A remote detection method, device, and terminal equipment for metering devices

Abstract

This invention discloses a remote detection method, device, and terminal equipment for metering devices. The method includes: acquiring historical row-level electricity consumption data; determining whether all historical row-level electricity consumption data are zero; if so, determining the detection result as no load; otherwise, acquiring the total active power meter data of the substation, the total active power meter data of the substation, the energy consumption data of the substation main meter, the energy consumption data of the substation auxiliary meter, the built-in clock data of the substation energy meter, the zero-point meter code data of the substation, the frozen meter code data of the substation, the total meter code energy consumption data of the substation, and the energy consumption data of each substation sub-meter code; performing loop detection, main and auxiliary meter electricity consumption comparison detection, clock detection, frozen time detection, and total and time-of-use meter code comparison detection; if all results are normal, determining the detection result as normal; otherwise, determining it as abnormal. This invention achieves automated data collection, improves data reliability, reduces human error, and improves inspection efficiency.

Description

Technical Field

[0001] This invention relates to the field of electrical energy metering and testing technology, and in particular to a remote testing method, device, and terminal equipment for metering devices. Background Technology

[0002] Traditional metering device testing typically requires on-site personnel visits, which is infrequent and time-consuming, hindering the timely detection and resolution of metering inaccuracies. The later a metering inaccuracy is discovered, the greater the associated costs and the more complex the resolution process becomes. Furthermore, traditional metering device testing methods are inefficient and cannot detect metering inaccuracies promptly. Summary of the Invention

[0003] This invention provides a remote detection method, device, and terminal equipment for metering devices to solve the technical problems of low detection efficiency and high error rate in existing technologies.

[0004] To address the aforementioned technical problems, embodiments of the present invention provide a remote detection method for a metering device, comprising:

[0005] When the metering device to be tested is a plant metering device, the historical electricity consumption data of the plant metering device within a first preset time period is obtained.

[0006] Determine whether all the historical row electricity consumption data are zero. If so, determine that the detection result of the plant metering device is no load. If not, acquire the plant metering device's forward active total meter code data, reverse active total meter code data, plant main meter energy consumption data, plant auxiliary meter energy consumption data, plant energy meter built-in clock data, plant zero-point meter code data, plant frozen meter code data, plant total meter code energy consumption data, and energy consumption data of each plant sub-meter code.

[0007] Based on the forward active power total meter data and the reverse active power total meter data of the power plant, determine the power plant circuit detection result; based on the power consumption data of the main meter and the power consumption data of the auxiliary meter, determine the main and auxiliary meter power consumption comparison detection result; based on the built-in clock data of the power meter, determine the power plant clock detection result; based on the zero-point meter data and the frozen meter data of the power plant, determine the power plant freeze time detection result; based on the total meter energy consumption data and the energy consumption data of each sub-meter, determine the total time-of-use meter comparison detection result.

[0008] If the detection results of the plant circuit, the comparison detection results of the main and auxiliary meter power consumption, the detection results of the plant clock, the detection results of the plant freeze time, and the comparison detection results of the plant total time-of-use meter code are all normal, the detection results of the plant metering device are determined to be normal; otherwise, the detection results of the plant metering device are determined to be abnormal.

[0009] As a preferred embodiment, before acquiring the first historical line-hour electricity data of the plant metering device within the first preset time period, the method further includes:

[0010] Obtain the operating status of the plant;

[0011] Determine whether the plant is in a shutdown state; if so, the metering device detects that the plant is in a shutdown state and stops detecting; if not, continue detecting.

[0012] The step of determining the substation circuit detection result based on the substation's forward active power total meter data and the substation's reverse active power total meter data includes:

[0013] Based on the forward active power meter data and the reverse active power meter data of the substation, determine whether the 10kV outgoing lines, 10kV station service transformers, 10kV connecting transformers, and 10kV arc suppression devices in the substation are all operating with reverse active power; if so, the substation circuit detection result is determined to be abnormal; if not, then...

[0014] Determine whether the 10kV capacitor bank and 35kV reactor in the substation are both operating in the forward reactive power direction, or both operating in the reverse active power direction, or both operating in the forward active power direction; if so, the substation circuit detection result is determined to be abnormal; if not, then...

[0015] Determine whether both the 10kV main transformer and the 35kV transformer in the substation are operating in the positive active direction; if so, the substation circuit detection results are abnormal; if not, then...

[0016] Determine whether the 500kV, 220kV, 110kV, and 35kV main transformer high-voltage lines in the substation are all operating in reverse active power; if yes, then the substation circuit detection result is determined to be abnormal; if not, then...

[0017] Determine whether the 500kV main transformer intermediate frequency, 220kV main transformer intermediate frequency, and 110kV main transformer intermediate frequency in the substation are all generating positive active power. If yes, then the substation circuit detection result is determined to be abnormal; otherwise,

[0018] Determine whether the 500kV, 220kV, 110kV, 35kV, and 10kV main transformers in the substation are all operating in the positive direction with active power; if yes, then the substation circuit test result is determined to be abnormal; if no, then the substation circuit test result is determined to be normal.

