Management line loss positioning method, system, equipment, medium and product of distribution line automation equipment

Abstract

The invention relates to the technical field of power systems, and discloses a management line loss positioning method, system and device of distribution line automation equipment, a medium and a product. According to the method, whether the management line loss abnormity exists in the line or not is judged by judging whether the proportion of the difference value of the statistical power consumption and the technical power consumption of each line in the current statistical period to the total power supply quantity of the line exceeds the preset first proportion threshold value or not, and the line is determined to be the management line loss abnormity line. If yes, the troubleshooting range of the management line loss is shortened to be within the automatic segments, whether the line loss state of the automatic segments is abnormal or not is judged according to the loss data of all the automatic segments on the line with the abnormal management line loss, and the automatic segments with the abnormal line loss state are screened as sections with the abnormal management line loss; therefore, the precision and efficiency of management line loss positioning are improved, and the abnormal accurate identification from the line level to the segment level is realized.

Description

Technical Field

[0001] This invention relates to the field of power system technology, and in particular to a method, system, device, medium, and product for locating line losses in power distribution line automation equipment. Background Technology

[0002] Line loss rate is a key economic indicator for measuring the planning, operation, and management level of power grids. It mainly includes technical line loss and management line loss. Technical line loss is the energy loss caused by the inherent physical characteristics (such as resistance) of transmission lines and transformers, and can be calculated theoretically. Management line loss is mainly caused by non-technical factors such as metering device errors, data acquisition failures, and electricity theft.

[0003] Currently, with the improvement of distribution automation, a large number of automated segments (such as pole-mounted circuit breakers) have been deployed on the distribution network. These switches typically integrate intelligent terminals, enabling the collection and uploading of operational data such as voltage and current, providing a data foundation for more refined line loss analysis. At the same time, power companies have generally established integrated data platforms capable of accessing data from multiple systems, including dispatching, marketing, and electricity consumption information collection, making big data analysis possible.

[0004] However, in actual line loss management, current statistical analysis is mostly conducted on the entire distribution line or transformer substation as the smallest unit. When an abnormal line loss rate is found in a transformer substation or the overall line, maintenance personnel find it difficult to quickly determine whether the root cause of the abnormality occurs in a section of the main line, a branch line, or the user side. This results in a huge scope of investigation, often requiring manual "carpet-style" inspections, which is not only time-consuming and labor-intensive (traditional investigations may take several hours), but also prone to missing problem points. Especially in complex environments, the granularity of line loss anomaly location is coarse, leading to low investigation efficiency. Summary of the Invention

[0005] In view of this, in order to solve the above-mentioned technical problems, the present invention provides a method, system, equipment, medium and product for locating line losses in power distribution line automation equipment.

[0006] The first aspect of this invention provides a method for locating line losses in power distribution line automation equipment, comprising:

[0007] For each segment of the power distribution line, obtain the statistical power loss and technical power loss of the line in the current statistical period.

[0008] Obtain the first difference between the statistical power loss and the technical power loss of the line, and determine whether the proportion of the first difference to the total power supply of the line exceeds a preset first proportion threshold.

[0009] If the proportion of the first difference to the total power supply of the line exceeds the preset first proportion threshold, the line is identified as a line with abnormal line loss.

[0010] Obtain the loss data of each automated segment on the line with abnormal line loss, determine whether the line loss status of each automated segment is abnormal based on the loss data, and filter out the automated segments with abnormal line loss status as the line loss abnormal management segments.

[0011] Preferably, the method further includes:

[0012] Obtain the net positive active power at the substation gate of the line in the current statistical period, and the sum of the net positive active power of all distribution transformers. Based on the difference between the net positive active power at the substation gate and the sum of the net positive active power of all distribution transformers, determine the statistical loss power of the line in the current statistical period.

[0013] Preferably, the method further includes:

[0014] The active power loss of each conductor segment on the line is obtained, and the active power loss of each conductor segment is accumulated according to the sampling time to obtain the total conductor loss of the line at each time. The total conductor loss of the line at each time is integrated over time within the current statistical period to obtain the conductor technical power loss of the line within the current statistical period.

[0015] The load rate of each public distribution transformer corresponding to the line at each sampling time is obtained. Combined with the typical no-load loss and full-load loss parameters in the equipment ledger, the active power loss of each public distribution transformer at each time is calculated. The active power loss of all public distribution transformers in the current statistical period is accumulated and integrated to obtain the technical power loss of the public distribution transformers in the current statistical period of the line.

[0016] The technical power loss of the line in the current statistical period is determined based on the sum of the technical power loss of the conductor and the technical power loss of the public distribution transformer.

[0017] Preferably, the step of acquiring loss data for each automated segment on the line with abnormal line loss, determining whether the line loss status of each automated segment is abnormal based on the loss data, and selecting automated segments with abnormal line loss status as managed line loss abnormal segments includes:

[0018] Obtain loss data for each automated segment on the line with abnormal line loss; wherein, the loss data includes the statistical power loss and technical power loss of each automated segment in the current statistical period;

[0019] For each of the automated segments, a second difference between the statistical power loss and the technical power loss of the automated segment is obtained, and it is determined whether the proportion of the second difference to the active power flowing into the automated segment is greater than a preset second proportion threshold.

[0020] If the proportion of the second difference to the active power flowing into the automated segment is greater than the preset second proportion threshold, then the line loss status of the automated segment is determined to be abnormal, and the automated segment with abnormal line loss status is determined to be the managed line loss abnormal segment.

[0021] Preferably, the method further includes:

[0022] The active power of the automated segment at each sampling time within the current statistical period is obtained, and the active power at each sampling time is integrated within the current statistical period to obtain the active power flowing into the automated segment.

[0023] The sum of the net positive active power of all distribution transformers in the current statistical period is obtained for the automated segment. The difference between the inflow active power and the sum of the net positive active power of all distribution transformers is calculated to obtain the statistical power loss of the automated segment.

[0024] Preferably, the method further includes:

[0025] The active power loss of each conductor segment in the current statistical period is obtained, and the active power loss of each conductor segment is added together to obtain the technical power loss of the automated segment in the current statistical period.

[0026] Secondly, the present invention also provides a management line loss location system for power distribution line automation equipment, comprising:

[0027] The line loss acquisition module is used to acquire the statistical power loss and technical power loss of each segment of the power distribution line in the current statistical period.

[0028] The judgment module is used to obtain a first difference between the statistical power loss and the technical power loss of the line, and to determine whether the proportion of the first difference to the total power supply of the line exceeds a preset first proportion threshold.

[0029] The line anomaly identification module is used to identify the line as a line with abnormal management line loss when the proportion of the first difference to the total power supply of the line exceeds the preset first proportion threshold.

