A method, device and equipment for locating abnormal metering points of bus power imbalance

Abstract

The present invention discloses a method, device and equipment for locating abnormal metering points of busbar power imbalance, which relates to the technical field of safe operation of power grids. The method first integrates the system data of the power quantity acquisition system and the data acquisition and monitoring control system to form basic data, and then determines the input-type lines and output-type lines relative to the busbar and the busbar power imbalance rate according to the basic data and the current directions of each line in the same substation with respect to the busbar that have been manually sorted out. Finally, based on the curve coupling relationship between the busbar power imbalance rate and the line power quantity, it is judged whether there is an abnormality in the line. In this way, the real-time nature of the system data can be utilized to quickly locate abnormal metering points when the busbar power is unbalanced. Furthermore, not only can a large amount of manpower and material resources be reduced, achieving the effect of improving quality and efficiency, and guiding the economic operation of substation components, providing a theoretical strategy for loss reduction and efficiency improvement, but also it is beneficial for staff to find out the fault points in time and effectively eliminate the faults.

Description

Technical Field

[0001] The present invention belongs to the technical field of power grid safe operation, and particularly relates to a method, device and equipment for locating abnormal metering points of bus power imbalance. Background Art

[0002] Electric energy has always played a crucial role in the development of China's national economy. In recent years, with the rapid development of China's economy, the social electricity load has been continuously increasing, and the demand for electric energy has also been continuously growing. In order to achieve better economic benefits, power enterprises need to pay more attention to line loss management. The line loss rate is an important economic and technical indicator that comprehensively reflects the power grid planning and design, production operation and management level, and is a sign to measure the level of line loss.

[0003] Monitoring the network loss rate and the bus power imbalance rate is an important part of line loss management work. When the mutation of the bus power imbalance rate exceeds the set threshold, relevant professionals are required to diagnose the mutation reason in time. However, the current diagnostic method for abnormal bus power imbalance rate involves many links, resulting in a long time consumption: According to the statistical analysis of the bus power imbalance rate diagnosis in the power-related profession, if the bus power imbalance rate is abnormal, it takes an average of 85 minutes only in the link of analyzing the abnormal point of the metering device, and it takes an average of 106.67 minutes to complete the whole abnormal processing, which exceeds half of the morning working hours and the work efficiency is very low. Therefore, how to quickly locate the abnormal metering point when the bus power is unbalanced is an urgent research topic for those skilled in the art. Summary of the Invention

[0004] The purpose of the present invention is to provide a method, device, computer equipment and computer-readable storage medium for locating abnormal metering points of bus power imbalance, so as to solve the problems of time-consuming for locating abnormal metering points and low work efficiency when the bus power is unbalanced currently.

[0005] To achieve the above purpose, the present invention adopts the following technical solutions:

[0006] In the first aspect, a method for locating abnormal metering points of bus power imbalance is provided, including:

[0007] Integrate the system data of the power quantity acquisition system and the data acquisition and monitoring control system to form basic data. Among them, the basic data includes first ledger data, second ledger data, first power quantity record data, second power quantity record data, and ledger association data. The first ledger data includes the unique identifier of the first substation, the unique identifier of the first line, the power metering point multiplier corresponding one-to-one to the unique identifier of the first line, and the one-to-many correspondence between the unique identifier of the first substation and the unique identifier of the first line. The second ledger data includes the unique identifier of the second substation, the unique identifier of the second line, and the one-to-many correspondence between the unique identifier of the second substation and the unique identifier of the second line. The first power quantity record data includes the active forward power quantity bottom table value and the active reverse power quantity bottom table value corresponding to the unique identifier of the first line in all historical unit time periods. The second power quantity record data includes the integrated power quantity corresponding to the unique identifier of the second line in all historical unit time periods. The ledger association data includes the one-to-one correspondence between the unique identifier of the first substation and the unique identifier of the second substation and the one-to-one correspondence between the unique identifier of the first line and the unique identifier of the second line;

[0008] According to the one-to-many correspondence between the unique identifier of the first substation and the unique identifier of the first line or the one-to-many correspondence between the unique identifier of the second substation and the unique identifier of the second line in the basic data, and according to the current directions of each line to the busbar in the same substation sorted out manually, determine at least one input line identifier and at least one output line identifier corresponding to the unique identifier of the first substation or the unique identifier of the second substation. Among them, the input line identifier refers to the unique identifier of the first line or the unique identifier of the second line corresponding to the line where the power quantity flows into the busbar, and the output line identifier refers to the unique identifier of the first line or the unique identifier of the second line corresponding to the line where the power quantity flows out of the busbar;

[0009] According to the basic data, calculate the busbar power quantity unbalance rate in the recent multiple historical unit time periods according to the following formula:

[0010]

[0011] In the formula, i represents a positive integer, and BPIR i represents the busbar power quantity unbalance rate in the i-th historical unit time period among the recent multiple historical unit time periods. m represents a positive integer, M represents the total number of identifiers of the at least one input line identifier, and k m represents the power metering point multiplier corresponding to the m-th input line identifier among the at least one input line identifier in the basic data, and a m,iDenote the positive active energy meter reading corresponding to the m-th input line identifier in the basic data during the i-th historical unit period, a m,i-1 Denote the positive active energy meter reading corresponding to the m-th input line identifier in the basic data during the previous adjacent historical unit period, where the previous adjacent historical unit period refers to an adjacent historical unit period that is chronologically before the i-th historical unit period. n represents a positive integer, and N represents the total number of identifiers of the at least one output line identifier, k n Denote the electricity metering point multiplier corresponding to the n-th output line identifier among the at least one output line identifier in the basic data, b n,i Denote the negative active energy meter reading corresponding to the n-th output line identifier in the basic data during the i-th historical unit period, b n,i-1 Denote the negative active energy meter reading corresponding to the n-th output line identifier in the basic data during the previous adjacent historical unit period;

[0012] Based on the bus power imbalance rate in the recent multiple historical unit periods, draw an imbalance rate curve with time as the horizontal coordinate and the bus power imbalance rate as the vertical coordinate;

[0013] For each input line identifier among the at least one input line identifier, draw a corresponding power curve with time as the horizontal coordinate and the integrated power as the vertical coordinate based on the corresponding integrated power in the basic data during the recent multiple historical unit periods. When it is found that the corresponding power curve is linearly similar to the imbalance rate curve, determine that the corresponding line is an abnormal metering point;

[0014] For each output line identifier among the at least one output line identifier, draw a corresponding power curve with time as the horizontal coordinate and the integrated power as the vertical coordinate based on the corresponding integrated power in the basic data during the recent multiple historical unit periods. When it is found that the corresponding power curve is linearly opposite to the imbalance rate curve, determine that the corresponding line is an abnormal metering point;

[0015] Output and display the lines that are abnormal metering points.

[0016] Based on the above invention content, a new solution is provided that is based on an electricity quantity acquisition system and a data acquisition and monitoring control system and can quickly locate abnormal metering points when the busbar electricity quantity is unbalanced. That is, first integrate the system data of the electricity quantity acquisition system and the data acquisition and monitoring control system to form basic data, and then determine the input-type lines and output-type lines relative to the busbar and the busbar electricity quantity imbalance rate according to the basic data and the current directions of each line in the same substation towards the busbar that have been manually sorted out. Finally, based on the curve coupling relationship between the busbar electricity quantity imbalance rate and the line electricity quantity, determine whether there is an abnormality in the line. In this way, the real-time nature of the system data can be utilized to quickly locate abnormal metering points when the busbar electricity quantity is unbalanced. Furthermore, not only can a large amount of manpower and material resources be reduced, achieving the effect of improving quality and efficiency, and guiding the economic operation of substation components, providing a theoretical strategy for loss reduction and efficiency improvement, but it can also help the staff to find the fault points in a timely and effective manner, eliminate the faults, and improve the accuracy of the system data.

[0017] In a possible design, integrating the system data of the electricity quantity acquisition system and the data acquisition and monitoring control system to form basic data includes:

[0018] Parse and obtain the equipment inventory data and period electricity quantity data from the system data file of the electricity quantity acquisition system, and obtain the model data and integrated electricity quantity data of the data acquisition and monitoring control system. Among them, the equipment inventory data includes the first substation unique identifier, the first line unique identifier in the electricity quantity acquisition system, the electric energy metering point multiplier corresponding one-to-one to the first line unique identifier, and the one-to-many correspondence between the first substation unique identifier and the first line unique identifier. The period electricity quantity data includes the electricity quantity base table values collected in all historical unit periods corresponding to the first line unique identifier. The model data includes the second substation unique identifier, the second line unique identifier in the data acquisition and monitoring control system, and the one-to-many correspondence between the second substation unique identifier and the second line unique identifier. The integrated electricity quantity data includes the integrated electricity quantity in all historical unit periods corresponding to the second line unique identifier.