[0019] The step of determining the main and auxiliary meter power consumption comparison test results based on the power consumption data of the main meter and the auxiliary meter of the plant includes:

[0020] Calculate the first main-to-sub-meter energy consumption difference between the main meter energy consumption data and the sub-meter energy consumption data of the plant;

[0021] Determine whether the difference in energy consumption between the first main and secondary meters exceeds a preset first difference value; if yes, determine that the energy consumption comparison detection result of the main and secondary meters is abnormal; if no, determine that the energy consumption comparison detection result of the main and secondary meters is normal.

[0022] The step of determining the plant clock detection result based on the built-in clock data of the plant's power meter includes:

[0023] Determine whether the built-in clock data of the power meter in the plant is inconsistent with the actual time; if yes, determine that the clock detection result of the plant is abnormal; if no, determine that the clock detection result of the plant is normal.

[0024] The step of determining the plant freezing time detection result based on the plant zero-point meter code data and the plant freezing meter code data includes:

[0025] Determine whether the zero-point meter code data and the freeze meter code data of the plant are not equal; if so, determine that the freeze time detection result of the plant is abnormal; if not, determine that the freeze time detection result of the plant is normal.

[0026] The step of determining the comparison and detection result of the total time-of-use meter codes of the plant based on the total energy consumption data of the plant and the energy consumption data of each of the plant's sub-meter codes includes:

[0027] Determine whether the total energy consumption data of the plant / station is not equal to the sum of the energy consumption data of each sub-meter of the plant / station; if so, determine that the comparison and detection result of the total time-of-use meter of the plant / station is abnormal; if not, determine that the comparison and detection result of the total time-of-use meter of the plant / station is normal.

[0028] Wherein, "reverse active energy flow" means that the direction of reactive energy flow is the direction of inflow into the bus; "forward reactive energy flow" means that the direction of reactive energy flow is the direction of outflow from the bus; "reverse active energy flow" means that the direction of active energy flow is the direction of inflow into the bus; and "forward active energy flow" means that the direction of active energy flow is the direction of outflow from the bus.

[0029] As a preferred embodiment, the remote detection method for the metering device further includes:

[0030] The metering device to be tested is a dedicated transformer metering device, which acquires the user's operating status.

[0031] Determine whether the user's operating status is out of service; if yes, the detection result of the dedicated transformer metering device is out of service, and the detection is stopped; if no, obtain the dedicated transformer three-phase current of the dedicated transformer metering device.

[0032] Determine whether all three-phase currents of the transformer are less than a preset first current threshold. If yes, the detection result of the transformer metering device is no load. If no, acquire the transformer data items corresponding to the second largest current value data of the transformer A phase voltage, transformer B phase voltage, transformer C phase voltage, transformer A phase current, transformer B phase current, transformer C phase current, transformer second largest current value data within a second preset time period, transformer built-in clock data, transformer zero-point meter code data, transformer frozen meter code data, transformer total meter code energy consumption data, and energy consumption data of each transformer sub-meter code. The transformer data items include: voltage, current, active power, reactive power, and power factor.

[0033] Based on the phase voltage of phase A, phase voltage of phase B, phase voltage of phase C, phase current of phase A, phase current of phase B, and phase current of phase C of the dedicated transformer, the detection result of the dedicated transformer circuit is determined; based on the dedicated transformer data item corresponding to the second largest current value data within the second preset time period, the detection result of the dedicated transformer load is determined; based on the built-in clock data of the dedicated transformer energy meter, the detection result of the dedicated transformer clock is determined; based on the dedicated transformer zero-point meter code data and the dedicated transformer frozen meter code data, the detection result of the dedicated transformer frozen time is determined; based on the total meter code energy consumption data of the dedicated transformer and the energy consumption data of each dedicated transformer sub-meter code, the detection result of the total time-sharing meter code comparison of the dedicated transformer is determined.

[0034] If the detection results of the dedicated transformer circuit, the dedicated transformer load, the dedicated transformer clock, the dedicated transformer freeze time, and the dedicated transformer total time-of-use meter code comparison are all normal, the detection result of the dedicated transformer metering device is determined to be normal; otherwise, the detection result of the dedicated transformer metering device is determined to be abnormal.

[0035] As a preferred embodiment, determining the transformer circuit detection result based on the phase voltage of phase A, the phase voltage of phase B, the phase voltage of phase C, the phase current of phase A, the phase current of phase B, and the phase current of phase C of the transformer includes:

[0036] Calculate the phase angle of phase A of the dedicated transformer based on the phase voltage and phase current of phase A of the dedicated transformer;

[0037] Calculate the phase angle of phase B of the dedicated transformer based on the phase voltage and phase current of phase B of the dedicated transformer;

[0038] Calculate the phase angle of the C phase of the dedicated transformer based on the phase voltage and phase current of the C phase of the dedicated transformer;

[0039] If the power system corresponding to the dedicated transformer metering device is a three-phase four-wire system, then determine whether at least one of the phase angles of the dedicated transformer A phase, the dedicated transformer B phase, and the dedicated transformer C phase is within a preset first included angle range; if yes, then determine that the detection result of the dedicated transformer circuit is abnormal; if no, then determine that the detection result of the dedicated transformer circuit is normal.

