determining module configured to determine that the current value is abnormal if an absolute value of any phase of the current value is less than or equal to the abnormal threshold corresponding to the phase.

[0072] Optionally, the fault identification generating module comprises:

[0073] a change state inquiring module configured to inquire a change state of the line loss rate of the transformer in each of the first time periods in a second time period;

[0074] a mutation finding module configured to find, if the change state is that the line loss rate of the transformer in each of the first time periods tends to be stable and belongs to positive line loss in the second time period, the line loss rate of the transformer in the first time period that is mutated relative to the change state;

[0075] a fault identification configuring module configured to generate, if the mutation is found, a fault identification indicating that the total meter is faulty in the first time period.

[0076] Optionally, the mutation finding module comprises:

[0077] a threshold comparing module configured to compare the line loss rate of the transformer in each of the first time periods with a preset line loss threshold, the line loss threshold being a negative number;

[0078] an attribute inquiring module configured to inquire an attribute of the line loss rate of the transformer in each of the first time periods;

[0079] a mutation determining module configured to determine that the line loss rate of the transformer in the first time period is mutated relative to the change state if the line loss rate of the transformer in the first time period is less than the line loss threshold and the attribute is negative line loss.

[0080] Optionally, the metering state determining module comprises:

[0081] a first range determining module configured to, if the fault category is current loop virtual connection and the fault identification indicates that the total meter is faulty, inquire the first time period in which the current loop virtual connection is located as a first time range and inquire the first time period in which the fault identification is located as a second time range, respectively;

[0082] a current loop virtual connection marking module configured to determine that a metering state of the total meter is short-time current loop virtual connection if the first time range is the same as the second time range.

[0083] a second range determining module, configured to, if the fault category is a current loop short circuit and the fault identifier indicates that the total meter is faulty, query the first time period in which the current loop short circuit occurs as a third time range, and query the first time period in which the fault identifier occurs as a fourth time range;

[0084] a current loop short circuit marking module, configured to, if the third time range is the same as the fourth time range, determine that the metering state of the total meter is a short-time current loop short circuit.

[0085] According to another aspect of the present application, an electronic device is provided, which comprises:

[0086] at least one processor; and

[0087] a memory connected to the at least one processor in communication; wherein,

[0088] the memory stores a computer program executable by the at least one processor, and the computer program is executed by the at least one processor to enable the at least one processor to perform the total meter metering detection method according to any one of the embodiments of the present application.

[0089] According to another aspect of the present application, a computer readable storage medium is provided, which stores a computer program for enabling a processor to implement the total meter metering detection method according to any one of the embodiments of the present application when executed.

[0090] In the embodiment, running data is collected for a designated transformer area, a transformer in the transformer area is configured with a total meter, and the running data includes current values and line loss rates. The running data is cleaned in at least one dimension of the transformer area, the transformer and the total meter to eliminate interference and improve the quality of the running data, thereby improving the reliability of fault detection. If the cleaning is completed, the total meter is classified according to the current values in a first time period. A fault identifier is generated for the total meter in the first time period according to the line loss rates in a second time period, the fault identifier indicating whether the total meter is faulty, and the second time period is divided into a plurality of first time periods. The metering state of the total meter in the first time period is determined in combination with the fault category and the fault identifier. In the embodiment, the change of the current values and the line loss rates of the transformer area are associated and calculated to determine the fault of the current loop of the total meter of the transformer area, which can effectively improve the accuracy of fault detection, has strong usability, is simple to calculate, easy to understand and master, occupies less computing resources, and is easier to integrate into a power system.

[0091] It is to be understood that the embodiments described herein are merely exemplary of the application and that a person skilled in the art can devise other embodiments without departing from the scope of the present application. It is also to be understood that not all of the benefits described herein need necessarily be realized in any particular embodiment of the application. BRIEF DESCRIPTION OF DRAWINGS

[0092] In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings needed in the embodiments description will be briefly introduced as follows. Obviously, the drawings in the following description are only some embodiments of the present application, and other drawings can be obtained by those skilled in the art without any creative effort based on these drawings.

[0093] Figure 1 is a flow chart of a total metering detection method according to an embodiment of the present application;

[0094] Figure 2 is a structural schematic diagram of a total metering detection device according to an embodiment of the present application;

[0095] Figure 3 is a structural schematic diagram of an electronic device according to an embodiment of the present application. DETAILED DESCRIPTION

[0096] In order to make the technical personnel in the art better understand the present application, the technical solutions in the embodiments of the present application will be described clearly and completely in the following with reference to the drawings in the embodiments of the present application. Obviously, the described embodiments are only some embodiments of the present application, but not all. Based on the embodiments in the present application, all other embodiments obtained by those skilled in the art without any creative effort should belong to the scope of protection of the present application.