[0019] Directly store the equipment inventory data into the database as the first inventory data in the basic data, and organize and store the period electricity quantity data into the database to form the first electricity record data in the basic data. Among them, the first electricity record data includes the active forward electricity quantity base table value and the active reverse electricity quantity base table value corresponding to the first line unique identifier in all historical unit periods.

[0020] Directly store the model data into the database as the second inventory data in the basic data, and directly store the integrated electricity quantity data into the database as the second electricity record data in the basic data.

[0021] Output and display the data in the device ledger data and the model data for the operation to be associated;

[0022] In response to the manual association operation of the first substation unique identifier in the device ledger data with the first substation unique identifier in the model data and the first line unique identifier in the device ledger data with the first line unique identifier in the model data, form the ledger association data in the basic data, where the ledger association data includes the one-to-one correspondence between the first substation unique identifier and the second substation unique identifier and the one-to-one correspondence between the first line unique identifier and the second line unique identifier.

[0023] In a possible design, integrating the system data of the power quantity acquisition system and the data acquisition and monitoring control system to form basic data further includes:

[0024] Parse and obtain the meter reading data from the system data file of the power quantity acquisition system, where the meter reading data includes the power quantity meter reading values corresponding to the first line unique identifier and collected in a single historical unit period;

[0025] Sort the meter reading data and store it in the database to form the traceability data in the basic data.

[0026] In a possible design, parsing and obtaining the device ledger data and the period power quantity data from the system data file of the power quantity acquisition system includes:

[0027] Receive the E-format file transmitted by the secure file transfer protocol from the power quantity acquisition system;

[0028] Convert the ledger file in the E-format file into a stream and parse it line by line to obtain the device ledger data, and parse the non-ledger file in the E-format file to obtain the period power quantity data / and the meter reading data, where the device ledger data includes the first substation unique identifier, the first line unique identifier, the power metering point multiplier corresponding one-to-one to the first line unique identifier, and the one-to-many correspondence between the first substation unique identifier and the first line unique identifier in the power quantity acquisition system, the period power quantity data includes the power quantity meter reading values corresponding to the first line unique identifier and collected in all historical unit periods, and the meter reading data includes the power quantity meter reading values corresponding to the first line unique identifier and collected in a single historical unit period.

[0029] In a possible design, obtaining the model data and the integrated power quantity data of the data acquisition and monitoring control system includes:

[0030] By means of historical database synchronization, the model data and integrated power consumption data of the data acquisition and monitoring control system are periodically synchronized to the local device, where the model data includes the unique identifier of the second substation, the unique identifier of the second line, and the one-to-many correspondence between the unique identifier of the second substation and the unique identifier of the second line in the data acquisition and monitoring control system, and the integrated power consumption data includes the integrated power consumption corresponding to the unique identifier of the second line and during all historical unit time periods.

[0031] In a possible design, the lines output and displayed as abnormal metering points include:

[0032] For the input line identifier or output line identifier corresponding to the line that is an abnormal metering point, update the corresponding electricity metering point multiplier to:

[0033]

[0034] In the formula, represents the updated value of the corresponding electricity metering point multiplier, k represents the electricity metering point multiplier in the basic data and corresponding thereto, η represents a preset reduction coefficient and the value range is (-1, 0) ∪ (0, 1);

[0035] For the input line identifier or output line identifier corresponding to the line that is an abnormal metering point, substitute the updated value of the corresponding electricity metering point multiplier back into the calculation formula of the bus power imbalance rate in the recent multiple historical unit time periods to obtain the new value of the corresponding bus power imbalance rate in the recent multiple historical unit time periods;

[0036] For the input line identifier or output line identifier corresponding to the line that is an abnormal metering point, if it is found that the new value of the corresponding bus power imbalance rate is within the pre-given range [-2%, 2%], when outputting and displaying the corresponding line, also output and display the updated value of the corresponding electricity metering point multiplier as a reasonable multiplier value, so as to cooperate with on-site personnel to check the actual multiplier and determine whether the corresponding line is a problematic line.

[0037] In a possible design, the lines output and displayed as abnormal metering points include:

[0038] For the input line identifier or output line identifier corresponding to the line that is an abnormal metering point, if there is a corresponding peer line identifier, then the positive active power bottom meter value or negative active power bottom meter value corresponding to the peer line identifier in the basic data and in the i-th historical unit time period is taken as the corresponding negative active power bottom meter value or positive active power bottom meter value in the i-th historical unit time period, and the positive active power bottom meter value or negative active power bottom meter value corresponding to the peer line identifier in the basic data and in the previous adjacent historical unit time period is taken as the corresponding negative active power bottom meter value or positive active power bottom meter value in the previous adjacent historical unit time period, and these are re-substituted into the calculation formula of the bus power imbalance rate in the most recent multiple historical unit time periods to obtain the corresponding new value of the bus power imbalance rate in the most recent multiple historical unit time periods;

[0039] For the input line identifier or output line identifier corresponding to the line that is an abnormal metering point, if it is found that the corresponding new value of the bus power imbalance rate is within the pre-given range [-2%, 2%], then the corresponding line is taken as a problem line and output for display, otherwise the corresponding line is taken as a non-problem line and the output display is terminated.

[0040] In a second aspect, a device for locating abnormal metering points of bus power imbalance is provided, including a data integration module, a line determination module, a calculation module, a curve drawing module, and an output display module;

[0041] The data integration module is used to integrate the system data of the power quantity acquisition system and the data acquisition and monitoring control system to form basic data. Among them, the basic data includes first ledger data, second ledger data, first power quantity record data, second power quantity record data, and ledger association data. The first ledger data includes the first substation unique identifier, the first line unique identifier in the power quantity acquisition system, the power metering point multiplier corresponding one-to-one to the first line unique identifier, and the one-to-many correspondence between the first substation unique identifier and the first line unique identifier. The second ledger data includes the second substation unique identifier, the second line unique identifier in the data acquisition and monitoring control system, and the one-to-many correspondence between the second substation unique identifier and the second line unique identifier. The first power quantity record data includes the active forward power quantity bottom table value and the active reverse power quantity bottom table value corresponding to the first line unique identifier in all historical unit time periods. The second power quantity record data includes the integrated power quantity corresponding to the second line unique identifier in all the historical unit time periods. The ledger association data includes the one-to-one correspondence between the first substation unique identifier and the second substation unique identifier and the one-to-one correspondence between the first line unique identifier and the second line unique identifier;

[0042] The line determination module is communicatively connected to the data integration module and is used to determine at least one input line identifier and at least one output line identifier corresponding to the first substation unique identifier or the second substation unique identifier according to the one-to-many correspondence between the first substation unique identifier and the first line unique identifier or the one-to-many correspondence between the second substation unique identifier and the second line unique identifier in the basic data, and according to the current directions of each line to the busbar in the same substation sorted out manually. Among them, the input line identifier refers to the first line unique identifier or the second line unique identifier corresponding to the line where the power quantity flows into the busbar, and the output line identifier refers to the first line unique identifier or the second line unique identifier corresponding to the line where the power quantity flows out of the busbar;

[0043] The calculation module is communicatively connected to the data integration module and the line determination module respectively, and is used to calculate the busbar power quantity imbalance rate in the most recent multiple historical unit time periods according to the following formula based on the basic data:

[0044]

[0045] In the formula, i represents a positive integer, and BPIR i represents the busbar power quantity imbalance rate in the i-th historical unit time period among the most recent multiple historical unit time periods, m represents a positive integer, M represents the total number of identifiers of the at least one input line identifier, km Denote the power metering point multiple corresponding to the m-th input line identifier in the at least one input line identifier in the basic data, a m,i Denote the active forward power base meter value corresponding to the m-th input line identifier in the basic data, in the i-th historical unit period, a m,i-1 Denote the active forward power base meter value corresponding to the m-th input line identifier in the basic data, in the previous adjacent historical unit period, where the previous adjacent historical unit period refers to an adjacent historical unit period that is chronologically before the i-th historical unit period. n represents a positive integer, N represents the total number of identifiers of the at least one output line identifier, k n Denote the power metering point multiple corresponding to the n-th output line identifier in the at least one output line identifier in the basic data, b n,i Denote the active reverse power base meter value corresponding to the n-th output line identifier in the basic data, in the i-th historical unit period, b n,i-1 Denote the active reverse power base meter value corresponding to the n-th output line identifier in the basic data, in the previous adjacent historical unit period;