[0040] If the power system corresponding to the dedicated transformer metering device is a three-phase three-wire system, then determine whether the phase angle of phase A of the dedicated transformer is within the preset second included angle range; if yes, then determine that the detection result of the dedicated transformer circuit is abnormal; if no, then

[0041] Determine whether the phase angle of phase C of the special transformer is within the preset third included angle range; if yes, determine that the detection result of the special transformer circuit is abnormal; if no, determine that the detection result of the special transformer circuit is normal.

[0042] The step of determining the transformer load detection result based on the transformer data item corresponding to the second largest current value data within the second preset time period includes:

[0043] Based on the data items of the dedicated transformer, determine whether there is an abnormal current, voltage, or power; if so, determine that the load detection result of the dedicated transformer is abnormal; if not, determine that the load detection result of the dedicated transformer is normal.

[0044] The step of determining the transformer clock detection result based on the built-in clock data of the transformer energy meter includes:

[0045] Determine whether the built-in clock data of the dedicated transformer energy meter is inconsistent with the actual time; if yes, determine that the dedicated transformer clock detection result is abnormal; if no, determine that the dedicated transformer clock detection result is normal.

[0046] The step of determining the transformer freeze time detection result based on the transformer zero-point meter code data and the transformer freeze meter code data includes:

[0047] Determine whether the zero-point meter code data and the freeze meter code data of the special transformer are not equal; if so, determine that the freeze time detection result of the special transformer is abnormal; if not, determine that the freeze time detection result of the protected special transformer is normal.

[0048] The step of determining the comparison and detection result of the total and time-of-use meter codes of the dedicated transformer based on the total meter code energy consumption data and the energy consumption data of each of the dedicated transformer sub-meter codes includes:

[0049] Determine whether the sum of the total energy consumption data of the dedicated transformer and the sum of the energy consumption data of each of the dedicated transformer sub-meters is not equal; if yes, then determine that the comparison and detection result of the total and sub-meter codes of the dedicated transformer is abnormal; if no, then determine that the comparison and detection result of the total and sub-meter codes of the dedicated transformer is normal.

[0050] As a preferred embodiment, the remote detection method for the metering device further includes:

[0051] When the metering device to be tested is a public transformer metering device, the operating status of the transformer substation is obtained;

[0052] Determine whether the operating status of the transformer substation is out of service; if yes, the detection result of the public transformer metering device is out of service, and the detection is stopped; if no, obtain the public transformer three-phase current of the public transformer metering device.

[0053] The system determines whether all three-phase currents of the transformer are less than a preset second current threshold. If so, the transformer metering device detects no load. If not, it acquires the transformer data items corresponding to the second-largest current value data within a second preset time period, the transformer energy meter's built-in clock data, the transformer reverse active power total meter code first data, the transformer reverse active power total meter code second data, the transformer total meter code energy consumption data, and the energy consumption data of each transformer sub-meter code. The transformer data items include: voltage, current, active power, reactive power, and power factor. The transformer reverse active power total meter code first data is the data corresponding to the transformer reverse active power total meter code at a preset first time point. The transformer reverse active power total meter code second data is the data corresponding to the transformer reverse active power total meter code at a preset second time point.

[0054] Based on the phase voltage of phase A, phase voltage of phase B, phase voltage of phase C, phase current of phase A, phase current of phase B, and phase current of phase C of the transformer, the transformer circuit detection result is determined; based on the transformer data item corresponding to the second largest current value data within the second preset time period, the transformer load detection result is determined; based on the built-in clock data of the transformer energy meter, the transformer clock detection result is determined; based on the first and second data of the transformer reverse active power total meter code, the transformer freeze time detection result is determined; based on the energy consumption data of the transformer total meter code and the energy consumption data of each transformer sub-meter code, the transformer total time-of-use meter code comparison detection result is determined.

[0055] If the results of the transformer circuit detection, the transformer load detection, the transformer clock detection, the transformer freeze time detection, and the transformer total time-of-use meter code comparison are all normal, the detection result of the transformer metering device is determined to be normal; otherwise, the detection result of the transformer metering device is determined to be abnormal.

[0056] As a preferred embodiment, determining the transformer circuit detection result based on the transformer A-phase voltage, transformer B-phase voltage, transformer C-phase voltage, transformer A-phase current, transformer B-phase current, and transformer C-phase current includes:

[0057] Calculate the phase angle of phase A of the common transformer based on the phase voltage and phase current of phase A of the common transformer;

[0058] Calculate the phase angle of phase B of the common transformer based on the phase voltage and phase current of phase B of the common transformer;

[0059] Calculate the phase angle of the C phase of the common transformer based on the phase voltage and phase current of the C phase of the common transformer;

[0060] The step of determining the transformer load detection result based on the transformer data item corresponding to the second largest current value data within the second preset time period includes:

[0061] If the power system corresponding to the public transformer metering device is a three-phase four-wire system, then determine whether at least one of the public transformer phase A angle, the public transformer phase B angle, and the public transformer phase C angle is within a preset first included angle range; if yes, then determine that the public transformer circuit detection result is abnormal; if no, then determine that the public transformer circuit detection result is normal.