[0030] The line loss section location module is used to acquire the loss data of each automated segment on the line with abnormal line loss, determine whether the line loss status of each automated segment is abnormal based on the loss data, and filter out the automated segments with abnormal line loss status as the line loss abnormal section.

[0031] Thirdly, the present invention also provides an electronic device, the electronic device including a memory and a processor, the memory storing a computer program, the computer program being executed by the processor causing the processor to perform the steps of the management line loss location method for power distribution line automation equipment as described in the first aspect.

[0032] Fourthly, the present invention also provides a computer-readable storage medium having a computer program stored thereon, which, when executed, implements the steps of the management line loss location method for power distribution line automation equipment as described in the first aspect.

[0033] Fifthly, the present invention also provides a computer program product comprising a computer program stored on a non-transitory computer-readable storage medium, the computer program comprising program instructions, wherein, when the program instructions are executed by a computer, the computer performs the steps of the management line loss location method for power distribution line automation equipment as described in the first aspect.

[0034] As can be seen from the above technical solutions, this invention determines whether there is an abnormality in the management line loss of a line by checking whether the difference between the statistical power loss and the technical power loss of each line in the current statistical period exceeds a preset first threshold. Once a line is determined to be a line with an abnormal management line loss, the scope of the investigation is narrowed down to the automated segments. By using the loss data of each automated segment on the line with an abnormal management line loss, the line loss status of the automated segment is determined to be abnormal, and the automated segments with abnormal line loss status are selected as sections with abnormal management line loss, thereby improving the accuracy and efficiency of the management line loss location and achieving accurate identification of anomalies from the line level to the segment level. Attached Figure Description

[0035] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0036] Figure 1 This is an application environment diagram of a method for locating line losses in power distribution line automation equipment provided in an embodiment of the present invention;

[0037] Figure 2 A flowchart illustrating a method for locating line losses in power distribution line automation equipment, as provided in an embodiment of the present invention;

[0038] Figure 3 This is a schematic diagram of the structure of a 10kV feeder provided in an embodiment of the present invention;

[0039] Figure 4 This is a schematic diagram of the structure of a line loss location management system for power distribution line automation equipment provided in an embodiment of the present invention;

[0040] Figure 5 This is a schematic diagram of the structure of an electronic device provided in an embodiment of the present invention. Detailed Implementation

[0041] To enable those skilled in the art to better understand the present invention, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0042] Currently, with the continuous improvement of distribution automation, various automated segmentation devices, such as pole-mounted circuit breakers, are widely deployed in distribution networks. These switching devices typically integrate intelligent terminals, possessing the ability to collect and upload key operational data such as voltage and current in real time, laying a solid data foundation for achieving more refined and accurate line loss analysis. At the same time, major power companies have generally built integrated data management platforms capable of integrating data resources from multiple business segments, including dispatching systems, marketing systems, and electricity consumption information collection systems, providing technical support and platform assurance for conducting line loss analysis and mining based on big data technology.

[0043] However, in actual line loss management, the entire distribution line or power supply area is still generally used as the smallest unit for statistics and analysis. When the system detects abnormal fluctuations in the line loss rate of a certain area or the entire line, maintenance personnel often find it difficult to quickly and accurately determine the specific source of the anomaly. The problem may occur in a section of the main line, a branch line, or the power consumption link on the user side, but due to the lack of refined segmented analysis methods, the scope of investigation is greatly expanded. In this case, a large number of personnel are usually required to conduct "carpet-style" on-site inspections and tests. The whole process not only consumes a lot of time and human resources—for example, traditional investigation methods may take several hours or even longer—but is also very easy to miss key problems due to human negligence or on-site conditions. Especially in areas with complex terrain, harsh environments, or dense load distribution, the granularity of locating line loss anomalies is particularly coarse, resulting in low overall investigation efficiency and seriously restricting the timeliness and accuracy of line loss management. This invention constructs a segmented topology model and a multi-source data fusion analysis mechanism to address this issue.

[0044] Therefore, the method for locating line losses in the management of power distribution line automation equipment provided in this application embodiment can be applied to, for example... Figure 1 In the application environment shown, terminal 101 communicates with server 102 via a network. A data storage system can store the data that server 102 needs to process. The data storage system can be integrated onto server 102 or placed on the cloud or other network servers. For each segment of the power distribution line, terminal 101 or server 102 obtains the statistical power loss and technical power loss of the line within the current statistical period; obtains the first difference between the statistical power loss and technical power loss of the line, and determines whether the proportion of the first difference to the total power supply of the line exceeds a preset first proportion threshold; if the proportion of the first difference to the total power supply of the line exceeds the preset first proportion threshold, the line is identified as a line with abnormal line loss under management; obtains the loss data of each automated segment on the line with abnormal line loss, and determines whether the line loss status of each automated segment is abnormal based on the loss data, and filters out automated segments with abnormal line loss status as sections with abnormal line loss under management.

[0045] Terminal 101 can be, but is not limited to, various personal computers, laptops, smartphones, and tablets.

[0046] Server 102 can be a standalone physical server, a server cluster or distributed system consisting of multiple physical servers, or a cloud server that provides cloud computing services.

[0047] like Figure 2 As shown, this application provides a method for locating line losses in power distribution line automation equipment, which is applied to... Figure 1Taking terminal 101 or server 102 as an example, the explanation includes the following steps S1 to S4. Wherein:

[0048] Step S1: For each segment of the power distribution line, obtain the statistical power loss and technical power loss of the line in the current statistical period.

[0049] The line is a complete loop structure composed of multiple feeder lines originating from the busbar of the power distribution system. Each feeder line includes multiple automated switching devices, segmented conductor sections (specifically referring to each actual overhead line or underground cable section in the line, which are the physical entities that constitute the power grid), interconnection switching devices for connecting different lines, and distribution transformers that perform power conversion functions, among other important components.

[0050] Statistical power loss refers to the difference between the net positive active power measured at the busbar and the sum of the net positive active power of all distribution transformers connected to the line within a specific statistical period. It reflects the energy loss caused by various factors during actual power supply and is one of the important indicators for measuring line operating efficiency. Technical power loss, on the other hand, is calculated using the forward-backward substitution method, combined with actual line parameters and detailed operational data, through precise analysis and derivation. This part of the loss mainly includes the energy loss caused by factors such as conductor resistance, and the energy consumed by the public distribution transformers themselves during operation. It is a technical assessment combining theoretical calculations and practical real-world conditions.

[0051] Step S2: Obtain the first difference between the statistical power loss and the technical power loss of the line, and determine whether the proportion of the first difference to the total power supply of the line exceeds the preset first proportion threshold.