[0097] It should be noted that the terms "first", "second", and the like in the specification and claims of the present application and the above-described drawings are used to distinguish similar objects, and do not necessarily indicate a specific order or a chronological sequence. It should be understood that the data thus used can be interchanged under appropriate circumstances, so that the embodiments of the present application described herein can be implemented in an order other than that illustrated or described herein. In addition, the terms "include" and "have" and any variations thereof are intended to cover non-exclusive inclusion, for example, a process, method, system, product or device including a series of steps or units does not necessarily have to be limited to those steps or units clearly listed, but can include other steps or units not clearly listed or inherent to these processes, methods, products or devices.

[0098] Embodiment one

[0099] Figure 1A flowchart of a total metering detection method provided for the first embodiment of the present application, the present embodiment can be applicable to the case of considering the line loss rate to distinguish the fault of the total metering of the transformer of the public transformer area, and the method can be executed by a total metering detection device, which can be realized in the form of hardware and / or software, and can be configured in an electronic device. Figure 1 As shown in the figure, the method comprises:

[0100] Step 101, collecting operation data of the specified area.

[0101] The area is deployed in the power system, which can be used to reduce the high-voltage power of the transformer substation to the low-voltage power used by local and centralized industrial and commercial users, so that these users can fully utilize the power, which can complete the conversion between high and low voltage between the power outgoing line and the connector rack box, and complete the distribution and comprehensive management of the power supply line.

[0102] The transformer is deployed in the area, which is used to convert high-voltage power into low-voltage power or vice versa. The main structure includes the voltage regulating transformer at the power generation end, the voltage and frequency transformer. It is used to provide enough energy for large users, and also manages the distribution network well.

[0103] The transformer in the area is configured with a total metering table (total metering table for short), which is used to accurately calculate the energy consumption of the transformer. The fault of the metering terminal table, the transformer and the secondary circuit directly leads to the loss of energy consumption calculation of the transformer, and also leads to the inaccuracy of the line loss rate calculation of the public transformer area. The correct and reasonable line loss rate of the public transformer area can assist the power supply enterprise to make intelligent decisions when planning line loss and formulating loss reduction measures.

[0104] In the present embodiment, for the specified area, the data generated during the operation of the area in the recent period of time can be collected, which is recorded as operation data.

[0105] In order to facilitate the statistics of operation data, the present embodiment divides a plurality of second time periods (such as months), and divides a plurality of first time periods (such as days) in each second time period (such as month).

[0106] Exemplarily, the operation data includes current value, voltage value, line loss rate, current collection time point, current average value, line loss examination value, power supply, power supply, current fluctuation time, line loss rate fluctuation time, etc.

[0107] Step 102, cleaning the operation data under at least one dimension of the area, the transformer and the total metering table.

[0108] In the embodiment, the operation data is preprocessed in at least one dimension of the transformer, the transformer and the total meter, that is, the operation data is cleaned to eliminate some abnormal operation data in at least one dimension of the transformer, the transformer and the total meter, such as noise, irrelevant data and null, to improve the availability of the operation data, improve the quality of the operation data, and thus improve the accuracy of judging the total meter fault.

[0109] In one case, the reason for the abnormal line loss rate of the transformer in the second time period is queried.

[0110] If the reason is that the transformer is lightly loaded, the small current value will affect the judgment of the total meter fault, the operation data related to the light load is eliminated, wherein the load capacity of the transformer includes no load, light load, full load, overload and the like, the no load means no load, the light load means that the current load power is less than 30% of the full load power, the heavy load means that the current load power is more than 80% of the full load power, and the full load means that the current load power is 100% of the full load power.

[0111] In another case, the power supply state of the transformer is queried.

[0112] If the power supply state includes load cutting and ring network power supply, since the ring network power supply causes fluctuation of the line loss rate, the operation data related to the load cutting and the ring network power supply can be eliminated.

[0113] In yet another case, the use state of the total meter in the second time period is queried.

[0114] If the use state is replacement, the replacement of the total meter will cause the communication signal in the field to be affected, and the collected operation data may be missing, and thus the operation data related to the replacement of the total meter can be eliminated.

[0115] In yet another case, the data state of the total meter in the second time period is queried.