[0062] If the power system corresponding to the public transformer metering device is a three-phase three-wire system, then determine whether the phase angle of phase A of the public transformer is within the preset second included angle range; if yes, then determine that the detection result of the public transformer circuit is abnormal; if no, then

[0063] Determine whether the phase angle of phase C of the public transformer is within the preset third included angle range; if yes, determine that the detection result of the public transformer circuit is abnormal; if no, determine that the detection result of the public transformer circuit is normal.

[0064] The step of determining the public transformer clock detection result based on the built-in clock data of the public transformer energy meter includes:

[0065] Determine whether the built-in clock data of the public transformer energy meter is inconsistent with the actual time; if yes, determine that the public transformer clock detection result is abnormal; if no, determine that the public transformer clock detection result is normal.

[0066] The step of determining the transformer freeze time detection result based on the first data of the transformer reverse active power total meter and the second data of the transformer reverse active power total meter includes:

[0067] Calculate the reverse travel difference between the first data of the reverse active power total meter code of the public transformer and the second data of the reverse active power total meter code of the public transformer;

[0068] Determine if the reverse travel difference is not zero; if yes, then the public transformer freezing time detection result is determined to be abnormal; if no, then the public transformer freezing time detection result is determined to be normal.

[0069] The step of determining the comparison and detection result of the total time-of-use meter code of the public transformer based on the energy consumption data of the total meter code and the energy consumption data of each of the individual meter codes of the public transformer includes:

[0070] Determine whether the sum of the total energy consumption data of the public transformer and the energy consumption data of each of the public transformer sub-meters is not equal; if so, determine that the comparison and detection result of the total and sub-meter codes of the public transformer is abnormal; if not, determine that the comparison and detection result of the total and sub-meter codes of the public transformer is normal.

[0071] As a preferred embodiment, the remote detection method for the metering device further includes:

[0072] When the metering device to be tested is a low-voltage metering device, the built-in clock data of the low-voltage energy meter, the low-voltage zero-point meter code data, the low-voltage frozen meter code data, the low-voltage total meter code energy consumption data, and the energy consumption data of each low-voltage sub-meter code are acquired.

[0073] Based on the built-in clock data of the low-voltage energy meter, the low-voltage clock detection result is determined; based on the low-voltage zero-point meter code data and the low-voltage freeze meter code data, the low-voltage freeze time detection result is determined; based on the low-voltage total meter code energy consumption data and the energy consumption data of each of the low-voltage sub-meter codes, the low-voltage total time-sharing meter code comparison detection result is determined.

[0074] If the low-voltage clock detection result, the low-voltage freeze time detection result, and the low-voltage total time-of-use meter code comparison detection result are all normal, the detection result of the low-voltage metering device is determined to be normal; otherwise, the detection result of the low-voltage metering device is determined to be abnormal.

[0075] As a preferred embodiment, the low-voltage clock detection result is determined based on the built-in clock data of the low-voltage energy meter, including:

[0076] Determine whether the built-in clock data of the low-voltage energy meter is inconsistent with the actual time; if yes, determine that the low-voltage clock detection result is abnormal; if no, determine that the low-voltage clock detection result is normal.

[0077] The step of determining the low-pressure freeze time detection result based on the low-pressure zero-point meter code data and the low-pressure freeze meter code data includes:

[0078] Determine whether the low-pressure zero-point meter code data and the low-pressure freeze meter code data are unequal; if so, determine that the low-pressure freeze time detection result is abnormal; if not, determine that the low-pressure freeze time detection result is normal.

[0079] The step of determining the low-voltage total time-of-use meter code comparison and detection result based on the low-voltage total meter code energy consumption data and the energy consumption data of each of the low-voltage sub-meter codes includes:

[0080] Determine whether the sum of the energy consumption data of the total low-voltage meter code and the energy consumption data of each of the individual low-voltage meter codes is not equal; if yes, then determine that the comparison and detection result of the total low-voltage meter code is abnormal; if no, then determine that the comparison and detection result of the total low-voltage meter code is normal.

[0081] Based on the above embodiments, another embodiment of the present invention provides a remote detection device for a metering device, comprising: a data acquisition module and a detection module;

[0082] The data acquisition module acquires the historical line-time energy consumption data of the plant / station metering device within a first preset time period when the metering device to be tested is a plant / station metering device; when the historical line-time energy consumption data is not all zero, it acquires the plant / station forward active total meter code data, plant / station reverse active total meter code data, plant / station main meter energy consumption data, plant / station auxiliary meter energy consumption data, plant / station energy meter built-in clock data, plant / station zero-point meter code data, plant / station frozen meter code data, plant / station total meter code energy consumption data, and energy consumption data of each plant / station sub-meter code of the plant / station metering device.

[0083] The detection module determines whether all historical line energy consumption data are zero. If so, it determines that the detection result of the substation metering device is no load. If not, it determines the substation circuit detection result based on the substation forward active power total meter data and the substation reverse active power total meter data; it determines the main and auxiliary meter energy consumption comparison detection result based on the substation main meter energy consumption data and the substation auxiliary meter energy consumption data; it determines the substation clock detection result based on the substation energy meter's built-in clock data; and it determines the substation zero-point meter data and the... The system freezes meter readings at the plant / station and determines the plant / station freeze time detection result. Based on the total energy consumption data of the plant / station's total meter readings and the energy consumption data of each of the plant / station's sub-meter readings, the system determines the plant / station's total time-of-use meter reading comparison detection result. If the plant / station circuit detection result, the main / sub-meter energy consumption comparison detection result, the plant / station clock detection result, the plant / station freeze time detection result, and the plant / station total time-of-use meter reading comparison detection result are all normal, the detection result of the plant / station metering device is determined to be normal; otherwise, the detection result of the plant / station metering device is determined to be abnormal.