[0052] During power line operation, the first difference is obtained by calculating the difference between the statistical power loss and the technical power loss. This difference effectively reflects the degree of line loss in actual operation and is an important indicator for measuring power transmission efficiency and line operating status. Furthermore, comparing the first difference with the total power supply of the line to determine its proportion provides a more intuitive representation of the actual line loss within the total power supply, thus providing a quantitative basis for line loss analysis and management. If this proportion exceeds a preset first proportion threshold, it indicates a significant abnormality in line loss. This usually signifies non-technical loss factors in line operation, possibly caused by metering errors, electricity theft, or management oversights. In this case, further diagnostic procedures need to be initiated to locate the specific abnormal section and take appropriate measures for investigation and handling.

[0053] The total power supply of a power line refers to the net positive active power transmitted by the power line within a specific statistical period, and is one of the important indicators for measuring the power transmission situation. In order to accurately calculate this value, it is first necessary to collect all positive active power recorded by the power metering device of the line within the same statistical period, as well as any possible reverse active power. Then, the final net power supply result is obtained by calculating the difference between the two.

[0054] Positive active power typically refers to the electrical energy transmitted from the power source to the load. This energy represents the main direction of energy flow in the power grid and is primarily used to drive the normal operation of various electrical devices. Reverse active power, on the other hand, reflects the feedback of electrical energy from the load to the power source under certain specific conditions, such as when distributed energy resources are connected to the grid or when the load has generating capacity. By accurately calculating the difference between these two quantities, the net positive active power actually consumed or supplied by the line can be determined. This indicator not only accurately reflects the net direction of energy flow in the power grid but also provides important data for evaluating the power supply efficiency of lines, optimizing energy distribution, and monitoring the operating status of the power grid, thereby comprehensively improving the economy and stability of the power grid.

[0055] The first percentage threshold can be flexibly adjusted based on experience and data analysis in actual operation, and can usually be initially set to about 5%. When the calculated percentage of the first difference exceeds the preset threshold, it is determined that there is an obvious abnormality in the management line loss of the transmission or distribution line, and further investigation of human factors or management loopholes is required.

[0056] Step S3: If the proportion of the first difference to the total power supply of the line exceeds the preset first proportion threshold, the line is identified as a line with abnormal line loss.

[0057] If the proportion of the first difference to the total power supply of the line does not exceed the preset first proportion threshold, the line loss of the line can be considered to be within the normal range. Therefore, there is no need to carry out further positioning and in-depth analysis. The focus can be shifted to continuously monitoring the operating status of other lines to ensure the stability and efficiency of the overall power grid operation.

[0058] When the proportion of the first difference to the total power supply of the line does not exceed the preset first proportion threshold, it indicates that the line loss of the line is within the normal range, and no further location and in-depth analysis is required. At this time, the focus can be shifted to continuously monitoring the operating status of other lines to ensure the stability and efficiency of the overall power grid operation.

[0059] Step S4: Obtain the loss data of each automated segment on the line with abnormal line loss, and determine whether the line loss status of each automated segment is abnormal based on the loss data, and filter out the automated segments with abnormal line loss status as the line loss abnormal management segments.

[0060] Automated segmentation refers to independent line sections defined by feeder automation switches on the power distribution line. Each automated segment generates corresponding loss data during operation, specifically including statistical and technical power loss within a specific statistical period. By comprehensively analyzing this loss data, it is possible to determine whether there are any abnormalities in the line loss status of each automated segment. If the line loss data of a segment exceeds a reasonable range, that segment is determined to be a managed line loss abnormality segment. The system will automatically generate an abnormality notification and send it to relevant marketing personnel for further investigation into whether there are any meter malfunctions or abnormal electricity usage behaviors such as theft or leakage in that segment.

[0061] It should be noted that, in this embodiment of the application, the difference between the statistical power loss and the technical power loss of each line in the current statistical period is used to determine whether the ratio of the difference to the total power supply of the line exceeds a preset first ratio threshold to determine whether there is an abnormality in the line loss. If the line is determined to be a line with abnormal line loss, the scope of investigation of line loss is shortened to the automated segment. The loss data of each automated segment on the line with abnormal line loss is used to determine whether the line loss status of the automated segment is abnormal, and the automated segment with abnormal line loss status is selected as the line loss abnormal section, thereby improving the accuracy and efficiency of line loss location and realizing accurate identification of anomalies from the line level to the segment level.

[0062] In some embodiments, the method further includes: obtaining the net positive active power of the substation gate of the line in the current statistical period, and the sum of the net positive active power of all distribution transformers, and determining the statistical loss power of the line in the current statistical period based on the difference between the net positive active power of the substation gate and the sum of the net positive active power of all distribution transformers.

[0063] Among them, net positive active power refers to the net value after subtracting reverse active power from the positive active power recorded by the power metering device, reflecting the actual power supplied and effectively used by users.

[0064] Among them, such as Figure 3 For any 10kV feeder shown, M1 represents the 10kV outgoing switchgear of the substation. It can collect electrical quantities such as voltage, current, active power, reactive power, power factor, forward active energy, and reverse active energy of the 10kV feeder and upload them to the main station. The collection frequency may vary depending on technical conditions, but it is generally uploaded once every 15 minutes. The arrow next to the switch indicates the reference direction for collecting electrical quantities.

[0065] F1-F4 represent feeder automation switches. F3 is a tie switch, powered by different lines on both sides, and is normally open during operation. The line from the 10kV switchgear of the substation to the tie switch is called the main line, and other lines are called branch lines. Switches on both sides of the main line are called section switches, such as F1 and F2. Switches on one side of the main line are called branch switches, such as F4. The lines between adjacent automation switches or on the load side of the end branch switch are called an automation section. For example, the lines between F1 and F2, between F2, F3, and F4, or on the load side of F4 are all automation sections.

[0066] Each automated switch can collect its own electrical quantities such as voltage, current, active power, reactive power, and power factor in real time and upload them to the main station. The collection frequency may vary depending on technical conditions, but it is generally uploaded once every 10 minutes. The arrow next to the switch indicates the reference direction for collecting electrical quantities.

[0067] L11, ..., L4n represent the distribution transformers on the line. Each distribution transformer can collect its own electrical quantities such as voltage, current, active power, reactive power, power factor, forward active energy, and reverse active energy, and upload them to the main station. The frequency of data collection may vary depending on technical conditions, but it is generally uploaded once every 15 minutes. The arrow next to the switch indicates the reference direction for collecting electrical quantities.

[0068] In the diagram, the connection points between electrical equipment (distribution transformers, branch lines, etc.) and the lines represent electrical connection points. In practice, these could be connection devices such as poles, cable heads, etc. The lines between these electrical connection points are called conductor segments. The power supply department's feeder ledger records the model and length of each conductor segment, and the impedance value of each conductor segment can be obtained by looking up a table.