[0116] If the data state includes that at least one of the voltage value and the current value is 0, the operation data when at least one of the voltage value and the current value is 0 is eliminated.

[0117] Of course, the above cleaning process is only an example, and other cleaning processes can be set according to actual conditions when the embodiment of the present application is implemented, and the embodiment of the present application is not limited thereto. In addition, in addition to the above cleaning process, other cleaning processes can be used according to actual needs by those skilled in the art, and the embodiment of the present application is not limited thereto.

[0118] In step 103, if the cleaning process is completed, the total meter is divided into a fault category according to the current value in the first time period.

[0119] For the operation data after the cleaning treatment, the current value in the first time period can be analyzed, the current value in the first time period reflects the real-time operation state of the transformer in the current relatively short time, and the total meter is divided into a fault category according to the real-time operation state, and the possible fault of the total meter is identified.

[0120] In an embodiment of the present application, step 103 can include the following steps:

[0121] Step 1031, count the total number of sampling points for collecting current values in the first time period.

[0122] In this embodiment, the current values collected in the first time period can be arranged in time sequence to obtain a current sequence I n , n = 1, 2,..., N, each data in the current sequence can be recorded as a sampling point, and in the case that the transformer total meter communication signal is normal and the collected current value is normal, the total number of sampling points can be counted, and taking a day as an example of the first time period, the current value is collected every 15 minutes, then the total number of sampling points N = 96.

[0123] Step 1032, identify the current value that is abnormal under a certain phase.

[0124] Generally, the transformer total meter collects A, B, and C three-phase current values, and traverses the current values of each phase to identify the current value that is abnormal under a certain phase.

[0125] In a specific implementation, if any phase current value is null (i.e. I n = null), it can be determined that the current value is abnormal.

[0126] For each phase current value, the average value I 均 of the current value in the second time period is calculated.

[0127] The absolute value of the average value is taken as a specified proportion λ (0 < λ < 100%, such as 50%) as an abnormal threshold.

[0128] If the absolute value of any phase current value is less than or equal to the abnormal threshold corresponding to the phase (i.e. |I n | ≤ |I 均

[0129] |·λ), it can be determined that the current value is abnormal.

[0130] Of course, the above-mentioned manner of identifying abnormal current values is only an example, and other manners of identifying abnormal current values can be set according to actual conditions in the implementation of the embodiments of the present application, and the embodiments of the present application do not limit this. In addition, in addition to the above-mentioned manner of identifying abnormal current values, other manners of identifying abnormal current values can be used according to actual needs by those skilled in the art, and the embodiments of the present application do not limit this.

[0131] Step 1033, in the first time period, a first number of abnormal current values is counted.

[0132] Step 1034, in the same first time period, a first proportion of the first number in the total number is counted.

[0133] Step 1035, if the first proportion is greater than or equal to a preset first proportion threshold, it is determined that the fault category of the total meter is a virtual connection of the current loop.

[0134] In the present embodiment, in each first time period, a first number of abnormal current values can be counted. In the same first time period, a first proportion of the first number in the total number is counted, and the first proportion is compared with a preset first proportion threshold (such as 24 / 96).

[0135] If the first proportion is greater than or equal to the first proportion threshold, it indicates that there are more abnormal current values in the first time period, and the current is not stable, so it can be determined that the fault category of the total meter is likely to be a virtual connection of the current loop.

[0136] Step 1036, in the first time period, a second number of collected at least one phase current values is counted.

[0137] Step 1037, in the same first time period, a second proportion of the second number in the total number is counted.

[0138] Step 1038, if the second proportion is less than or equal to a preset second proportion threshold, it is determined that the fault category of the total meter is a short circuit of the current loop.

[0139] In the present embodiment, the A, B, and C three-phase current values of the total meter of the transformer of the transformer area are collected, and in each first time period, a second number of collected at least one phase (i.e. any one phase or any two phases or three phases) current values is counted. In the same first time period, a first two proportions of the second number in the total number are counted, and the second proportion is compared with a preset second proportion threshold (such as 80 / 96).

[0140] If the second proportion is less than or equal to the second proportion threshold, it indicates that the collected current values are less, so it can be determined that the fault category of the total meter is likely to be a short circuit of the current loop.

[0141] Step 104, generating fault identification of the total meter in the first time period according to the line loss rate in the second time period.

[0142] In the embodiment, the line loss rate in the second time period can represent the real-time running state of the transformer in the current relatively long period, and the real-time running state can be taken as a reference to generate the fault identification of the total meter in the first time period. The fault identification indicates whether the total meter has a fault, and identifies possible faults of the total meter.