[0084] Based on the above embodiments, another embodiment of the present invention provides a terminal device, the terminal device including a processor, a memory, and a computer program stored in the memory and configured to be executed by the processor, wherein the processor executes the computer program to implement the remote detection method of the metering device described in the above embodiments of the invention.

[0085] Compared with the prior art, the embodiments of the present invention have the following beneficial effects:

[0086] In the case of a plant / station metering device under test, this invention acquires historical line-by-line energy consumption data of the plant / station metering device within a first preset time period; determines whether all historical line-by-line energy consumption data are zero; if so, determines that the detection result of the plant / station metering device is no load; if not, acquires the plant / station forward active power total meter code data, plant / station reverse active power total meter code data, plant / station main meter energy consumption data, plant / station auxiliary meter energy consumption data, plant / station energy meter built-in clock data, plant / station zero-point meter code data, plant / station frozen meter code data, plant / station total meter code energy consumption data, and energy consumption data of each plant / station sub-meter code; determines the plant / station loop detection result based on the plant / station forward active power total meter code data and the plant / station reverse active power total meter code data; and determines the plant / station loop detection result based on the plant / station... The invention utilizes the following methods to determine the power consumption data: First, it compares the power consumption of the main meter and the auxiliary meter to determine the power consumption comparison result. Second, it uses the built-in clock data of the power meters to determine the station clock detection result. Third, it uses the zero-point meter code data and the frozen meter code data to determine the station freeze time detection result. Fourth, it uses the total meter code power consumption data and the power consumption data of each sub-meter code to determine the total time-of-use meter code comparison detection result. If all four methods—station circuit detection, main / auxiliary meter power consumption comparison, station clock detection, station freeze time detection, and total time-of-use meter code comparison—are normal, the station metering device's detection result is considered normal. Otherwise, it is considered abnormal. This invention achieves automated data collection, improves data reliability, reduces human error, and increases inspection efficiency. Attached Figure Description

[0087] Figure 1 This is a flowchart illustrating a remote detection method for a metering device according to an embodiment of the present invention;

[0088] Figure 2 This is a schematic diagram of the structure of a remote detection device for a metering device provided in an embodiment of the present invention. Detailed Implementation

[0089] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. 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.

[0090] Example 1

[0091] Please refer to Figure 1 The above is a flowchart illustrating a remote detection method for a metering device according to an embodiment of the present invention, comprising:

[0092] S1. When the metering device to be tested is a plant metering device, acquire the historical electricity consumption data of the plant metering device within a first preset time period.

[0093] It should be noted that the first preset time is 6 months prior to the current time.

[0094] In step S1, if the metering device to be tested is a plant metering device, the historical electricity consumption data of the plant metering device within the previous 6 months of the current time is obtained.

[0095] S2. Determine whether all the historical row electricity consumption data are zero. If yes, determine that the detection result of the plant metering device is no load. If no, obtain the plant metering device's forward active total meter code data, plant reverse active total meter code data, plant main meter energy consumption data, plant auxiliary meter energy consumption data, plant energy meter built-in clock data, plant zero-point meter code data, plant frozen meter code data, plant total meter code energy consumption data, and energy consumption data of each plant sub-meter code.

[0096] It should be noted that the positive active power meter data of the plant refers to the positive active power meter data statistically recorded by the plant's metering device; similarly, the total reverse active power meter data, the main meter energy consumption data, the auxiliary meter energy consumption data, the built-in clock data of the energy meter, the zero-point meter data, the frozen meter data, the total meter energy consumption data, and the energy consumption data of each plant's sub-meter are all relevant data statistically recorded by the plant's metering device.

[0097] In step S2, if all historical electricity consumption data within the past 6 months is zero, the no-load metering device test result is directly generated. If there are non-zero values ​​in the historical electricity consumption data within the past 6 months, the data used for monitoring is obtained.

[0098] When acquiring forward active power meter data and reverse active power total meter data for power plants, the data at 00:00 of the current day is used. If the data is incomplete or the daily electricity consumption on all lines within the substation is zero, the data is traced back one day, with a maximum traceback period of the preset number of days. The preset number of days can be adjusted, with a default of 10 days.

[0099] It should also be noted that the no-load test result indicates that the metering device cannot detect valid data, so no further judgment is made on whether the metering device is abnormal. The specific reason for the zero electricity consumption data can be arranged manually in the future.

[0100] S3. Determine the plant circuit detection result based on the plant's forward active power total meter code data and the plant's reverse active power total meter code data; determine the main and auxiliary meter power consumption comparison detection result based on the plant's main meter power consumption data and the plant's auxiliary meter power consumption data; determine the plant's clock detection result based on the plant's power meter's built-in clock data; determine the plant's freeze time detection result based on the plant's zero-point meter code data and the plant's freeze meter code data; determine the plant's total time-of-use meter code comparison detection result based on the plant's total meter code power consumption data and the power consumption data of each plant's sub-meter code.