[0069] Assume that within a certain statistical period, the positive active power measured at substation gate M1 is: Reverse active power is This allows us to obtain the net positive active power at the substation gate. = - Similarly, any distribution transformer L ij The measured positive active power is Reverse active power is Then any distribution transformer L ij Net positive active power measured within the statistical period.

[0070] (1)

[0071] Suppose that at a certain moment, the voltage measured at the substation gate M1 is UM1.

[0072] Any distribution transformer Lij The measured active power is P Lij The reactive power is Q Lij A positive measurement indicates that the power direction is consistent with the reference direction; a negative measurement indicates that it is inconsistent. Any feeder automatic switch F i Measured absolute value of active power | PF i | Absolute value of reactive power|QF i All measured values ​​are positive, but the actual sign is unknown.

[0073] In this application, in order to obtain the statistical loss of the line in the current statistical period, the net positive active power EM1 of the substation gate M1 and the sum of the net positive active power of all distribution transformers are first obtained. The sum of the net positive active power EM1 and the net positive active power of all distribution transformers is used. The difference can be used to obtain the statistical power loss of the line during the statistical period.

[0074] In some embodiments, the method further includes: obtaining the active power loss of each conductor segment on the line; accumulating the active power loss of each conductor segment according to the sampling time to obtain the total conductor loss of the line at each time; and performing time integration on the total conductor loss of the line at each time within the current statistical period to obtain the conductor technical loss of the line within the current statistical period; obtaining the load rate of each public distribution transformer corresponding to the line at each sampling time; calculating the active power loss of each public distribution transformer at each time by combining the typical no-load loss and full-load loss parameters in the equipment ledger; accumulating and integrating the active power losses of all public distribution transformers within the current statistical period to obtain the public distribution transformer technical loss of the line within the current statistical period; and determining the technical loss of the line within the current statistical period based on the sum of the conductor technical loss and the public distribution transformer technical loss.

[0075] Active power loss is the heat loss generated by the current flowing through the resistance of the conductors and the transformer core and windings. Its magnitude is directly proportional to the square of the load current, the resistance value, and the operating time, conforming to the basic principle of Joule's law. Typical no-load loss is the core loss of the transformer when it is running under no-load at rated voltage, mainly caused by hysteresis and eddy currents. Typical full-load loss includes the sum of winding copper loss and core loss at rated current. Both are determined based on the equipment's factory test report.

[0076] Technical losses include conductor technical losses and public distribution transformer technical losses. The calculation method for conductor technical losses is as follows:

[0077] (1) Obtain the active power of each distribution transformer at each sampling time. and reactive power The voltage UM1 at substation gate M1 is used to calculate the current of each conductor segment at each sampling time using the "forward-backward substitution method".

[0078] (2) Based on the equipment ledger of the power supply department (the ledger includes the model, cross-section, and length of each conductor segment. Typical parameters include the line resistance and reactance corresponding to different models and cross-sections) and typical equipment parameters, the heat generation power after the current flows through the conductor segment (overhead line, cable) can be calculated, that is, the active power loss of each conductor segment. ;

[0079] (3) Add up the active power losses of all conductor segments on the line at a certain sampling time to obtain the active power loss of the line at that time. ;

[0080] (4) Assuming that the active power loss of the line remains constant between sampling times, an approximate curve of the active power loss of the line can be plotted. This curve is integral over the statistical period. This refers to the electrical power loss of the conductor during the statistical period.

[0081] The calculation method for power loss in public distribution transformer technology is as follows:

[0082] (1) Obtain the active power of each public distribution transformer at each sampling time. and reactive power Calculate the load rate for each public distribution transformer at each sampling time. The formula is as follows: .

[0083] (2) Equipment ledger of power supply department (the ledger includes the model and capacity of each public distribution transformer. Typical parameters refer to the no-load loss and full-load loss of a certain model and capacity distribution transformer), obtain the model of public distribution transformer, find the typical no-load loss and full-load loss of the model, and calculate the active power loss of each public distribution transformer at each sampling time.

[0084] (3) The active power loss of all public distribution transformers at each sampling time is summed to obtain the total loss of public distribution transformers on the line at that time; the total loss is integrated over the statistical period to obtain the technical power loss of public distribution transformers on the line in the current statistical period.

[0085] In some embodiments, acquiring loss data for each automated segment on a line with abnormal line loss, determining whether the line loss status of each automated segment is abnormal based on the loss data, and filtering out automated segments with abnormal line loss status as managed line loss abnormal sections, includes: acquiring loss data for each automated segment on a line with abnormal line loss; wherein, the loss data includes statistical power loss and technical power loss for each automated segment in the current statistical period; for each automated segment, acquiring a second difference between the statistical power loss and technical power loss of the automated segment, and determining whether the proportion of the second difference to the active power flowing into the automated segment is greater than a preset second proportion threshold; if it is determined that the proportion of the second difference to the active power flowing into the automated segment is greater than the preset second proportion threshold, then the line loss status of the automated segment is determined to be abnormal, and the automated segment with abnormal line loss status is determined to be a managed line loss abnormal section.

[0086] In order to obtain the statistical power loss of each automated segment on the line with abnormal line loss, this method further includes: obtaining the active power of the automated segment at each sampling time in the current statistical period, and integrating the active power at each sampling time in the current statistical period to obtain the active power flowing into the automated segment; obtaining the sum of the net positive active power of all distribution transformers in the automated segment in the current statistical period, and calculating the difference between the flowing active power and the sum of the net positive active power of all distribution transformers to obtain the statistical power loss of the automated segment.

[0087] By determining the active power values ​​of all boundary switches (relative to the reference direction) at a specific sampling moment in the automated segment, key operational information of the distribution network can be systematically obtained. Since the absolute values ​​of these active powers can be directly obtained through real-time measurement sampling, the core and challenge of the entire identification process lies in accurately determining their positive or negative sign, i.e., the actual direction of power flow. To achieve this goal efficiently and reliably, a calculation method is adopted that starts from the last segment of the distribution system (excluding tie switch segments containing only one boundary switch) and proceeds segment by segment towards the power source side (i.e., the substation busbar side). This method sequentially determines the power direction of the boundary switches in each segment, thereby gradually constructing the active power sign identification result for the entire network. This recursive strategy is not only logically clear and computationally efficient, but also effectively reduces error propagation, improves the overall accuracy of the judgment, and provides a reliable data foundation for subsequent distribution automation analysis and control.

[0088] Determine the boundary switch power symbol at a certain moment for the final automated segment. In this application, as... Figure 3 As shown, first determine the sign of the sampling power of the boundary switch F4 at the very end of the segment. According to power conservation, we have:

[0089] (2)

[0090] in, This is the sum of the active power collected from all distribution transformers within the segment. This represents the active power loss of this segment.