[0046] The curve plotting module, communicatively connected to the calculation module, is configured to plot an unbalance rate curve with the horizontal coordinate being time and the vertical coordinate being the bus power unbalance rate according to the bus power unbalance rates in the recent multiple historical unit periods;

[0047] The curve plotting module is further communicatively connected to the data integration module, and is configured to, for each input line identifier in the at least one input line identifier, plot a power curve with the horizontal coordinate being time and the vertical coordinate being the integrated power according to the corresponding integrated power in the basic data and in the recent multiple historical unit periods, and when it is found that the corresponding power curve is linearly similar to the unbalance rate curve, determine that the corresponding line is an abnormal metering point, and is configured to, for each output line identifier in the at least one output line identifier, plot a power curve with the horizontal coordinate being time and the vertical coordinate being the integrated power according to the corresponding integrated power in the basic data and in the recent multiple historical unit periods, and when it is found that the corresponding power curve is linearly opposite to the unbalance rate curve, determine that the corresponding line is an abnormal metering point;

[0048] The output display module, communicatively connected to the curve plotting module, is configured to output and display the lines that are abnormal metering points.

[0049] In a third aspect, the present invention provides a computer device, including a memory, a processor, and a transceiver that are communicatively connected in sequence. Among them, the memory is used to store computer programs, the transceiver is used to send and receive messages, and the processor is used to read the computer programs and execute the method for locating abnormal metering points of bus power imbalance as described in the first aspect or any possible design in the first aspect.

[0050] In a fourth aspect, the present invention provides a computer-readable storage medium, on which instructions are stored. When the instructions are run on a computer, the method for locating abnormal metering points of bus power imbalance as described in the first aspect or any possible design in the first aspect is executed.

[0051] In a fifth aspect, the present invention provides a computer program product containing instructions. When the instructions are run on a computer, the computer is made to execute the method for locating abnormal metering points of bus power imbalance as described in the first aspect or any possible design in the first aspect.

[0052] Beneficial effects of the above solutions:

[0053] (1) The present invention creatively provides a new solution based on the power quantity acquisition system and the data acquisition and monitoring control system, which can quickly locate abnormal metering points when the bus power is unbalanced. That is, first integrate the system data of the power quantity acquisition system and the data acquisition and monitoring control system to form basic data, and then determine the input-type lines and output-type lines relative to the bus and the bus power imbalance rate according to the basic data and the current directions of each line in the same substation towards the bus that have been manually sorted out. Finally, based on the curve coupling relationship between the bus power imbalance rate and the line power quantity, judge whether there is an abnormality in the line. In this way, the real-time nature of the system data can be utilized to quickly locate abnormal metering points when the bus power is unbalanced. Furthermore, not only can a large amount of manpower and material resources be reduced, achieving the effect of improving quality and efficiency, and it can guide the economic operation of substation components, providing a theoretical strategy for reducing losses and increasing efficiency, but it can also help the staff to find the fault point in time and effectively, eliminate the fault, and improve the accuracy of the system data;

[0054] (2) The reasonable magnification value can also be automatically calculated through a preset truth coefficient, achieving the purpose of replacing manual calculation and greatly reducing the calculation time required. Furthermore, the time for judging and suspecting a magnification problem can be reduced, further facilitating the staff to find the fault point in time and effectively, and eliminating the fault;

[0055] (3) The power quantity data of the opposite-end line can also be called to verify whether the line identified as an abnormal metering point is a problematic line, achieving the purpose of replacing manual calculation and greatly reducing the calculation time required. Furthermore, the time for judging the problematic line can be reduced, further facilitating the staff to find the fault point in time and effectively, and eliminating the fault. Brief Description of the Drawings

[0056] In order to more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the following will briefly introduce the drawings required for use in the description of the embodiments or the prior art. Obviously, the drawings in the following description are only some embodiments of the present invention. For those of ordinary skill in the art, without creative efforts, other drawings can also be obtained based on these drawings.

[0057] Figure 1 It is a schematic flowchart of the method for locating the abnormal metering point of bus power imbalance provided by the embodiment of the present application.

[0058] Figure 2 It is a data example diagram of the meter reading data provided by the embodiment of the present application.

[0059] Figure 3 It is a data example diagram of the period power data provided by the embodiment of the present application.

[0060] Figure 4 It is a data example diagram of the st file in the equipment inventory data provided by the embodiment of the present application.

[0061] Figure 5 It is a data example diagram of the am file in the equipment inventory data provided by the embodiment of the present application.

[0062] Figure 6 It is a data example diagram of the cu file in the equipment inventory data provided by the embodiment of the present application.

[0063] Figure 7 It is a daily meter data example diagram obtained based on the data of the power collection system provided by the embodiment of the present application.

[0064] Figure 8 It is a daily meter data example diagram obtained based on the data of the data acquisition and monitoring control system provided by the embodiment of the present application.

[0065] Figure 9 It is an example diagram of the equipment inventory association relationship maintenance page provided by the embodiment of the present application.

[0066] Figure 10 It is a data example diagram of the association table data provided by the embodiment of the present application.

[0067] Figure 11 It is an example diagram of the bus model formula provided by the embodiment of the present application.

[0068] Figure 12 It is an example diagram showing that there is a linearly similar situation in the curve coupling relationship between the bus power imbalance rate and the line power provided by the embodiment of the present application.

[0069] Figure 13 This is an example diagram showing that there is no linear approximation in the curve coupling relationship between the bus power imbalance rate and the line power provided by the embodiments of the present application.

[0070] Figure 14 This is an example diagram showing that there is a linear opposite situation in the curve coupling relationship between the bus power imbalance rate and the line power provided by the embodiments of the present application.

[0071] Figure 15 This is a schematic structural diagram of the bus power imbalance abnormal measurement point positioning device provided by the embodiments of the present application.

[0072] Figure 16 This is a schematic structural diagram of the computer device provided by the embodiments of the present application. Detailed implementation manners

[0073] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the following will briefly introduce the present invention in combination with the accompanying drawings and the description of the embodiments or the prior art. Obviously, the following description of the structures of the drawings is only some embodiments of the present invention. For those of ordinary skill in the art, without creative efforts, other drawings can be obtained based on these drawings. It should be noted here that the description of these embodiments is used to help understand the present invention, but does not constitute a limitation to the present invention.

[0074] It should be understood that although terms such as first and second etc. may be used herein to describe various objects, these objects should not be limited by these terms. These terms are only used to distinguish one object from another. For example, the first object can be called the second object, and similarly the second object can be called the first object, without departing from the scope of the exemplary embodiments of the present invention.

[0075] It should be understood that for the term "and / or" that may appear in this text, it is only a description of the association relationship of associated objects, indicating that there can be three relationships. For example, A and / or B can represent: A exists alone, B exists alone, or A and B exist simultaneously, etc.; another example, A, B and / or C can represent any one of A, B and C or any combination of them; for the term " / and" that may appear in this text, it is a description of another association object relationship, indicating that there can be two relationships. For example, A / and B can represent: A exists alone or A and B exist simultaneously, etc.; in addition, for the character " / " that may appear in this text, generally it represents that the associated objects before and after are an "or" relationship.

[0076] Embodiment:

[0077] Such as Figure 1As shown, the method for locating abnormal metering points of busbar power imbalance provided in the first aspect of this embodiment can be, but is not limited to, executed by a computer device with certain computing resources, such as a platform server, a personal computer (PC, referring to a multi-purpose computer suitable for personal use in terms of size, price, and performance; desktop computers, laptops, small laptops, tablet computers, and ultrabooks all belong to personal computers), a smart phone, a personal digital assistant (PDA), or a wearable device, etc. As Figure 1 shown, the method for locating abnormal metering points of busbar power imbalance can include, but is not limited to, the following steps S1 to S7.