[0101] It should be noted that there are 5 testing items for the metering devices of the plant and station: plant and station circuit test, plant and station main and auxiliary meter power consumption comparison test, plant and station clock test, plant and station freeze time test, and plant and station total time and sub-meter code comparison test.

[0102] S4. If the detection results of the plant circuit, the comparison detection results of the main and auxiliary meter power consumption, the detection results of the plant clock, the detection results of the plant freeze time, and the comparison detection results of the plant total time-of-use meter code are all normal, the detection results of the plant metering device are determined to be normal; otherwise, the detection results of the plant metering device are determined to be abnormal.

[0103] In a preferred embodiment, before acquiring the first historical electricity consumption data of the power plant metering device within a first preset time period, the method further includes:

[0104] Obtain the operating status of the plant;

[0105] Determine whether the plant is in a shutdown state; if so, the metering device detects that the plant is in a shutdown state and stops detecting; if not, continue detecting.

[0106] The step of determining the substation circuit detection result based on the substation's forward active power total meter data and the substation's reverse active power total meter data includes:

[0107] Based on the forward active power meter data and the reverse active power meter data of the substation, determine whether the 10kV outgoing lines, 10kV station service transformers, 10kV connecting transformers, and 10kV arc suppression devices in the substation are all operating with reverse active power; if so, the substation circuit detection result is determined to be abnormal; if not, then...

[0108] Determine whether the 10kV capacitor bank and 35kV reactor in the substation are both operating in the forward reactive power direction, or both operating in the reverse active power direction, or both operating in the forward active power direction; if so, the substation circuit detection result is determined to be abnormal; if not, then...

[0109] Determine whether both the 10kV main transformer and the 35kV transformer in the substation are operating in the positive active direction; if so, the substation circuit detection results are abnormal; if not, then...

[0110] Determine whether the 500kV, 220kV, 110kV, and 35kV main transformer high-voltage lines in the substation are all operating in reverse active power; if yes, then the substation circuit detection result is determined to be abnormal; if not, then...

[0111] Determine whether the 500kV main transformer intermediate frequency, 220kV main transformer intermediate frequency, and 110kV main transformer intermediate frequency in the substation are all generating positive active power. If yes, then the substation circuit detection result is determined to be abnormal; otherwise,

[0112] Determine whether the 500kV, 220kV, 110kV, 35kV, and 10kV main transformers in the substation are all operating in the positive direction with active power; if yes, then the substation circuit test result is determined to be abnormal; if no, then the substation circuit test result is determined to be normal.

[0113] The step of determining the main and auxiliary meter power consumption comparison test results based on the power consumption data of the main meter and the auxiliary meter of the plant includes:

[0114] Calculate the first main-to-sub-meter energy consumption difference between the main meter energy consumption data and the sub-meter energy consumption data of the plant;

[0115] Determine whether the difference in energy consumption between the first main and secondary meters exceeds a preset first difference value; if yes, determine that the energy consumption comparison detection result of the main and secondary meters is abnormal; if no, determine that the energy consumption comparison detection result of the main and secondary meters is normal.

[0116] The step of determining the plant clock detection result based on the built-in clock data of the plant's power meter includes:

[0117] Determine whether the built-in clock data of the power meter in the plant is inconsistent with the actual time; if yes, determine that the clock detection result of the plant is abnormal; if no, determine that the clock detection result of the plant is normal.

[0118] The step of determining the plant freezing time detection result based on the plant zero-point meter code data and the plant freezing meter code data includes:

[0119] Determine whether the zero-point meter code data and the freeze meter code data of the plant are not equal; if so, determine that the freeze time detection result of the plant is abnormal; if not, determine that the freeze time detection result of the plant is normal.

[0120] The step of determining the comparison and detection result of the total time-of-use meter codes of the plant based on the total energy consumption data of the plant and the energy consumption data of each of the plant's sub-meter codes includes:

[0121] Determine whether the total energy consumption data of the plant / station is not equal to the sum of the energy consumption data of each sub-meter of the plant / station; if so, determine that the comparison and detection result of the total time-of-use meter of the plant / station is abnormal; if not, determine that the comparison and detection result of the total time-of-use meter of the plant / station is normal.

[0122] Wherein, "reverse active energy flow" means that the direction of reactive energy flow is the direction of inflow into the bus; "forward reactive energy flow" means that the direction of reactive energy flow is the direction of outflow from the bus; "reverse active energy flow" means that the direction of active energy flow is the direction of inflow into the bus; and "forward active energy flow" means that the direction of active energy flow is the direction of outflow from the bus.

[0123] In this embodiment, before acquiring the first historical electricity consumption data of the power plant metering device within the first preset time period, the operating status of the power plant must also be acquired. If the operating status of the power plant is out of service, the detection result of the power plant metering device is out of service, and the detection is stopped, that is, no further operation is performed. If the operating status of the power plant is not out of service, the detection continues, that is, the subsequent operation continues.