[0143] In an embodiment of the present application, step 104 can include the following steps:

[0144] Step 1041, querying the change state of the line loss rate of the transformer in each first time period represented in the second time period.

[0145] In the embodiment, for a given second time period, the line loss rate of the transformer in each first time period in the second time period is traversed to analyze the change trend.

[0146] For example, for the line loss rate of the first time period, the proportion of the line loss rate in the second time period within the preset line loss range and with a positive attribute (i.e. positive line loss) can be counted. If the proportion is greater than a preset trend threshold, it can be determined that the change state of the line loss rate of the transformer in each first time period represented in the second time period is that the line loss rate of the transformer in each first time period tends to be stable and belongs to positive line loss in the second time period.

[0147] Step 1042, if the change state is that the line loss rate of the transformer in each first time period tends to be stable and belongs to positive line loss in the second time period, then the line loss rate of the transformer in the first time period that is relatively changed with respect to the change state is found.

[0148] If the change state of the line loss rate of the transformer in each first time period represented in the second time period is that the line loss rate of the transformer in each first time period tends to be stable and belongs to positive line loss in the second time period, then for the second time period, the line loss rate of the transformer in the first time period that is relatively changed (i.e. with a larger change amplitude) with respect to the change state is found.

[0149] In a specific implementation, the line loss rate of the transformer in each first time period is compared with a preset line loss threshold, where the line loss threshold is a negative number, such as -10%.

[0150] The attribute of the line loss rate of the transformer in each first time period is queried.

[0151] If the line loss rate of the transformer in a first time period is less than the line loss threshold and the attribute is negative line loss (i.e. negative value), it is determined that the line loss rate of the transformer in the first time period is abruptly changed relative to the change state.

[0152] In step 1043, if found, a fault identifier indicating a fault is generated for the total meter in the first time period.

[0153] In the case where the line loss rate of the transformer in the first time period is abruptly changed relative to the change state, a fault identifier indicating a fault is generated for the total meter in the first time period.

[0154] In step 105, the metering state of the total meter in the first time period is determined in combination of the fault category and the fault identifier.

[0155] In the embodiment, the fault category and the fault identifier are determinations of the metering state of the total meter in different dimensions, so that the information of both the fault category and the fault identifier can be associated to finally determine the metering state of the total meter in the first time period, and thus determine whether the current loop of the total meter is faulty.

[0156] In one case, if the fault category is current loop open and the fault identifier indicates that the total meter is faulty, the first time period in which the current loop is open is queried as a first time range, and the first time period in which the fault identifier is located is queried as a second time range.

[0157] The first time period and the second time range are compared.

[0158] If the first time range and the second time range are the same, it is determined that the metering state of the total meter is short-time current loop open.

[0159] In another case, if the fault category is current loop short and the fault identifier indicates that the total meter is faulty, the first time period in which the current loop is short is queried as a third time range, and the first time period in which the fault identifier is located is queried as a fourth time range.

[0160] The third time period and the fourth time range are compared.

[0161] If the third time range and the fourth time range are the same, it is determined that the metering state of the total meter is short-time current loop short.

[0162] In the embodiment, running data of a designated transformer area is collected, a transformer in the transformer area is configured with a total meter, the running data includes current values and line loss rates, the running data is cleaned under at least one dimension of the transformer area, the transformer and the total meter, interference is eliminated, and quality of the running data is improved, so that reliability of fault detection is improved, if the cleaning is completed, the total meter is divided into fault categories according to the current values in a first time period, the total meter is generated with fault identification in the first time period according to the line loss rates in a second time period, the fault identification indicates whether the total meter has a fault, and the second time period is divided into a plurality of first time periods, and a metering state of the total meter in the first time period is determined in combination with the fault categories and the fault identification. In the embodiment, the change of the current values and the line loss rates of the transformer area are associated and calculated to determine the fault of the current loop of the total meter of the transformer area, the accuracy of fault detection is effectively improved, the usability is strong, the calculation is simple, the embodiment is easy to understand and master, and the calculation resource is small, and the embodiment is more easily integrated into a power system.

[0163] Embodiment two

[0164] Figure 2 A structure diagram of a total meter metering detection device provided in the embodiment two is shown in the figure. Figure 2 As shown in the figure, the device includes:

[0165] A running data collection module 201 is configured to collect running data of a designated transformer area, a transformer in the transformer area is configured with a total meter, and the running data includes current values and line loss rates.

[0166] A data cleaning module 202 is configured to clean the running data under at least one dimension of the transformer area, the transformer and the total meter.