[0078] S1. Integrate the system data of the power acquisition system and the supervisory control and data acquisition (SCADA) system to form basic data. Among them, the basic data includes, but is not limited to, first ledger data, second ledger data, first power record data, second power record data, and ledger association data, etc. The first ledger data includes, but is not limited to, the first substation unique identifier, the first line unique identifier in the power acquisition system, the power metering point multiplier corresponding one-to-one to the first line unique identifier, and the one-to-many correspondence between the first substation unique identifier and the first line unique identifier, etc. The second ledger data includes, but is not limited to, the second substation unique identifier, the second line unique identifier in the supervisory control and data acquisition system, and the one-to-many correspondence between the second substation unique identifier and the second line unique identifier, etc. The first power record data includes, but is not limited to, the active forward power meter reading value and the active reverse power meter reading value corresponding to the first line unique identifier in all historical unit time periods, etc. The second power record data includes, but is not limited to, the integrated power corresponding to the second line unique identifier in all historical unit time periods, etc. The ledger association data includes, but is not limited to, the one-to-one correspondence between the first substation unique identifier and the second substation unique identifier and the one-to-one correspondence between the first line unique identifier and the second line unique identifier, etc.

[0079] In step S1, both the power acquisition system and the supervisory control and data acquisition (SCADA) system are existing systems. Among them, the power acquisition system can provide the following system data: (1) Meter reading data, such as Figure 2As shown, it sequentially includes information such as sequence (i.e., the positioning column during system parsing), number (i.e., the acquisition quantity ID in the cu file, forming a corresponding relationship), time (i.e., the specific time of the current file data), power quantity (i.e., the power quantity value of the acquisition quantity numbered in the file during the period from the time in the file to the last 15 minutes), and quality bit (not explained temporarily as it is not used); (2) Period power quantity data, such as Figure 3 As shown, it sequentially includes information such as sequence (i.e., the positioning column during system parsing), number (i.e., the acquisition quantity ID in the cu file, forming a corresponding relationship), time (i.e., the specific time of the current file data), power quantity (i.e., the bottom value of the time table of the acquisition quantity numbered in the file), and quality bit (not explained temporarily as it is not used); (3) Equipment ledger data, specifically including st files, am files, and cu files. Among them, the st file is as Figure 4 As shown, it sequentially includes information such as sequence (i.e., the positioning column during system parsing), substation ID (i.e., the unique identification column of the substation), substation name (i.e., the name column of the substation), and substation type (i.e., the type column of the substation); The am file is as Figure 5 As shown, it sequentially includes information such as sequence (i.e., the positioning column during system parsing), meter ID (i.e., the unique identification of this acquisition device, also the unique identification of the equipment, having a corresponding relationship with the line), meter name (i.e., the name of this acquisition device, also the equipment name), substation ID (i.e., the substation ID column in the st file, forming a corresponding relationship), substation name (i.e., the substation name in the st file), equipment type (i.e., indicating what type of equipment this acquisition device is installed on, such as a line or a main transformer, from which the equipment type of the equipment can be determined), CT (i.e., the CT ratio of the current acquisition device), PT (i.e., the PT ratio of the current acquisition device), LT (i.e., the magnification of the current acquisition device, also the magnification of the electric energy metering point), and voltage level (i.e., the voltage level of the equipment where the current acquisition device is located); The cu file is as Figure 6 As shown, it sequentially includes information such as sequence (i.e., the positioning column during system parsing), acquisition quantity ID (i.e., the unique identification of the acquisition quantity), description (i.e., the description of the acquisition quantity name), equipment ID (i.e., the meter ID corresponding to the am file, forming a corresponding relationship), CT (i.e., the CT ratio of the current acquisition quantity), PT (i.e., the PT ratio of the current acquisition quantity), LT (i.e., the magnification of the current acquisition quantity, also the magnification of the electric energy metering point), and voltage level (i.e., the voltage level of the equipment where the current acquisition quantity is located). And the data acquisition and monitoring control system can provide the following system data: (4) Integrated power quantity data, including the line ID in the model data and the calculated integrated power quantity; (5) Model data, including data such as substation ID and line ID. Therefore, the system data of the aforementioned integrated power quantity acquisition system and data acquisition and monitoring control system form basic data, and can specifically include but are not limited to the following steps S11 - S14.

[0080] S11. Parse and obtain the equipment inventory data and the period electricity data from the system data file of the electricity quantity acquisition system, and obtain the model data and the integrated electricity quantity data of the data acquisition and monitoring control system. Among them, the equipment inventory data includes, but is not limited to, the first substation unique identifier in the electricity quantity acquisition system (i.e., the substation ID in the st file), the first line unique identifier (i.e., the electricity meter ID in the am file and the equipment type is line), the electricity metering point multiplier corresponding one-to-one to the first line unique identifier (i.e., LT in the cu file), and the one-to-many correspondence between the first substation unique identifier and the first line unique identifier, etc. The period electricity data includes, but is not limited to, the electricity bottom table values (i.e., the electricity in the period electricity data) collected corresponding to the first line unique identifier in all historical unit periods (such as all 15-minute periods), etc. The model data includes, but is not limited to, the second substation unique identifier in the data acquisition and monitoring control system (i.e., the substation ID in the model data), the second line unique identifier (i.e., the line ID in the model data), and the one-to-many correspondence between the second substation unique identifier and the second line unique identifier, etc. The integrated electricity quantity data includes, but is not limited to, the integrated electricity quantity corresponding to the second line unique identifier in all the historical unit periods (i.e., the integrated electricity quantity calculated in the integrated electricity quantity data), etc.

[0081] In the step S11, specifically, device ledger data and period electricity consumption data are parsed and obtained from the system data file of the electricity consumption collection system, including but not limited to: first, receiving the E-format file transmitted from the electricity consumption collection system via the Secure File Transfer Protocol (SFTP); then converting the ledger files (i.e., st files, am files, and cu files) in the E-format file into a stream and parsing them line by line to obtain the device ledger data, and parsing the non-ledger files in the E-format file to obtain the period electricity consumption data / and meter reading data, where the device ledger data includes but is not limited to the first substation unique identifier in the electricity consumption collection system, the first line unique identifier, the electricity metering point multiplier corresponding one-to-one to the first line unique identifier, and the one-to-many correspondence between the first substation unique identifier and the first line unique identifier, etc., the period electricity consumption data includes but is not limited to the electricity meter reading values collected in all historical unit periods corresponding to the first line unique identifier, etc., and the meter reading data includes but is not limited to the electricity meter reading values (i.e., the electricity in the meter reading data) collected in a single historical unit period corresponding to the first line unique identifier. And obtaining the model data and integrated electricity consumption data of the data acquisition and monitoring control system, including but not limited to: synchronizing the model data and integrated electricity consumption data of the data acquisition and monitoring control system to the local device periodically (e.g., every 1 hour) through the historical database synchronization method, where the model data includes but is not limited to the second substation unique identifier, the second line unique identifier in the data acquisition and monitoring control system, and the one-to-many correspondence between the second substation unique identifier and the second line unique identifier, etc., and the integrated electricity consumption data includes but is not limited to the integrated electricity consumption in all historical unit periods corresponding to the second line unique identifier.

[0082] S12. Directly store the device ledger data into the database as the first ledger data in the basic data, and organize and store the period electricity consumption data to form the first electricity consumption record data in the basic data, where the first electricity consumption record data includes but is not limited to the active forward electricity meter reading values and active reverse electricity meter reading values in all historical unit periods corresponding to the first line unique identifier.

[0083] In the step S12, the specific organization method of the period electricity consumption data is the existing conventional method. The finally stored first ledger data and the first electricity consumption record data can be but are not limited to the daily table data as Figure 7 shown. In addition, if the meter reading data is also parsed and obtained from the system data file of the electricity consumption collection system, the meter reading data can also be organized and stored to form the traceability data in the basic data.

[0084] S13. Directly store the model data into the database as the second ledger data in the basic data, and directly store the integrated power quantity data into the database as the second power quantity record data in the basic data.

[0085] In step S13, the finally stored second ledger data and second power quantity record data can be, but are not limited to, daily table data as Figure 8 shown.

[0086] S14. Output and display the data in the equipment ledger data and model data for the pending association operation.

[0087] In step S14, the data in the equipment ledger data and model data for the pending association operation can be, but are not limited to, displayed on the equipment ledger association relationship maintenance page as Figure 9 shown.