[0124] In substation circuit testing, the total positive active power, total positive reactive power, total reverse active power, and total reverse reactive power readings of the energy meter should follow the principle of reverse direction for power flowing into the busbar and positive direction for power flowing out of the busbar. If any of the following conditions occur, the substation circuit test result is abnormal; otherwise, the substation circuit test result is normal. The following conditions include:

[0125] (1) 10kV outgoing lines, 10kV station service transformers, 10kV connecting transformers, and 10kV arc suppression devices operate in the "reverse active power" mode;

[0126] (2) 10kV capacitor banks and 35kV reactors are in "forward reactive", "reverse active" or "forward active" mode.

[0127] (3) The 10kV main transformer and the 35kV transformer are in "positive active power" mode.

[0128] (4) The 500kV main transformer, 220kV main transformer, 110kV main transformer, and 35kV main transformer are operating in the "reverse active power" mode.

[0129] (5) The 500kV main transformer intermediate, the 220kV main transformer intermediate, and the 110kV main transformer intermediate are "positive active";

[0130] (6) The 500kV main transformer is low, the 220kV main transformer is low, the 110kV main transformer is low, the 35kV main transformer is low, and the 10kV main transformer is low, which are "positive active".

[0131] In a preferred embodiment, the remote detection method for the metering device further includes:

[0132] The metering device to be tested is a dedicated transformer metering device, which acquires the user's operating status.

[0133] Determine whether the user's operating status is out of service; if yes, the detection result of the dedicated transformer metering device is out of service, and the detection is stopped; if no, obtain the dedicated transformer three-phase current of the dedicated transformer metering device.

[0134] Determine whether all three-phase currents of the transformer are less than a preset first current threshold. If yes, the detection result of the transformer metering device is no load. If no, acquire the transformer data items corresponding to the second largest current value data of the transformer A phase voltage, transformer B phase voltage, transformer C phase voltage, transformer A phase current, transformer B phase current, transformer C phase current, transformer second largest current value data within a second preset time period, transformer built-in clock data, transformer zero-point meter code data, transformer frozen meter code data, transformer total meter code energy consumption data, and energy consumption data of each transformer sub-meter code. The transformer data items include: voltage, current, active power, reactive power, and power factor.

[0135] Based on the phase voltage of phase A, phase voltage of phase B, phase voltage of phase C, phase current of phase A, phase current of phase B, and phase current of phase C of the dedicated transformer, the detection result of the dedicated transformer circuit is determined; based on the dedicated transformer data item corresponding to the second largest current value data within the second preset time period, the detection result of the dedicated transformer load is determined; based on the built-in clock data of the dedicated transformer energy meter, the detection result of the dedicated transformer clock is determined; based on the dedicated transformer zero-point meter code data and the dedicated transformer frozen meter code data, the detection result of the dedicated transformer frozen time is determined; based on the total meter code energy consumption data of the dedicated transformer and the energy consumption data of each dedicated transformer sub-meter code, the detection result of the total time-sharing meter code comparison of the dedicated transformer is determined.

[0136] If the detection results of the dedicated transformer circuit, the dedicated transformer load, the dedicated transformer clock, the dedicated transformer freeze time, and the dedicated transformer total time-of-use meter code comparison are all normal, the detection result of the dedicated transformer metering device is determined to be normal; otherwise, the detection result of the dedicated transformer metering device is determined to be abnormal.

[0137] In this embodiment, the metering device to be tested is a dedicated transformer metering device. The user's operating status is obtained. If the user's operating status is out of service, the detection result of the dedicated transformer metering device is out of service, and the detection is stopped, that is, no further operation is performed. If the user's operating status is not out of service, the dedicated transformer three-phase current of the dedicated transformer metering device is obtained.

[0138] If the three-phase current of the dedicated transformer is less than the preset first current threshold, the test result of the dedicated transformer metering device under no-load conditions is directly generated. If the three-phase current of the dedicated transformer is less than the preset first current threshold, the data used for testing is acquired. The first current threshold is adjustable, with a default value of 0.03 amps.

[0139] It should be noted that the phase voltage of phase A of the dedicated transformer refers to the phase voltage of item A as statistically recorded by the dedicated transformer metering device; similarly, the phase voltage of phase B of the dedicated transformer, the phase voltage of phase C of the dedicated transformer, the phase current of phase A of the dedicated transformer, the phase current of phase B of the dedicated transformer, the phase current of phase C of the dedicated transformer, the data items of the dedicated transformer, the built-in clock data of the dedicated transformer energy meter, the zero-point meter code data of the dedicated transformer, the frozen meter code data of the dedicated transformer, the total meter code energy consumption data of the dedicated transformer, and the energy consumption data of each dedicated transformer sub-meter code are all relevant data statistically recorded by the dedicated transformer metering device.

[0140] When acquiring the phase voltage of A phase, phase voltage of B phase, phase voltage of C phase, phase current of A phase, phase current of B phase, and phase current of C phase of the dedicated transformer, the data at 0:00 of the day is used.

[0141] The data item corresponding to the second largest current value of the dedicated transformer metering device within the second preset time period is obtained. The data item corresponding to the second largest current value among the 24 hourly data of the previous day's electricity meter is taken. The data item includes voltage, current, active power, reactive power, and power factor.

[0142] There are five testing items for the metering device of the special transformer: special transformer circuit test, special transformer load test, special transformer clock test, special transformer freeze time test, and special transformer total time and minute meter code comparison test.