[0167] A fault category division module 203 is configured to divide the total meter into fault categories according to the current values in a first time period if the cleaning is completed.

[0168] A fault identification generation module 204 is configured to generate the total meter with fault identification in the first time period according to the line loss rates in a second time period, the fault identification indicates whether the total meter has a fault, and the second time period is divided into a plurality of first time periods.

[0169] A metering state determination module 205 is configured to determine a metering state of the total meter in the first time period in combination with the fault categories and the fault identification.

[0170] In an embodiment of the application, the data cleaning module 202 includes:

[0171] A light-load elimination module is configured to query a reason for the line loss rate anomaly of the transformer in the second time period; if the reason is light load of the transformer, the operation data related to the light load is eliminated.

[0172] A power supply elimination module is configured to query a power supply state of the transformer; if the power supply state includes a ring network power supply, the operation data related to the ring network power supply is eliminated.

[0173] A replacement elimination module is configured to query a use state of the total meter in the second time period; if the use state is replacement, the operation data related to replacement of the total meter is eliminated.

[0174] A null value elimination module is configured to query a data state of the total meter in the second time period; if the data state includes at least one of a voltage value and a current value being 0, the operation data when at least one of the voltage value and the current value is 0 is eliminated.

[0175] In an embodiment of the present application, the fault category division module 203 includes:

[0176] A total quantity statistical module is configured to count a total quantity of sampling points for collecting the current value in a first time period.

[0177] An abnormal current value identification module is configured to identify the current value in an abnormal state at a certain phase.

[0178] A first quantity statistical module is configured to count a first quantity of the current value in an abnormal state in the first time period.

[0179] A first proportion statistical module is configured to count a first proportion of the first quantity in the total quantity in the same first time period.

[0180] A current loop virtual connection determination module is configured to determine that a fault category of the total meter is current loop virtual connection if the first proportion is greater than or equal to a preset first proportion threshold.

[0181] A second quantity statistical module is configured to count a second quantity of the current value of at least one phase that has been collected in the first time period.

[0182] A second proportion statistical module is configured to count a second proportion of the second quantity in the total quantity in the same first time period.

[0183] A current loop short circuit determination module is configured to determine that a fault category of the total meter is current loop short circuit if the second proportion is less than or equal to a preset second proportion threshold.

[0184] In one embodiment of the present application, the abnormal current value identification module comprises:

[0185] a null value abnormality determination module, configured to determine that the current value is abnormal if the current value of any phase is null;

[0186] a current average value calculation module, configured to calculate, for the current value of each phase, an average value of the current value in a second time period;

[0187] an abnormal threshold generation module, configured to take a specified proportion of the absolute value of the average value as an abnormal threshold;

[0188] a threshold abnormality determination module, configured to determine that the current value is abnormal if the absolute value of the current value of any phase is less than or equal to the abnormal threshold corresponding to the phase.

[0189] In one embodiment of the present application, the fault mark generation module 204 comprises:

[0190] a change state query module, configured to query a change state of the line loss rate of the transformer in each first time period in a second time period;

[0191] a mutation finding module, configured to find, if the change state is that the line loss rate of the transformer in each first time period tends to be stable in a second time period and belongs to positive line loss, the line loss rate of the transformer in the first time period that is mutated relative to the change state;

[0192] a fault mark configuration module, configured to generate, if found, a fault mark indicating that a fault occurs for the total table in the first time period.

[0193] In one embodiment of the present application, the mutation finding module comprises:

[0194] a threshold comparison module, configured to compare the line loss rate of the transformer in each first time period with a preset line loss threshold, the line loss threshold being a negative number;

[0195] an attribute query module, configured to query an attribute of the line loss rate of the transformer in each first time period;

[0196] a mutation determination module, configured to determine that the line loss rate of the transformer in the first time period is mutated relative to the change state if the line loss rate of the transformer in a certain first time period is less than the line loss threshold and the attribute is negative line loss.

[0197] In one embodiment of the present application, the metering state determination module 205 comprises:

[0198] The first range determining module is configured to, if the fault category is the current loop virtual connection and the fault identifier indicates that the total meter is faulty, respectively query the first time period in which the current loop virtual connection is located as a first time range and the first time period in which the fault identifier is located as a second time range.

[0199] The current loop virtual connection marking module is configured to, if the first time range is the same as the second time range, determine that the metering state of the total meter is a short-time current loop virtual connection.