[0088] S15. Respond to the manual association operation of the first plant unique identifier in the equipment ledger data with the first plant unique identifier in the model data and the first line unique identifier in the equipment ledger data with the first line unique identifier in the model data, to form the ledger association data in the basic data, where the ledger association data includes, but is not limited to, the one-to-one correspondence between the first plant unique identifier and the second plant unique identifier and the one-to-one correspondence between the first line unique identifier and the second line unique identifier.

[0089] In step S15, the finally stored ledger association data can be, but are not limited to, association table data as Figure 10 shown.

[0090] S2. According to the one-to-many correspondence between the first plant unique identifier and the first line unique identifier or the one-to-many correspondence between the second plant unique identifier and the second line unique identifier in the basic data, and according to the current directions of each line to the busbar in the same plant sorted out manually, determine at least one input line identifier and at least one output line identifier corresponding to the first plant unique identifier or the second plant unique identifier, where the input line identifier refers to the first line unique identifier or the second line unique identifier corresponding to the line where the power quantity flows into the busbar, and the output line identifier refers to the first line unique identifier or the second line unique identifier corresponding to the line where the power quantity flows out of the busbar.

[0091] After the step S2, at least one input line identifier and at least one output line identifier corresponding to the unique identifier of the first substation or the unique identifier of the second substation can also be used to create a bus model formula with conditions such as voltage level, substation, and line. For example, Figure 11 As shown, then the bus model formula is combined with the lines and basic data contained in the topology diagram to form bus data that can be panoramically displayed in the bus power balance intelligent dashboard, and the data flow (forward / reverse) of the lines contained in the bus and the line power calculation formula can be viewed through the bus model formula layer by layer until the specific line metering point, so as to achieve the purpose of viewing metering points by switching multiple systems.

[0092] S3. According to the basic data, calculate the bus power imbalance rate in the most recent multiple historical unit periods according to the following formula:

[0093]

[0094] In the formula, i represents a positive integer, and BPIR i represents the bus power imbalance rate in the i-th historical unit period among the most recent multiple historical unit periods, m represents a positive integer, M represents the total number of identifiers of the at least one input line identifier, and k m represents the power metering point multiplier corresponding to the m-th input line identifier in the at least one input line identifier in the basic data, and a m,i represents the value of the positive active power meter base corresponding to the m-th input line identifier in the basic data and in the i-th historical unit period, and a m,i-1 represents the value of the positive active power meter base corresponding to the m-th input line identifier in the basic data and in the previous adjacent historical unit period. The previous adjacent historical unit period refers to an adjacent historical unit period that is chronologically before the i-th historical unit period. n represents a positive integer, N represents the total number of identifiers of the at least one output line identifier, and k n represents the power metering point multiplier corresponding to the n-th output line identifier in the at least one output line identifier in the basic data, and b n,i represents the value of the reverse active power meter base corresponding to the n-th output line identifier in the basic data and in the i-th historical unit period, and b n,i-1 represents the value of the reverse active power meter base corresponding to the n-th output line identifier in the basic data and in the previous adjacent historical unit period.

[0095] S4. Based on the bus power imbalance rate in the recent multiple historical unit time periods, an imbalance rate curve is plotted with time on the horizontal coordinate and the bus power imbalance rate on the vertical coordinate.

[0096] In step S4, as can be seen from the formula shown in step S3, when there is a large mutation in the power of a certain line, the bus power imbalance rate will also change accordingly. Therefore, by using the coupling relationship between the line power and the bus power imbalance rate, the curve graphs of the bus power imbalance rate and the line power can be plotted separately first, and then whether there is an abnormality in the line can be judged according to the coupling relationship between the two curves. Specifically, the imbalance rate curve can be plotted by, but not limited to, echarts data visualization software.

[0097] S5. For each input line identifier in the at least one input line identifier, based on the corresponding integrated power in the basic data and in the recent multiple historical unit time periods, a power curve with time on the horizontal coordinate and the integrated power on the vertical coordinate is plotted, and when it is found that the corresponding power curve is linearly similar to the imbalance rate curve, the corresponding line is determined as an abnormal metering point.

[0098] In step S5, as Figure 12 shown, since the power curve of the "Guangchang Main Line" is linearly similar to the imbalance rate curve (i.e., increasing or decreasing synchronously), it can be determined that the "Guangchang Main Line" is an abnormal metering point. On the contrary, as Figure 13 shown, since the power curve of the "#1 Transformer - High Voltage" line is not linearly similar to the imbalance rate curve, it can be determined that the "#1 Transformer - High Voltage" line is a normal metering point.

[0099] S6. For each output line identifier in the at least one output line identifier, based on the corresponding integrated power in the basic data and in the recent multiple historical unit time periods, a power curve with time on the horizontal coordinate and the integrated power on the vertical coordinate is plotted, and when it is found that the corresponding power curve is linearly opposite to the imbalance rate curve, the corresponding line is determined as an abnormal metering point.

[0100] In step S6, as Figure 14 shown, since the power curve of the "Tuchang Line" is linearly opposite to the imbalance rate curve (i.e., increasing or decreasing conversely), it can be determined that the "Tuchang Line" is an abnormal metering point.

[0101] S7. Output and display the lines that are abnormal metering points.

[0102] In step S7, the line as an abnormal metering point can be displayed in the busbar power balance smart dashboard but is not limited to, so as to remind the staff to check and confirm whether the line is a problem line, so as to complete the analysis work in the abnormal point link of the metering device.

[0103] Therefore, based on the method for locating abnormal metering points of busbar power imbalance described in the aforementioned steps S1 to S7, a new solution is provided that is based on the power collection system and the data collection and monitoring control system and can quickly locate abnormal metering points when the busbar power is unbalanced, that is, firstly integrate the system data of the power collection system and the data collection and monitoring control system to form basic data, and then determine the input type line and output type line relative to the busbar and the busbar power imbalance rate according to the basic data and the current direction of each line to the busbar that has been manually sorted out in the same plant station, and finally determine whether the line is abnormal based on the curve coupling relationship between the busbar power imbalance rate and the line power. In this way, the real-time nature of the system data can be used to quickly locate the abnormal metering point when the busbar power is unbalanced, thereby not only reducing a large amount of manpower and material resources, but also improving quality and efficiency, and guiding the economic operation of substation components, providing theoretical strategies for reducing losses and increasing efficiency, but also helping staff to find fault points in a timely and effective manner, troubleshoot, and improve the accuracy of system data.

[0104] Based on the technical solution of the first aspect, this embodiment further provides a possible design for enriching the output display content. That is, considering that in the current bus balance diagnosis and analysis problem finding process, the method of initially judging that it is suspected to be a rate problem is to give a hypothetical reasonable rate based on the comparison of the historical electricity of the gateways between different systems, and then calculate it manually, and then let the on-site operation and maintenance personnel verify the actual rate on site. This method is time-consuming and has low accuracy. From the formula of step S3, it can be seen that the bus power imbalance rate is actually a linear combination of a series of values, so that within the given range of the bus power imbalance rate [-2%, 2%], when the meter collects data normally, the rates of all lines are determined according to the actual number of coil turns of the on-site PT and CT, and the actual number of coil turns of the on-site voltage transformer PT (Phase Voltage Transformer) and the current transformer CT (Current Transformer) is limited, that is, the power metering point rate combination is limited. Therefore, in the step of outputting and displaying the line as the abnormal metering point, it may include but is not limited to the following steps S711 to S713.

[0105] S711. For the input line identifier or output line identifier corresponding to the line of the abnormal metering point, the corresponding electric energy metering point multiplier is updated to:

[0106]

[0107] In the formula, represents the updated value of the multiplier corresponding to the power metering point, k represents the multiplier of the corresponding power metering point in the basic data, and η represents a preset true value coefficient with a value range of (-1, 0) ∪ (0, 1).

[0108] In the step S711, the specific preset method of the true value coefficient may include, but is not limited to: calculating multiple multiplier values in advance through the PT turns and CT turns provided on-site, and then obtaining multiple true value coefficients according to the comparison results between the multiple multiplier values and the multiplier of the corresponding power metering point in the basic data. In addition, the true value coefficient can be exemplified as 0.25.

[0109] S712. For the input line identifier or output line identifier corresponding to the line with an abnormal metering point, substitute the updated value of the corresponding power metering point multiplier back into the calculation formula of the bus power imbalance rate in the most recent multiple historical unit time periods to obtain the new value of the corresponding bus power imbalance rate in the most recent multiple historical unit time periods.