[0091] As mentioned earlier, since the sampling times for the power of automated switches and the power of distribution transformers may not be consistent, there are two scenarios: if the automated switches and distribution transformers are sampled simultaneously at a certain moment, then the sampling sign of the power of the automated switches will be different from that of the distribution transformers. Consistent; if the distribution transformer is not sampled when the automatic switch samples at a certain moment, assuming that the automatic switch sampling time is between the distribution transformer sampling times t1 and t2, according to the above formula (2), we have:

[0092] (3)

[0093] in, That is, the net positive active power during the distribution transformer period, calculated according to formula (1). Assume... The sign remains unchanged during this period, and can be determined using the right side of the equation. After determining the power sign, combine it with the measured absolute value of the active power. This determines the active power of F4. .

[0094] Determine the sign of the boundary switch power at a certain moment in a non-end-of-line automation segment. Taking the automation segment between F1 and F2 as an example, according to power conservation, we have:

[0095]

[0096] in, It is the sum of the active power sampled from all distribution transformers within that segment. This represents the active power loss of this segment. To determine... The symbol must be determined first. The symbols. In the F2-F3-F4 segment, we have:

[0097]

[0098] Known Based on whether the sampling time of the automatic switch is the same as the sampling time of the distribution transformer, a similar method as described above is used to determine the sampling time sequentially. , The symbol is used to determine the actual value of its active power.

[0099] To accurately obtain the total active power flowing into the automated segment within the current statistical period, it is necessary to perform integration calculations on the active power data recorded at each sampling time point of the segment. Specifically, this process involves discretely sampling the power values ​​over a continuous time period and accumulating them using numerical integration methods (such as the trapezoidal or rectangular method) within the start and end time range of the current statistical period to obtain the total accumulated active power during that time period.

[0100] Assuming that the active power remains constant under the boundary switching state between adjacent sampling times, the integral value over the entire statistical period can be approximately estimated by using the active power values ​​collected at these discrete time points, thus achieving effective assessment and measurement of active power. For example, in the F2-F3-F4 segment, the inflow of active power is... .

[0101] In order to obtain the sum of the net positive active power of all distribution transformers in the current statistical period for automated segmentation. The statistical loss of electricity in the automated segment is determined by the sum of the net positive active power of each distribution transformer within the current statistical period. The difference between the inflow active power and the sum of the net positive active power of all distribution transformers is calculated to obtain the statistical loss of electricity in the automated segment.

[0102] In some embodiments, the method further includes: obtaining the active power loss of each conductor segment in the current statistical period of the automated segmentation, and adding the active power losses of each conductor segment to obtain the technical power loss of the automated segmentation in the current statistical period.

[0103] By accumulating the active power losses of each conductor segment in the automated segment within the current statistical period, the total technical power loss of the automated segment in the current statistical period can be accurately calculated. This process effectively reflects the actual energy loss during power transmission, thus providing reliable data support for subsequent energy efficiency analysis and optimization. The difference between the technical power loss and the statistical power loss is the management power loss of the automated segment in the current statistical period; combined with 2026...

[0104] Based on the same inventive concept, this application also provides a management line loss location system for implementing the above-mentioned method for locating management line losses in distribution line automation equipment.

[0105] The solution provided by this system is similar to the solution described in the above method. Therefore, the specific limitations of the management line loss location system embodiment of one or more power distribution line automation equipment provided below can be found in the limitations of the management line loss location method of power distribution line automation equipment above, and will not be repeated here.

[0106] like Figure 4 As shown in the figure, this application provides a management line loss location system for power distribution line automation equipment, including:

[0107] The line loss acquisition module 100 is used to acquire the statistical power loss and technical power loss of each segment of the power distribution line in the current statistical period.

[0108] The judgment module 200 is used to obtain the first difference between the statistical power loss and the technical power loss of the line, and to determine whether the proportion of the first difference to the total power supply of the line exceeds a preset first proportion threshold.

[0109] The line anomaly identification module 300 is used to identify a line as a line with abnormal management line loss if the proportion of the first difference to the total power supply of the line exceeds a preset first proportion threshold.

[0110] The line loss section location module 400 is used to acquire loss data of each automated segment on the line with abnormal line loss, determine whether the line loss status of each automated segment is abnormal based on the loss data, and filter out the automated segments with abnormal line loss status as the line loss abnormal section.

[0111] In some embodiments, the system further includes: a statistical loss determination module, used for:

[0112] Obtain the net positive active power of the substation gate and the sum of the net positive active power of all distribution transformers within the current statistical period. Based on the difference between the net positive active power of the substation gate and the sum of the net positive active power of all distribution transformers, determine the statistical loss of the line within the current statistical period.

[0113] In some embodiments, the system further includes: a technology loss determination module, configured to:

[0114] The active power loss of each conductor segment on the line is obtained, and the active power loss of each conductor segment is accumulated according to the sampling time to obtain the total conductor loss of the line at each time. The total conductor loss of the line at each time is integrated over time within the current statistical period to obtain the conductor technical power loss of the line within the current statistical period.

[0115] Obtain the load rate of each public distribution transformer corresponding to the line at each sampling time. Combine the typical no-load loss and full-load loss parameters in the equipment ledger to calculate the active power loss of each public distribution transformer at each time. Add up and integrate the active power loss of all public distribution transformers in the current statistical period to obtain the technical power loss of the public distribution transformers in the current statistical period.

[0116] The technical loss of the line in the current statistical period is determined by the sum of the technical loss of the conductor and the technical loss of the public distribution transformer.

[0117] In some embodiments, the line loss section location module 400 is used for:

[0118] Acquire loss data for each automated segment on the line with abnormal line loss; the loss data includes the statistical power loss and technical power loss of each automated segment in the current statistical period.

[0119] For each automated segment, obtain the second difference between the statistical power loss and the technical power loss of the automated segment, and determine whether the proportion of the second difference to the active power flowing into the automated segment is greater than the preset second proportion threshold.

[0120] If the proportion of the second difference to the active power flowing into the automated segment is greater than the preset second proportion threshold, then the line loss status of the automated segment is determined to be abnormal, and the automated segment with abnormal line loss status is identified as the managed line loss abnormal segment.

[0121] In some embodiments, the system further includes: a statistical loss calculation module, used for:

[0122] The active power of the automated segment at each sampling time within the current statistical period is obtained, and the active power at each sampling time is integrated over the current statistical period to obtain the active power flowing into the automated segment.

[0123] The sum of the net positive active power of all distribution transformers in the current statistical period is obtained for the automated segmentation. The difference between the inflow active power and the sum of the net positive active power of all distribution transformers is calculated to obtain the statistical power loss of the automated segmentation.

[0124] In some embodiments, the system further includes: a technology loss calculation module, used for:

[0125] The active power loss of each conductor segment in the current statistical period is obtained, and the active power loss of each conductor segment is added together to obtain the technical power loss of the automated segment in the current statistical period.