[0200] The second range determining module is configured to, if the fault category is the current loop short connection and the fault identifier indicates that the total meter is faulty, respectively query the first time period in which the current loop short connection is located as a third time range and the first time period in which the fault identifier is located as a fourth time range.

[0201] The current loop short connection marking module is configured to, if the third time range is the same as the fourth time range, determine that the metering state of the total meter is a short-time current loop short connection.

[0202] The total meter metering detection device provided by the embodiment of the present application can execute the total meter metering detection method provided by any embodiment of the present application, and has the corresponding function modules and beneficial effects of executing the total meter metering detection method.

[0203] Embodiment three

[0204] Figure 3 A structural schematic diagram of an electronic device 10 that can be used to implement embodiments of the present application is shown. The electronic device is intended to represent various forms of digital computers, such as laptops, desktops, tablets, personal digital assistants, servers, blade servers, mainframes, and other appropriate computers. The electronic device can also represent various forms of mobile devices, such as personal digital assistants, cellular telephones, smartphones, wearable devices (e.g., headsets, glasses, watches, etc.), and other similar computing devices. The components shown here, their connections and relationships, and their functions, are meant to be examples only, and are not intended to limit the implementations of the present application described and / or claimed in this document.

[0205] As Figure 3As shown, the electronic device 10 includes at least one processor 11, and a memory, such as a read-only memory (ROM) 12, a random access memory (RAM) 13, etc., communicatively connected to the at least one processor 11, where the memory stores a computer program executable by the at least one processor. The processor 11 can perform various appropriate actions and processes according to the computer program stored in the read-only memory (ROM) 12 or loaded into the random access memory (RAM) 13 from the storage unit 18. In the RAM 13, various programs and data required for the operation of the electronic device 10 can also be stored. The processor 11, the ROM 12, and the RAM 13 are connected to each other through a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0206] Various components in the electronic device 10 are connected to the I / O interface 15, including an input unit 16, such as a keyboard, a mouse, etc., an output unit 17, such as various types of displays, a speaker, etc., a storage unit 18, such as a magnetic disk, an optical disk, etc., and a communication unit 19, such as a network card, a modem, a wireless communication transceiver, etc. The communication unit 19 allows the electronic device 10 to exchange information / data with other devices through a computer network, such as the Internet, and / or various telecommunication networks.

[0207] The processor 11 can be various general and / or special-purpose processing components with processing and computing capabilities. Some examples of the processor 11 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various special-purpose artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, a digital signal processor (DSP), and any appropriate processor, controller, microcontroller, etc. The processor 11 performs various methods and processes described above, such as the total table metrology detection method.

[0208] In some embodiments, the total table metrology detection method can be implemented as a computer program tangibly embodied in a computer readable storage medium, such as the storage unit 18. In some embodiments, part or all of the computer program can be loaded and / or installed onto the electronic device 10 via the ROM 12 and / or the communication unit 19. When the computer program is loaded into the RAM 13 and executed by the processor 11, one or more steps of the total table metrology detection method described above can be performed. Alternatively, in other embodiments, the processor 11 can be configured to perform the total table metrology detection method by any other appropriate means, such as by means of firmware.

[0209] The various embodiments of the systems and techniques described above can be implemented in digital electronic circuitry, integrated circuitry, a field programmable gate array (FPGA), an application specific integrated circuit (ASIC), a system on a chip (SOC), a load programmable logic device (CPLD), computer hardware, firmware, software, and / or combinations thereof. These various embodiments can include implementation in one or more computer programs that are executable and / or interpretable on a programmable system including at least one programmable processor, which can be special or general purpose, coupled to receive data and instructions from, and to transmit data and instructions to, a storage system, at least one input device, and at least one output device.

[0210] Computer programs used to implement the processes of the application can be written in any combination of one or more programming languages. These computer programs can be provided to a processor of a general purpose computer, special purpose computer, or other programmable data processing apparatus, such that the computer program

[0211] In the context of the present application, a computer-readable storage medium can be a tangible medium that can contain or store computer programs for use by or in connection with an instruction execution system, apparatus, or device. Computer-readable storage media can include, but are not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or any suitable combination of the foregoing. Alternatively, a computer-readable storage medium can be a machine-readable signal medium. More specific examples of the machine-readable storage medium will include one or more lines of electrical connections, portable computer disks, hard disk drives, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or Flash memory), optical fibers, portable compact disc read-only memories (CD-ROMs), optical storage devices, magnetic storage devices, or any suitable combination of the foregoing.