[0110] S713. For the input line identifier or output line identifier corresponding to the line with an abnormal metering point, if it is found that the new value of the corresponding bus power imbalance rate is within the pre-given range [-2%, 2%], when outputting and displaying the corresponding line, the updated value of the corresponding power metering point multiplier will also be output and displayed as a reasonable multiplier value, so as to cooperate with on-site personnel to view the actual multiplier and determine whether the corresponding line is a problem line.

[0111] Based on the foregoing possible design one, a reasonable multiplier value can be automatically calculated through the preset true value coefficient, achieving the purpose of replacing manual calculation and greatly reducing the calculation time required, thereby reducing the time for judging and suspecting multiplier problems, and further facilitating the staff to find the fault point and eliminate the fault in a timely and effective manner.

[0112] Based on the technical solution of the foregoing first aspect or possible design one, this embodiment further provides a possible design two for verifying abnormal metering points, that is, considering that in the process of finding problems in the current bus balance diagnosis and analysis, sometimes it is necessary to use the power of the line of the opposite substation to replace the power of the line of this substation for problem analysis. However, for complex substations, when replacement by the opposite end is required, due to the large number of substations involved, the workload of manual switching operation is large and the efficiency is low. Therefore, in the case of excluding the T-connected line, the power and other information of other lines (i.e., the lines of the opposite substation) can be called, and the power of the line with an abnormal metering point can be verified as a problem line by taking the inverse power. Specifically, in the step of outputting and displaying the line with an abnormal metering point, it may include, but is not limited to, the following steps S721 to S722.

[0113] S721. For the input line identifier or output line identifier corresponding to the line that is an abnormal metering point, if there is a corresponding peer line identifier, then take the opposite value of the positive active power base meter value or negative active power base meter value corresponding to this peer line identifier in the basic data and within the \(i\)th historical unit time period as the corresponding negative active power base meter value or positive active power base meter value within the \(i\)th historical unit time period, and take the opposite value of the positive active power base meter value or negative active power base meter value corresponding to this peer line identifier in the basic data and within the previous adjacent historical unit time period as the corresponding negative active power base meter value or positive active power base meter value within the previous adjacent historical unit time period, and re-substitute them into the calculation formula of the bus power imbalance rate in the most recent multiple historical unit time periods to obtain the new value of the corresponding bus power imbalance rate in the most recent multiple historical unit time periods.

[0114] S722. For the input line identifier or output line identifier corresponding to the line that is an abnormal metering point, if it is found that the new value of the corresponding bus power imbalance rate is within the pre-given range \([-2\%, 2\%]\), then take the corresponding line as a problem line and output and display it; otherwise, take the corresponding line as a non-problem line and terminate the output display.

[0115] Thus, based on the foregoing possible design two, it is possible to verify whether the line that is an abnormal metering point is a problem line by calling the power data of the peer line, achieving the purpose of replacing manual calculation and greatly reducing the time required for calculation, and further reducing the time for judging problem lines, which is further conducive to the staff to find the fault point in time and effectively eliminate the fault.

[0116] As Figure 15 shown, in the second aspect of this embodiment, a virtual device for implementing the bus power imbalance abnormal metering point positioning method described in the first aspect or any possible design in the first aspect is provided, including a data integration module, a line determination module, a calculation module, a curve drawing module, and an output display module;

[0117] The data integration module is used to integrate the system data of the power quantity acquisition system and the data acquisition and monitoring control system to form basic data. Among them, the basic data includes first ledger data, second ledger data, first power quantity record data, second power quantity record data, and ledger association data. The first ledger data includes the first substation unique identifier, the first line unique identifier in the power quantity acquisition system, the power metering point multiplier corresponding one-to-one to the first line unique identifier, and the one-to-many correspondence between the first substation unique identifier and the first line unique identifier. The second ledger data includes the second substation unique identifier, the second line unique identifier in the data acquisition and monitoring control system, and the one-to-many correspondence between the second substation unique identifier and the second line unique identifier. The first power quantity record data includes the active forward power quantity base table value and the active reverse power quantity base table value corresponding to the first line unique identifier in all historical unit time periods. The second power quantity record data includes the integrated power quantity corresponding to the second line unique identifier in all historical unit time periods. The ledger association data includes the one-to-one correspondence between the first substation unique identifier and the second substation unique identifier and the one-to-one correspondence between the first line unique identifier and the second line unique identifier;

[0118] The line determination module is communicatively connected to the data integration module and is used to determine at least one input line identifier and at least one output line identifier corresponding to the first substation unique identifier or the second substation unique identifier according to the one-to-many correspondence between the first substation unique identifier and the first line unique identifier or the one-to-many correspondence between the second substation unique identifier and the second line unique identifier in the basic data, and according to the current directions of each line to the busbar in the same substation sorted out manually. Among them, the input line identifier refers to the first line unique identifier or the second line unique identifier corresponding to the line where the power quantity flows into the busbar, and the output line identifier refers to the first line unique identifier or the second line unique identifier corresponding to the line where the power quantity flows out of the busbar;

[0119] The calculation module is communicatively connected to the data integration module and the line determination module respectively, and is used to calculate the busbar power quantity unbalance rate in the recent multiple historical unit time periods according to the following formula based on the basic data:

[0120]

[0121] In the formula, i represents a positive integer, and BPIR i represents the busbar power quantity unbalance rate in the i-th historical unit time period in the recent multiple historical unit time periods, m represents a positive integer, M represents the total number of identifiers of the at least one input line identifier, km It represents the electricity metering point multiple corresponding to the m-th input line identifier in the at least one input line identifier and in the said basic data, a m,i It represents the positive active power meter reading value at the bottom of the meter corresponding to the m-th input line identifier in the said basic data, in the i-th historical unit time period, a m,i-1 It represents the positive active power meter reading value at the bottom of the meter corresponding to the m-th input line identifier in the said basic data, in the previous adjacent historical unit time period. The previous adjacent historical unit time period refers to an adjacent historical unit time period that is chronologically before the i-th historical unit time period. n represents a positive integer, N represents the total number of identifiers of the at least one output line identifier, k n It represents the electricity metering point multiple corresponding to the n-th output line identifier in the at least one output line identifier and in the said basic data, b n,i It represents the negative active power meter reading value at the bottom of the meter corresponding to the n-th output line identifier in the said basic data, in the i-th historical unit time period, b n,i-1 It represents the negative active power meter reading value at the bottom of the meter corresponding to the n-th output line identifier in the said basic data, in the previous adjacent historical unit time period;

[0122] The curve drawing module, communicatively connected to the calculation module, is configured to draw an unbalance rate curve with the horizontal coordinate being time and the vertical coordinate being the bus power unbalance rate according to the bus power unbalance rate in the recent multiple historical unit time periods;

[0123] The curve drawing module is also communicatively connected to the data integration module. For each input line identifier in the at least one input line identifier, it is configured to draw a corresponding power curve with the horizontal coordinate being time and the vertical coordinate being the integrated power according to the corresponding integrated power in the basic data and in the recent multiple historical unit time periods, and when it is found that the corresponding power curve and the unbalance rate curve are linearly similar, it determines that the corresponding line is an abnormal metering point. And for each output line identifier in the at least one output line identifier, it is configured to draw a corresponding power curve with the horizontal coordinate being time and the vertical coordinate being the integrated power according to the corresponding integrated power in the basic data and in the recent multiple historical unit time periods, and when it is found that the corresponding power curve and the unbalance rate curve are linearly opposite, it determines that the corresponding line is an abnormal metering point;

[0124] The output display module, communicatively connected to the curve drawing module, is configured to output and display the lines that are abnormal metering points.

[0125] For the working process, working details, and technical effects of the foregoing device provided in the second aspect of this embodiment, reference may be made to the method for locating abnormal metering points of bus power imbalance described in the first aspect or any possible design in the first aspect, which will not be elaborated herein.

[0126] As Figure 16 shown, in the third aspect of this embodiment, a computer device for executing the method for locating abnormal metering points of bus power imbalance described in the first aspect or any possible design in the first aspect is provided, including a memory, a processor, and a transceiver that are communicatively connected in sequence. Among them, the memory is used to store computer programs, the transceiver is used to send and receive messages, and the processor is used to read the computer programs and execute the method for locating abnormal metering points of bus power imbalance described in the first aspect or any possible design in the first aspect. Specifically, for example, the memory may include, but is not limited to, random access memory (RAM), read-only memory (ROM), flash memory, first input first output (FIFO), and / or first input last output (FILO), etc.; the processor may adopt, but is not limited to, a microprocessor of the STM32F105 series. In addition, the computer device may also include, but is not limited to, a power module, a display screen, and other necessary components.