[0126] It should be noted that, in this embodiment of the application, the difference between the statistical power loss and the technical power loss of each line in the current statistical period is used to determine whether the ratio of the difference to the total power supply of the line exceeds a preset first ratio threshold to determine whether there is an abnormality in the line loss. If the line is determined to be a line with abnormal line loss, the scope of investigation of line loss is shortened to the automated segment. The loss data of each automated segment on the line with abnormal line loss is used to determine whether the line loss status of the automated segment is abnormal, and the automated segment with abnormal line loss status is selected as the line loss abnormal section, thereby improving the accuracy and efficiency of line loss location and realizing accurate identification of anomalies from the line level to the segment level.

[0127] like Figure 5 As shown, this application embodiment provides an electronic device. The electronic device 10 includes a memory 20 and a processor 30. The memory 20 stores a computer program. When the computer program is executed by the processor 30, the processor 30 performs the following steps:

[0128] For each segment of the power distribution line, obtain the statistical power loss and technical power loss of the line in the current statistical period.

[0129] Obtain the first difference between the statistical power loss and the technical power loss of the line, and determine whether the proportion of the first difference to the total power supply of the line exceeds a preset first proportion threshold.

[0130] If the proportion of the first difference to the total power supply of the line exceeds the preset first proportion threshold, the line is identified as a line with abnormal line loss.

[0131] Obtain the loss data of each automated segment on the line with abnormal line loss, determine whether the line loss status of each automated segment is abnormal based on the loss data, and filter out the automated segments with abnormal line loss status as the line loss abnormal management segments.

[0132] In some embodiments, processor 30 performs:

[0133] Obtain the net positive active power at the substation gate of the line in the current statistical period, and the sum of the net positive active power of all distribution transformers. Based on the difference between the net positive active power at the substation gate and the sum of the net positive active power of all distribution transformers, determine the statistical loss power of the line in the current statistical period.

[0134] In some embodiments, processor 30 performs:

[0135] The active power loss of each conductor segment on the line is obtained, and the active power loss of each conductor segment is accumulated according to the sampling time to obtain the total conductor loss of the line at each time. The total conductor loss of the line at each time is integrated over time within the current statistical period to obtain the conductor technical power loss of the line within the current statistical period.

[0136] The load rate of each public distribution transformer corresponding to the line at each sampling time is obtained. Combined with the typical no-load loss and full-load loss parameters in the equipment ledger, the active power loss of each public distribution transformer at each time is calculated. The active power loss of all public distribution transformers in the current statistical period is accumulated and integrated to obtain the technical power loss of the public distribution transformers in the current statistical period of the line.

[0137] The technical power loss of the line in the current statistical period is determined based on the sum of the technical power loss of the conductor and the technical power loss of the public distribution transformer.

[0138] In some embodiments, the step of acquiring loss data for each automated segment on the line with abnormal line loss, determining whether the line loss status of each automated segment is abnormal based on the loss data, and filtering out automated segments with abnormal line loss status as managed line loss abnormal segments includes:

[0139] Obtain loss data for each automated segment on the line with abnormal line loss; wherein, the loss data includes the statistical power loss and technical power loss of each automated segment in the current statistical period;

[0140] For each of the automated segments, a second difference between the statistical power loss and the technical power loss of the automated segment is obtained, and it is determined whether the proportion of the second difference to the active power flowing into the automated segment is greater than a preset second proportion threshold.

[0141] If the proportion of the second difference to the active power flowing into the automated segment is greater than the preset second proportion threshold, then the line loss status of the automated segment is determined to be abnormal, and the automated segment with abnormal line loss status is determined to be the managed line loss abnormal segment.

[0142] In some embodiments, processor 30 performs:

[0143] The active power of the automated segment at each sampling time within the current statistical period is obtained, and the active power at each sampling time is integrated within the current statistical period to obtain the active power flowing into the automated segment.

[0144] The sum of the net positive active power of all distribution transformers in the current statistical period is obtained for the automated segment. The difference between the inflow active power and the sum of the net positive active power of all distribution transformers is calculated to obtain the statistical power loss of the automated segment.

[0145] In some embodiments, processor 30 performs:

[0146] The active power loss of each conductor segment in the current statistical period is obtained, and the active power loss of each conductor segment is added together to obtain the technical power loss of the automated segment in the current statistical period.

[0147] It should be noted that, in this embodiment of the application, the difference between the statistical power loss and the technical power loss of each line in the current statistical period is used to determine whether the ratio of the difference to the total power supply of the line exceeds a preset first ratio threshold to determine whether there is an abnormality in the line loss. If the line is determined to be a line with abnormal line loss, the scope of investigation of line loss is shortened to the automated segment. The loss data of each automated segment on the line with abnormal line loss is used to determine whether the line loss status of the automated segment is abnormal, and the automated segment with abnormal line loss status is selected as the line loss abnormal section, thereby improving the accuracy and efficiency of line loss location and realizing accurate identification of anomalies from the line level to the segment level.

[0148] This application provides a computer-readable storage medium storing a computer program thereon. When the computer program is executed, it implements the steps of the management line loss location method for power distribution line automation equipment as described in the above embodiments, specifically including:

[0149] For each segment of the power distribution line, obtain the statistical power loss and technical power loss of the line in the current statistical period.

[0150] Obtain the first difference between the statistical power loss and the technical power loss of the line, and determine whether the proportion of the first difference to the total power supply of the line exceeds a preset first proportion threshold.

[0151] If the proportion of the first difference to the total power supply of the line exceeds the preset first proportion threshold, the line is identified as a line with abnormal line loss.

[0152] Obtain the loss data of each automated segment on the line with abnormal line loss, determine whether the line loss status of each automated segment is abnormal based on the loss data, and filter out the automated segments with abnormal line loss status as the line loss abnormal management segments.

[0153] In some embodiments, the method for locating line losses in power distribution line automation equipment further includes:

[0154] Obtain the net positive active power at the substation gate of the line in the current statistical period, and the sum of the net positive active power of all distribution transformers. Based on the difference between the net positive active power at the substation gate and the sum of the net positive active power of all distribution transformers, determine the statistical loss power of the line in the current statistical period.

[0155] In some embodiments, the method for locating line losses in power distribution line automation equipment further includes:

[0156] The active power loss of each conductor segment on the line is obtained, and the active power loss of each conductor segment is accumulated according to the sampling time to obtain the total conductor loss of the line at each time. The total conductor loss of the line at each time is integrated over time within the current statistical period to obtain the conductor technical power loss of the line within the current statistical period.

[0157] The load rate of each public distribution transformer corresponding to the line at each sampling time is obtained. Combined with the typical no-load loss and full-load loss parameters in the equipment ledger, the active power loss of each public distribution transformer at each time is calculated. The active power loss of all public distribution transformers in the current statistical period is accumulated and integrated to obtain the technical power loss of the public distribution transformers in the current statistical period of the line.