[0212] To provide for interaction with a user, the systems and techniques described here can be implemented on an electronic device having a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user and a keyboard and a pointing device (e.g., a mouse or a trackball) by which the user can provide input to the electronic device. Other kinds of devices can be used to provide for interaction with a user as well; for example, feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form, including acoustic, speech, or tactile input.

[0213] The systems and techniques described here can be implemented in a computing system that includes a back end component (e.g., as a data server), or that includes a middleware component (e.g., an application server), or that includes a front end component (e.g., a user computer having a graphical user interface or a Web browser through which a user can interact with an implementation of the systems and techniques described here), or any combination of such back end, middleware, or front end components. The components of the system can be interconnected by any form or medium of digital data communication (e.g., a communication network). Examples of communication networks include a local area network (LAN), a wide area network (WAN), blockchain network, and the Internet.

[0214] The computing system can include clients and servers. A client and server are generally remote from each other and typically interact through a communication network. The relationship of client and server arises by virtue of computer programs running on the respective computers and having a client-server relationship to each other. A server can be a cloud server, also known as cloud computing server or cloud host, which is a host product in the cloud computing service system, to solve the defects of large management difficulty and weak business scalability in traditional physical host and VPS service.

[0215] Embodiment Four

[0216] The embodiment of the present application further provides a computer program product, which comprises a computer program, and the computer program implements the total table metering detection method provided in any embodiment of the present application when executed by a processor.

[0217] The computer program code can also be loaded onto a computer, other programmable data processing apparatus, or other devices to cause a series of operational steps to be performed on the computer, other programmable apparatus or other devices to produce the computer implemented process such that the

[0218] It should be understood that the various forms of flow shown in the figures are illustrative examples of implementing the steps of the application. Several of the steps have been expanded to show the various constituent database, application, and process steps used to implement the examples. Other steps have been simplified to more clearly and concisely illustrate main points. The ordering of steps is not essential. For example, some steps can be performed in parallel or in a different order. The embodiments of this application have been described with emphasis on the principles and illustrative examples of the application, and the forgoing description is in terms of preferred embodiments. It is to be understood that not necessarily all aspects or embodiments of the application have been described or will be described with particularity above. It is in no way intended that the application be limited to the embodiments shown herein-accuracy of the drawings and examples in some instances can have developed variations due to sample testing. It is also not intended that the application be limited to the explanations of the preferred embodiments or that the application be limited in scope or meaning to the preferred and alternate embodiments described hereinabove. Many modifications, variations, alterations, and equivalents can be apparent to one of ordinary skill in the art and are to be included within the scope of the present application. Therefore, the true scope of the application is to be indicated by the following claims.

[0219] The foregoing detailed description has set forth various embodiments of the application via the use of specific terminology. However, embodiments thereof should not be construed as limited to the foregoing aspects, since the same can be otherwise altered or modified without departing from the spirit and scope of the inventive subject matter.

Claims

1. A method for measuring and detecting a master meter, characterized in that, include: The operation data is collected for a designated transformer area. The transformers in the designated area are equipped with a master meter. The operation data includes current value and line loss rate. The operating data is cleaned under at least one dimension of the distribution area, the transformer, and the summary table; If the cleaning process is completed, the fault category of the master meter is determined based on the current value within the first time period. Based on the line loss rate within the second time period, a fault identifier is generated for the master table in the first time period. The fault identifier indicates whether the master table has failed. The second time period is divided into multiple first time periods. The metering status of the master meter within the first time period is determined by combining the fault category and the fault identifier; The step of classifying the fault category of the master meter based on the current value within the first time period includes: The total number of sampling points used to collect the current value within the first time period is counted. Identify the current value that is abnormal in a certain phase; During the first time period, the first number of current values ​​that are abnormal is counted; Within the same first time period, the first quantity is counted as a first proportion of the total quantity; If the first proportion is greater than or equal to the preset first proportion threshold, then the fault category of the total table is determined to be a current loop connection failure. During the first time period, a second number of the current values ​​of at least one phase that have been collected is counted; Within the same first time period, the second quantity is counted as a second proportion of the total quantity; If the second proportion is less than or equal to the preset second proportion threshold, then the fault category of the total meter is determined to be a current loop short circuit.