[0127] For the working process, working details, and technical effects of the foregoing computer device provided in the third aspect of this embodiment, reference may be made to the method for locating abnormal metering points of bus power imbalance described in the first aspect or any possible design in the first aspect, which will not be elaborated herein.

[0128] In the fourth aspect of this embodiment, a computer-readable storage medium storing instructions including the method for locating abnormal metering points of bus power imbalance described in the first aspect or any possible design in the first aspect is provided, that is, instructions are stored on the computer-readable storage medium, and when the instructions run on a computer, the method for locating abnormal metering points of bus power imbalance described in the first aspect or any possible design in the first aspect is executed. Among them, the computer-readable storage medium refers to a carrier for storing data, and may include, but is not limited to, computer-readable storage media such as floppy disks, optical discs, hard disks, flash memories, USB flash drives, and / or memory sticks. The computer may be a general-purpose computer, a dedicated computer, a computer network, or other programmable devices.

[0129] For the working process, working details and technical effects of the aforementioned computer-readable storage medium provided in the fourth aspect of this embodiment, reference may be made to the method for locating abnormal measurement points of bus power imbalance as described in the first aspect or any possible design in the first aspect, which will not be elaborated herein.

[0130] The fifth aspect of this embodiment provides a computer program product containing instructions, which when run on a computer, cause the computer to execute the method for locating abnormal measurement points of bus power imbalance as described in the first aspect or any possible design in the first aspect. Among them, the computer may be a general-purpose computer, a special-purpose computer, a computer network or other programmable devices.

[0131] Finally, it should be noted that the above are only the preferred embodiments of the present invention and are not intended to limit the protection scope of the present invention. Any modifications, equivalent replacements, improvements, etc. made within the spirit and principle of the present invention shall be included in the protection scope of the present invention.

Claims

1. A method for locating an abnormal metering point of busbar power imbalance, characterized in that, Including: Integrating the system data of the power quantity acquisition system and the data acquisition and monitoring control system to form basic data. The basic data includes first ledger data, second ledger data, first power quantity record data, second power quantity record data, and ledger association data. The first ledger data includes the first substation unique identifier, the first line unique identifier in the power quantity acquisition system, the power metering point multiplier corresponding one-to-one to the first line unique identifier, and the one-to-many correspondence between the first substation unique identifier and the first line unique identifier. The second ledger data includes the second substation unique identifier, the second line unique identifier in the data acquisition and monitoring control system, and the one-to-many correspondence between the second substation unique identifier and the second line unique identifier. The first power quantity record data includes the active forward power quantity base table value and the active reverse power quantity base table value corresponding to the first line unique identifier in all historical unit time periods. The second power quantity record data includes the integrated power quantity corresponding to the second line unique identifier in all historical unit time periods. The ledger association data includes the one-to-one correspondence between the first substation unique identifier and the second substation unique identifier and the one-to-one correspondence between the first line unique identifier and the second line unique identifier; According to the one-to-many correspondence between the first substation unique identifier and the first line unique identifier or the one-to-many correspondence between the second substation unique identifier and the second line unique identifier in the basic data, and according to the current directions of each line to the busbar in the same substation sorted out manually, determining at least one input type line identifier and at least one output type line identifier corresponding to the first substation unique identifier or the second substation unique identifier. The input type line identifier refers to the first line unique identifier or the second line unique identifier corresponding to the line where the power quantity flows into the busbar. The output type line identifier refers to the first line unique identifier or the second line unique identifier corresponding to the line where the power quantity flows out of the busbar; According to the basic data, calculating the busbar power quantity unbalance rate in the most recent multiple historical unit time periods according to the following formula: Wherein, i represents a positive integer, and BPIR i represents the bus power imbalance rate of the i-th historical unit period among the most recent multiple historical unit periods, m represents a positive integer, M represents the total number of identifications of the at least one input line identification, and k m represents the electric energy metering point multiple corresponding to the m-th input line identification in the at least one input line identification in the basic data, and a m,i represents the forward active power meter reading value corresponding to the m-th input line identification in the basic data and in the i-th historical unit period, and a m,i-1 represents the forward active power meter reading value corresponding to the m-th input line identification in the basic data and in the previous adjacent historical unit period, where the previous adjacent historical unit period refers to an adjacent historical unit period that is chronologically before the i-th historical unit period, n represents a positive integer, N represents the total number of identifications of the at least one output line identification, and k n represents the electric energy metering point multiple corresponding to the n-th output line identification in the at least one output line identification in the basic data, and b n,i represents the reverse active power meter reading value corresponding to the n-th output line identification in the basic data and in the i-th historical unit period, and b n,i-1 represents the reverse active power meter reading value corresponding to the n-th output line identification in the basic data and in the previous adjacent historical unit period; According to the busbar power quantity unbalance rate in the most recent multiple historical unit time periods, drawing an unbalance rate curve with the horizontal coordinate being time and the vertical coordinate being the busbar power quantity unbalance rate; For each input type line identifier in the at least one input type line identifier, drawing a corresponding power quantity curve with the horizontal coordinate being time and the vertical coordinate being the integrated power quantity according to the corresponding integrated power quantity in the basic data in the most recent multiple historical unit time periods, and when it is found that the corresponding power quantity curve is linearly similar to the unbalance rate curve, determining the corresponding line as an abnormal metering point; For each of the at least one output line identifier, according to the corresponding integrated power consumption in the base data within the most recent multiple historical unit time periods, a power curve is plotted with the horizontal coordinate being time and the vertical coordinate being the integrated power consumption. When it is found that the corresponding power curve has a linear opposite situation with the unbalance rate curve, it is determined that the corresponding line is an abnormal metering point; Output and display the lines identified as abnormal metering points.

2. The method for locating the abnormal metering point of busbar power imbalance according to claim 1, characterized in that Integrate the system data of the power consumption acquisition system and the data acquisition and monitoring control system to form base data, including: Parse and obtain the equipment ledger data and time period power consumption data from the system data file of the power consumption acquisition system, and obtain the model data and integrated power consumption data of the data acquisition and monitoring control system. Among them, the equipment ledger data includes the first substation unique identifier in the power consumption acquisition system, the first line unique identifier, the power metering point multiplier corresponding one-to-one to the first line unique identifier, and the one-to-many correspondence between the first substation unique identifier and the first line unique identifier. The time period power consumption data includes the power consumption bottom table values collected in all historical unit time periods corresponding to the first line unique identifier. The model data includes the second substation unique identifier, the second line unique identifier in the data acquisition and monitoring control system, and the one-to-many correspondence between the second substation unique identifier and the second line unique identifier. The integrated power consumption data includes the integrated power consumption in all historical unit time periods corresponding to the second line unique identifier; Directly store the equipment ledger data into the database as the first ledger data in the base data, and organize and store the time period power consumption data into the database to form the first power consumption record data in the base data. Among them, the first power consumption record data includes the active forward power consumption bottom table value and the active reverse power consumption bottom table value corresponding to the first line unique identifier in all historical unit time periods; Directly store the model data into the database as the second ledger data in the base data, and directly store the integrated power consumption data into the database as the second power consumption record data in the base data; Output and display the data in the equipment ledger data and the model data for the pending association operation; In response to the manual association operation of the first substation unique identifier in the equipment ledger data and the first substation unique identifier in the model data, and of the first line unique identifier in the equipment ledger data and the first line unique identifier in the model data, form the ledger association data in the base data. Among them, the ledger association data includes the one-to-one correspondence between the first substation unique identifier and the second substation unique identifier and the one-to-one correspondence between the first line unique identifier and the second line unique identifier.

3. The method for locating the abnormal metering point of busbar power imbalance according to claim 2, wherein, Integrate the system data of the power consumption acquisition system and the data acquisition and monitoring control system to form base data, further including: Parse and obtain the meter reading data from the system data file of the power quantity acquisition system, where the meter reading data includes the power quantity meter reading value corresponding to the unique identifier of the first line and collected in a single historical unit period. Organize and store the meter reading data into the database to form the traceability data in the basic data.