[0158] The technical power loss of the line in the current statistical period is determined based on the sum of the technical power loss of the conductor and the technical power loss of the public distribution transformer.

[0159] In some embodiments, the step of acquiring loss data for each automated segment on the line with abnormal line loss, determining whether the line loss status of each automated segment is abnormal based on the loss data, and filtering out automated segments with abnormal line loss status as managed line loss abnormal segments includes:

[0160] Obtain loss data for each automated segment on the line with abnormal line loss; wherein, the loss data includes the statistical power loss and technical power loss of each automated segment in the current statistical period;

[0161] For each of the automated segments, a second difference between the statistical power loss and the technical power loss of the automated segment is obtained, and it is determined whether the proportion of the second difference to the active power flowing into the automated segment is greater than a preset second proportion threshold.

[0162] If the proportion of the second difference to the active power flowing into the automated segment is greater than the preset second proportion threshold, then the line loss status of the automated segment is determined to be abnormal, and the automated segment with abnormal line loss status is determined to be the managed line loss abnormal segment.

[0163] In some embodiments, the method for locating line losses in power distribution line automation equipment further includes:

[0164] The active power of the automated segment at each sampling time within the current statistical period is obtained, and the active power at each sampling time is integrated within the current statistical period to obtain the active power flowing into the automated segment.

[0165] The sum of the net positive active power of all distribution transformers in the current statistical period is obtained for the automated segment. The difference between the inflow active power and the sum of the net positive active power of all distribution transformers is calculated to obtain the statistical power loss of the automated segment.

[0166] In some embodiments, the method for locating line losses in power distribution line automation equipment further includes:

[0167] The active power loss of each conductor segment in the current statistical period is obtained, and the active power loss of each conductor segment is added together to obtain the technical power loss of the automated segment in the current statistical period.

[0168] It should be noted that, in this embodiment of the application, the difference between the statistical power loss and the technical power loss of each line in the current statistical period is used to determine whether the ratio of the difference to the total power supply of the line exceeds a preset first ratio threshold to determine whether there is an abnormality in the line loss. If the line is determined to be a line with abnormal line loss, the scope of investigation of line loss is shortened to the automated segment. The loss data of each automated segment on the line with abnormal line loss is used to determine whether the line loss status of the automated segment is abnormal, and the automated segment with abnormal line loss status is selected as the line loss abnormal section, thereby improving the accuracy and efficiency of line loss location and realizing accurate identification of anomalies from the line level to the segment level.

[0169] This application provides a computer program product, which includes a computer program stored on a non-transitory computer-readable storage medium. The computer program includes program instructions, wherein when the program instructions are executed by a computer, the computer performs the following steps:

[0170] For each segment of the power distribution line, obtain the statistical power loss and technical power loss of the line in the current statistical period.

[0171] Obtain the first difference between the statistical power loss and the technical power loss of the line, and determine whether the proportion of the first difference to the total power supply of the line exceeds a preset first proportion threshold.

[0172] If the proportion of the first difference to the total power supply of the line exceeds the preset first proportion threshold, the line is identified as a line with abnormal line loss.

[0173] Obtain the loss data of each automated segment on the line with abnormal line loss, determine whether the line loss status of each automated segment is abnormal based on the loss data, and filter out the automated segments with abnormal line loss status as the line loss abnormal management segments.

[0174] In some embodiments, the computer performs:

[0175] Obtain the net positive active power at the substation gate of the line in the current statistical period, and the sum of the net positive active power of all distribution transformers. Based on the difference between the net positive active power at the substation gate and the sum of the net positive active power of all distribution transformers, determine the statistical loss power of the line in the current statistical period.

[0176] In some embodiments, the computer performs:

[0177] The active power loss of each conductor segment on the line is obtained, and the active power loss of each conductor segment is accumulated according to the sampling time to obtain the total conductor loss of the line at each time. The total conductor loss of the line at each time is integrated over time within the current statistical period to obtain the conductor technical power loss of the line within the current statistical period.

[0178] The load rate of each public distribution transformer corresponding to the line at each sampling time is obtained. Combined with the typical no-load loss and full-load loss parameters in the equipment ledger, the active power loss of each public distribution transformer at each time is calculated. The active power loss of all public distribution transformers in the current statistical period is accumulated and integrated to obtain the technical power loss of the public distribution transformers in the current statistical period of the line.

[0179] The technical power loss of the line in the current statistical period is determined based on the sum of the technical power loss of the conductor and the technical power loss of the public distribution transformer.

[0180] In some embodiments, the step of acquiring loss data for each automated segment on the line with abnormal line loss, determining whether the line loss status of each automated segment is abnormal based on the loss data, and filtering out automated segments with abnormal line loss status as managed line loss abnormal segments includes:

[0181] Obtain loss data for each automated segment on the line with abnormal line loss; wherein, the loss data includes the statistical power loss and technical power loss of each automated segment in the current statistical period;

[0182] For each of the automated segments, a second difference between the statistical power loss and the technical power loss of the automated segment is obtained, and it is determined whether the proportion of the second difference to the active power flowing into the automated segment is greater than a preset second proportion threshold.

[0183] If the proportion of the second difference to the active power flowing into the automated segment is greater than the preset second proportion threshold, then the line loss status of the automated segment is determined to be abnormal, and the automated segment with abnormal line loss status is determined to be the managed line loss abnormal segment.

[0184] In some embodiments, the computer performs:

[0185] The active power of the automated segment at each sampling time within the current statistical period is obtained, and the active power at each sampling time is integrated within the current statistical period to obtain the active power flowing into the automated segment.

[0186] The sum of the net positive active power of all distribution transformers in the current statistical period is obtained for the automated segment. The difference between the inflow active power and the sum of the net positive active power of all distribution transformers is calculated to obtain the statistical power loss of the automated segment.

[0187] In some embodiments, the computer performs:

[0188] The active power loss of each conductor segment in the current statistical period is obtained, and the active power loss of each conductor segment is added together to obtain the technical power loss of the automated segment in the current statistical period.

[0189] It should be noted that, in this embodiment of the application, the difference between the statistical power loss and the technical power loss of each line in the current statistical period is used to determine whether the ratio of the difference to the total power supply of the line exceeds a preset first ratio threshold to determine whether there is an abnormality in the line loss. If the line is determined to be a line with abnormal line loss, the scope of investigation of line loss is shortened to the automated segment. The loss data of each automated segment on the line with abnormal line loss is used to determine whether the line loss status of the automated segment is abnormal, and the automated segment with abnormal line loss status is selected as the line loss abnormal section, thereby improving the accuracy and efficiency of line loss location and realizing accurate identification of anomalies from the line level to the segment level.