2. The method according to claim 1, characterized in that, The step of cleaning the operating data in at least one dimension of the distribution area, the transformer, and the summary table includes: Inquire about the cause of the abnormal line loss rate of the transformer during the second time period; If the reason is that the transformer is lightly loaded, then the operating data related to the light load will be removed. Query the power supply status of the transformer; If the power supply status includes a ring network power supply switch, then the operating data related to the ring network power supply switch will be removed. Query the usage status of the master table during the second time period; If the usage status is "replacement", then the running data related to the replacement of the master table is removed; Query the data status of the master table in the second time period; If the data status includes at least one of the voltage value and the current value being 0, then the operating data when at least one of the voltage value and the current value is 0 is discarded.

3. The method according to claim 1, characterized in that, The identification of the current value that is abnormal in a certain phase includes: If the current value of any phase is empty, then the current value is determined to be abnormal; For each phase current value, calculate the average value of the current value over the second time period; The absolute value of the average is taken as a specified proportion as the anomaly threshold; If the absolute value of the current value in any phase is less than or equal to the abnormal threshold, then the current value is determined to be abnormal.

4. The method according to claim 1, characterized in that, The step of generating a fault identifier for the summary table in the first time period based on the line loss rate in the second time period includes: Query the change status of the line loss rate of the transformer in each of the first time periods, as represented by the second time period; If the change state is that the line loss rate of the transformer in each of the first time periods tends to be stable and is positive line loss in the second time period, then the line loss rate of the transformer that changes abruptly in the first time period relative to the change state is searched. If found, a fault identifier indicating a fault has occurred is generated for the master table during the first time period.

5. The method according to claim 4, characterized in that, The step of finding the line loss rate of the transformer that changes abruptly relative to the changing state during the first time period includes: The line loss rate of the transformer in each of the first time periods is compared with a preset line loss threshold, wherein the line loss threshold is a negative number; Query the attribute of the line loss rate of the transformer in each of the first time periods; If the line loss rate of the transformer in a certain first time period is less than the line loss threshold and the attribute is negative line loss, then it is determined that the line loss rate of the transformer in the first time period changes abruptly with respect to the change state.

6. The method according to any one of claims 1-5, characterized in that, Determining the metering status of the master meter within the first time period by combining the fault category and the fault identifier includes: If the fault category is a current loop connection and the fault identifier indicates that the master table has failed, then query the first time period in which the current loop connection is located as the first time range, and query the first time period in which the fault identifier is located as the second time range. If the first time range is the same as the second time range, then the metering status of the main meter is determined to be a short-time current loop connection. If the fault category is a current loop short circuit and the fault identifier indicates that the main meter has failed, then query the first time period in which the current loop short circuit occurs as the third time range, and query the first time period in which the fault identifier occurs as the fourth time range. If the third time range is the same as the fourth time range, then the metering status of the main meter is determined to be a short-time current loop short circuit.

7. A master meter measuring and testing device, characterized in that, include: The data acquisition module is used to collect operational data from a designated transformer area. The transformers in the transformer area are equipped with a master meter, and the operational data includes current values ​​and line loss rates. The data cleaning module is used to clean the operating data in at least one dimension of the distribution area, the transformer, and the master table; The fault category classification module is used to classify the fault category of the master table according to the current value within the first time period if the cleaning process is completed. The fault identification generation module is used to generate a fault identification for the master table in the first time period based on the line loss rate in the second time period. The fault identification indicates whether the master table has failed. The second time period is divided into multiple first time periods. A metering status determination module is used to determine the metering status of the master meter within the first time period by combining the fault category and the fault identifier. The fault category classification module includes: The total number statistics module is used to count the total number of sampling points used to collect the current value within the first time period; An abnormal current value identification module is used to identify the current value that is abnormal in a certain phase; The first quantity statistics module is used to count the first quantity of the current values ​​that are abnormal during the first time period. The first percentage statistics module is used to calculate the first percentage of the first quantity in the total quantity within the same first time period. The current loop connection determination module is used to determine the fault category of the total meter as current loop connection if the first proportion is greater than or equal to a preset first proportion threshold. The second quantity statistics module is used to count the second quantity of the current values ​​of at least one phase that have been collected during the first time period. The second percentage statistics module is used to calculate the second percentage of the second quantity in the total quantity within the same first time period. The current loop short circuit determination module is used to determine the fault category of the total meter as current loop short circuit if the second proportion is less than or equal to a preset second proportion threshold.

8. An electronic device, characterized in that, The electronic device includes: At least one processor; and A memory communicatively connected to the at least one processor; wherein, The memory stores a computer program that can be executed by the at least one processor, the computer program being executed by the at least one processor to enable the at least one processor to perform the total meter measurement and detection method according to any one of claims 1-6.

9. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program that, when executed by a processor, implements the total meter measurement and detection method according to any one of claims 1-6.

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