4. The method for locating the abnormal metering point of busbar power imbalance according to claim 2, wherein Parse and obtain the equipment inventory data and period power quantity data from the system data file of the power quantity acquisition system, including: Receive the E-format file transmitted from the power quantity acquisition system using the Secure File Transfer Protocol. Convert the inventory file in the E-format file into a stream, parse it line by line to obtain the equipment inventory data, and parse the non-inventory file in the E-format file to obtain the period power quantity data and meter reading data. The equipment inventory data includes the unique identifier of the first substation, the unique identifier of the first line, the power metering point multiplier corresponding one-to-one to the unique identifier of the first line, and the one-to-many correspondence between the unique identifier of the first substation and the unique identifier of the first line. The period power quantity data includes the power quantity meter reading value corresponding to the unique identifier of the first line and collected in all historical unit periods. The meter reading data includes the power quantity meter reading value corresponding to the unique identifier of the first line and collected in a single historical unit period.

5. The method for locating the abnormal metering point of busbar power imbalance according to claim 2, wherein Obtain the model data and integrated power quantity data of the Supervisory Control and Data Acquisition (SCADA) system, including: Periodically synchronize the model data and integrated power quantity data of the Supervisory Control and Data Acquisition (SCADA) system to the local device through the historical database synchronization method. The model data includes the unique identifier of the second substation, the unique identifier of the second line, and the one-to-many correspondence between the unique identifier of the second substation and the unique identifier of the second line. The integrated power quantity data includes the integrated power quantity corresponding to the unique identifier of the second line and in all historical unit periods.

6. The method for locating the abnormal metering point of busbar power imbalance according to claim 1, characterized in that Output and display the lines with abnormal metering points, including: For the input line identifier or output line identifier corresponding to the line with an abnormal metering point, update the corresponding power metering point multiplier to: Wherein, represents the updated value of the corresponding electricity metering point multiplier, k represents the electricity metering point multiplier corresponding in the basic data, and η represents a preset truth coefficient with a value range of (-1, 0) ∪ (0, 1); For the input line identifier or output line identifier corresponding to the line with an abnormal metering point, substitute the updated value of the corresponding power metering point multiplier back into the calculation formula of the bus power imbalance rate in the most recent multiple historical unit periods to obtain the new value of the corresponding bus power imbalance rate in the most recent multiple historical unit periods. For the input line identifier or output line identifier corresponding to the line with an abnormal metering point, if it is found that the new value of the corresponding bus power imbalance rate is within the pre-given range [-2%, 2%], when outputting and displaying the corresponding line, also output and display the updated value of the corresponding power metering point multiplier as a reasonable multiplier value to facilitate manual on-site inspection of the actual multiplier to determine whether the corresponding line is a problematic line.

7. The method for locating the abnormal metering point of busbar power imbalance according to claim 1, characterized in that, Output and display the lines with abnormal metering points, including: For the input line identifier or output line identifier corresponding to the line that is an abnormal metering point, if there is a corresponding opposite-end line identifier, the active forward electricity base meter value or the active reverse electricity base meter value corresponding to the opposite-end line identifier in the basic data and in the i-th historical unit period is negated as the corresponding active reverse electricity base meter value or active forward electricity base meter value in the i-th historical unit period, and the active forward electricity base meter value or the active reverse electricity base meter value corresponding to the opposite-end line identifier in the basic data and in the previous adjacent historical unit period is negated as the corresponding active reverse electricity base meter value or active forward electricity base meter value in the previous adjacent historical unit period, and is re-substituted into the calculation formula of the bus electricity unbalance rate in the most recent multiple historical unit periods to obtain the corresponding new value of the bus electricity unbalance rate in the most recent multiple historical unit periods; For the input line identifier or output line identifier corresponding to the line with abnormal metering point, if it is found that the corresponding new value of busbar power imbalance rate is within the predetermined range [-2%, 2%], the corresponding line will be regarded as a problem line and output display will be performed; otherwise, the corresponding line will be regarded as a non-problem line and the output display will be terminated.

8. A positioning device for abnormal measurement points of busbar power imbalance, characterized in that, It includes a data integration module, a route determination module, a calculation module, a curve drawing module and an output display module; The data integration module is used to integrate the system data of the power acquisition system and the data acquisition and monitoring control system to form basic data, wherein the basic data contains the first account data, the second account data, the first power record data, the second power record data and the account-related data, the first account data contains the first plant station unique identifier, the first line unique identifier, the electric energy metering point multiplier corresponding to the first line unique identifier in the power acquisition system, and the one-to-many correspondence between the first plant station unique identifier and the first line unique identifier, the second account data contains the second plant station unique identifier, the second line unique identifier and the one-to-many correspondence between the second plant station unique identifier and the second line unique identifier in the data acquisition and monitoring control system, the first power record data contains the active forward power base meter value and the active reverse power base meter value corresponding to the first line unique identifier and in all historical unit time periods, the second power record data contains the integrated power corresponding to the second line unique identifier and in all historical unit time periods, and the account-related data contains the one-to-one correspondence between the first plant station unique identifier and the second plant station unique identifier and the one-to-one correspondence between the first line unique identifier and the second line unique identifier; The line determination module is communicatively connected to the data integration module and is configured to determine at least one input line identifier and at least one output line identifier corresponding to the first substation unique identifier or the second substation unique identifier according to the one-to-many correspondence between the first substation unique identifier and the first line unique identifier or the one-to-many correspondence between the second substation unique identifier and the second line unique identifier in the basic data, and according to the current directions of each line to the busbar in the same substation sorted out manually, wherein the input line identifier refers to the first line unique identifier or the second line unique identifier corresponding to the line where the electric energy flows into the busbar, and the output line identifier refers to the first line unique identifier or the second line unique identifier corresponding to the line where the electric energy flows out of the busbar; The calculation module is respectively communicatively connected to the data integration module and the line determination module and is configured to calculate the busbar power imbalance rate in the most recent multiple historical unit time periods according to the following formula based on the basic data: Wherein, i represents a positive integer, and BPIR i represents the bus power imbalance rate of the i-th historical unit period among the most recent multiple historical unit periods, m represents a positive integer, M represents the total number of identifications of the at least one input line identification, and k m represents the power metering point multiplier corresponding to the m-th input line identification in the at least one input line identification in the basic data, and a m,i represents the value of the active forward power base meter corresponding to the m-th input line identification in the basic data and in the i-th historical unit period, and a m,i-1 represents the value of the active forward power base meter corresponding to the m-th input line identification in the basic data and in the previous adjacent historical unit period, where the previous adjacent historical unit period refers to an adjacent historical unit period that is chronologically before the i-th historical unit period, n represents a positive integer, N represents the total number of identifications of the at least one output line identification, and k n represents the power metering point multiplier corresponding to the n-th output line identification in the at least one output line identification in the basic data, and b n,i represents the value of the active reverse power base meter corresponding to the n-th output line identification in the basic data and in the i-th historical unit period, and b n,i-1 represents the value of the active reverse power base meter corresponding to the n-th output line identification in the basic data and in the previous adjacent historical unit period; The curve plotting module is communicatively connected to the calculation module and is configured to plot an imbalance rate curve with the horizontal coordinate being time and the vertical coordinate being the busbar power imbalance rate according to the busbar power imbalance rate in the most recent multiple historical unit time periods; The curve plotting module is also communicatively connected to the data integration module and is configured to, for each input line identifier among the at least one input line identifier, plot a power curve with the horizontal coordinate being time and the vertical coordinate being the integrated power according to the corresponding integrated power in the basic data and in the most recent multiple historical unit time periods, and determine that the corresponding line is an abnormal metering point when it is found that the corresponding power curve is linearly similar to the imbalance rate curve, and is configured to, for each output line identifier among the at least one output line identifier, plot a power curve with the horizontal coordinate being time and the vertical coordinate being the integrated power according to the corresponding integrated power in the basic data and in the most recent multiple historical unit time periods, and determine that the corresponding line is an abnormal metering point when it is found that the corresponding power curve is linearly opposite to the imbalance rate curve; The output display module is communicatively connected to the curve plotting module and is configured to output and display the lines that are abnormal metering points.

9. A computer device, characterized in that, It includes a memory, a processor, and a transceiver that are communicatively connected in sequence, wherein the memory is used to store a computer program, the transceiver is used to send and receive messages, and the processor is used to read the computer program and execute the method for locating abnormal metering points of busbar power imbalance according to any one of claims 1 to 7.

10. A computer-readable storage medium, characterized in that ,An instruction is stored on the computer-readable storage medium, and when the instruction runs on a computer, it executes the method for locating abnormal metering points of busbar power imbalance according to any one of claims 1 to 7.

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