[0190] Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working processes of the systems, electronic devices, computer storage media, and computer program products described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0191] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this invention are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of the invention described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover a non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0192] It should be understood that although the steps in the flowcharts of the embodiments described above are shown sequentially according to the arrows, these steps are not necessarily executed in the order indicated by the arrows. Unless explicitly stated herein, there is no strict order restriction on the execution of these steps, and they can be executed in other orders. Moreover, at least some steps in the flowcharts of the embodiments described above may include multiple steps or multiple stages. These steps or stages are not necessarily completed at the same time, but can be executed at different times. The execution order of these steps or stages is not necessarily sequential, but can be performed alternately or in turn with other steps or at least some of the steps or stages of other steps.

[0193] In the several embodiments provided by this invention, it should be understood that the disclosed systems, electronic devices, computer storage media, computer program products, and methods can be implemented in other ways. For example, the device embodiments described above are merely illustrative; for instance, the division of units is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the coupling or direct coupling or communication connection shown or discussed may be through some interfaces, indirect coupling or communication connection between devices or units, and may be electrical, mechanical, or other forms.

[0194] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of this embodiment according to actual needs.

[0195] Furthermore, the functional units in the various embodiments of the present invention can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit. The integrated unit can be implemented in hardware or as a software functional unit.

[0196] If the integrated unit is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of the present invention, in essence, or the part that contributes to the prior art, or all or part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions for executing all or part of the steps of the methods described in the various embodiments of the present invention through a computer device (which may be a personal computer, a server, or a network device, etc.). The aforementioned storage medium includes: USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, optical disks, and other media capable of storing program code.

[0197] The above embodiments are only used to illustrate the technical solutions of the present invention, and are not intended to limit it. Although the present invention has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features. Such modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. A method for locating line losses in power distribution line automation equipment, characterized in that, include: For each segment of the power distribution line, obtain the statistical power loss and technical power loss of the line in the current statistical period. Obtain the first difference between the statistical power loss and the technical power loss of the line, and determine whether the proportion of the first difference to the total power supply of the line exceeds a preset first proportion threshold. If the proportion of the first difference to the total power supply of the line exceeds the preset first proportion threshold, the line is identified as a line with abnormal line loss. Obtain the loss data of each automated segment on the line with abnormal line loss, determine whether the line loss status of each automated segment is abnormal based on the loss data, and filter out the automated segments with abnormal line loss status as the line loss abnormal management segments.

2. The method for locating line losses in power distribution line automation equipment according to claim 1, characterized in that, Also includes: Obtain the net positive active power at the substation gate of the line in the current statistical period, and the sum of the net positive active power of all distribution transformers. Based on the difference between the net positive active power at the substation gate and the sum of the net positive active power of all distribution transformers, determine the statistical loss power of the line in the current statistical period.

3. The method for locating line losses in power distribution line automation equipment according to claim 1, characterized in that, Also includes: The active power loss of each conductor segment on the line is obtained, and the active power loss of each conductor segment is accumulated according to the sampling time to obtain the total conductor loss of the line at each time. The total conductor loss of the line at each time is integrated over time within the current statistical period to obtain the conductor technical power loss of the line within the current statistical period. The load rate of each public distribution transformer corresponding to the line at each sampling time is obtained. Combined with the typical no-load loss and full-load loss parameters in the equipment ledger, the active power loss of each public distribution transformer at each time is calculated. The active power loss of all public distribution transformers in the current statistical period is accumulated and integrated to obtain the technical power loss of the public distribution transformers in the current statistical period of the line. The technical power loss of the line in the current statistical period is determined based on the sum of the technical power loss of the conductor and the technical power loss of the public distribution transformer.

4. The method for locating line losses in power distribution line automation equipment according to claim 1, characterized in that, The process of acquiring loss data for each automated segment on the line with abnormal line loss, determining whether the line loss status of each automated segment is abnormal based on the loss data, and filtering out automated segments with abnormal line loss status as managed line loss abnormal segments includes: Obtain loss data for each automated segment on the line with abnormal line loss; wherein, the loss data includes the statistical power loss and technical power loss of each automated segment in the current statistical period; For each of the automated segments, a second difference between the statistical power loss and the technical power loss of the automated segment is obtained, and it is determined whether the proportion of the second difference to the active power flowing into the automated segment is greater than a preset second proportion threshold. If the proportion of the second difference to the active power flowing into the automated segment is greater than the preset second proportion threshold, then the line loss status of the automated segment is determined to be abnormal, and the automated segment with abnormal line loss status is determined to be the managed line loss abnormal segment.

5. The method for locating line losses in power distribution line automation equipment according to claim 4, characterized in that, Also includes: The active power of the automated segment at each sampling time within the current statistical period is obtained, and the active power at each sampling time is integrated within the current statistical period to obtain the active power flowing into the automated segment. The sum of the net positive active power of all distribution transformers in the current statistical period is obtained for the automated segment. The difference between the inflow active power and the sum of the net positive active power of all distribution transformers is calculated to obtain the statistical power loss of the automated segment.

6. The method for locating line losses in power distribution line automation equipment according to claim 4, characterized in that, Also includes: The active power loss of each conductor segment in the current statistical period is obtained, and the active power loss of each conductor segment is added together to obtain the technical power loss of the automated segment in the current statistical period.

7. A line loss location system for automated power distribution line equipment, characterized in that, include: The line loss acquisition module is used to acquire the statistical power loss and technical power loss of each segment of the power distribution line in the current statistical period. The judgment module is used to obtain a first difference between the statistical power loss and the technical power loss of the line, and to determine whether the proportion of the first difference to the total power supply of the line exceeds a preset first proportion threshold. The line anomaly identification module is used to identify the line as a line with abnormal management line loss when the proportion of the first difference to the total power supply of the line exceeds the preset first proportion threshold. The line loss section location module is used to acquire the loss data of each automated segment on the line with abnormal line loss, determine whether the line loss status of each automated segment is abnormal based on the loss data, and filter out the automated segments with abnormal line loss status as the line loss abnormal section.

8. An electronic device, characterized in that, The electronic device includes a memory and a processor. The memory stores a computer program. When the computer program is executed by the processor, the processor performs the steps of the management line loss location method for power distribution line automation equipment as described in any one of claims 1-6.

9. A computer-readable storage medium having a computer program stored thereon, characterized in that, When the computer program is executed, it implements the steps of the management line loss location method for power distribution line automation equipment as described in any one of claims 1-6.

10. A computer program product, characterized in that, The computer program product includes a computer program stored on a non-transitory computer-readable storage medium, the computer program including program instructions, wherein when the program instructions are executed by a computer, the computer performs the steps of the management line loss location method for power distribution line automation equipment as described in any one of claims 1-6.

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