[0143] In a preferred embodiment, determining the transformer circuit detection result based on the phase voltage of phase A, the phase voltage of phase B, the phase voltage of phase C, the phase current of phase A, the phase current of phase B, and the phase current of phase C of the transformer includes:

[0144] Calculate the phase angle of phase A of the dedicated transformer based on the phase voltage and phase current of phase A of the dedicated transformer;

[0145] Calculate the phase angle of phase B of the dedicated transformer based on the phase voltage and phase current of phase B of the dedicated transformer;

[0146] Calculate the phase angle of the C phase of the dedicated transformer based on the phase voltage and phase current of the C phase of the dedicated transformer;

[0147] If the power system corresponding to the dedicated transformer metering device is a three-phase four-wire system, then determine whether at least one of the phase angles of the dedicated transformer A phase, the dedicated transformer B phase, and the dedicated transformer C phase is within a preset first included angle range; if yes, then determine that the detection result of the dedicated transformer circuit is abnormal; if no, then determine that the detection result of the dedicated transformer circuit is normal.

[0148] If the power system corresponding to the dedicated transformer metering device is a three-phase three-wire system, then determine whether the phase angle of phase A of the dedicated transformer is within the preset second included angle range; if yes, then determine that the detection result of the dedicated transformer circuit is abnormal; if no, then

[0149] Determine whether the phase angle of phase C of the special transformer is within the preset third included angle range; if yes, determine that the detection result of the special transformer circuit is abnormal; if no, determine that the detection result of the special transformer circuit is normal.

[0150] The step of determining the transformer load detection result based on the transformer data item corresponding to the second largest current value data within the second preset time period includes:

[0151] Based on the data items of the dedicated transformer, determine whether there is an abnormal current, voltage, or power; if so, determine that the load detection result of the dedicated transformer is abnormal; if not, determine that the load detection result of the dedicated transformer is normal.

[0152] The step of determining the transformer clock detection result based on the built-in clock data of the transformer energy meter includes:

[0153] Determine whether the built-in clock data of the dedicated transformer energy meter is inconsistent with the actual time; if yes, determine that the dedicated transformer clock detection result is abnormal; if no, determine that the dedicated transformer clock detection result is normal.

[0154] The step of determining the transformer freeze time detection result based on the transformer zero-point meter code data and the transformer freeze meter code data includes:

[0155] Determine whether the zero-point meter code data and the freeze meter code data of the special transformer are not equal; if so, determine that the freeze time detection result of the special transformer is abnormal; if not, determine that the freeze time detection result of the protected special transformer is normal.

[0156] The step of determining the comparison and detection result of the total and time-of-use meter codes of the dedicated transformer based on the total meter code energy consumption data and the energy consumption data of each of the dedicated transformer sub-meter codes includes:

[0157] Determine whether the sum of the total energy consumption data of the dedicated transformer and the sum of the energy consumption data of each of the dedicated transformer sub-meters is not equal; if yes, then determine that the comparison and detection result of the total and sub-meter codes of the dedicated transformer is abnormal; if no, then determine that the comparison and detection result of the total and sub-meter codes of the dedicated transformer is normal.

[0158] In this embodiment, the relevant data in the special transformer circuit detection needs to meet the following data requirements:

[0159] (1) When the meter connection method is three-phase three-wire, the phase current of phase B, the active power of phase B and the reactive power of phase B cannot have data at the same time, and the amount of data is greater than 0.

[0160] (2) When the meter connection method is three-phase three-wire, there are data for phase voltage of phase A, phase voltage of phase C, phase current of phase A, phase current of phase C, total active power, active power of phase A, active power of phase C, total reactive power, reactive power of phase A and reactive power of phase C, and the minimum current is greater than 0.25 amps.

[0161] (3) When the meter connection method is three-phase four-wire, the phase voltage of phase A, phase voltage of phase B, phase voltage of phase C, phase current of phase A, phase current of phase B, phase current of phase C (reverse current), total active power, active power of phase A, active power of phase B, active power of phase C, total reactive power, reactive power of phase A, reactive power of phase B and reactive power of phase C are all available, and the minimum current is greater than 0.25 amps;

[0162] If ammeter data is missing or the requirements of point (2) are not met, the data will be retrieved one day prior, with the maximum number of days to be retrieved being the preset number of days. The preset number of days can be adjusted, and the default is 10 days.

[0163] In the load testing of dedicated transformers, the relevant data must meet the following requirements:

[0164] (1) When the meter connection method is three-phase three-wire, the phase current of phase B, the active power of phase B and the reactive power of phase B cannot have data at the same time, and the amount of data is greater than 0.

[0165] (2) When the meter connection method is three-phase three-wire, there are data for phase voltage of phase A, phase voltage of phase C, phase current of phase A, phase current of phase C, total active power, active power of phase A, active power of phase C, total reactive power, reactive power of phase A and reactive power of phase C, and the minimum current is greater than 0.25 amps.

[0166] (3) When the meter connection method is three-phase four-wire, the currents of phase A and phase C are basically balanced, or when the meter connection method is three-phase four-wire, the currents of phase A, phase B and phase C are basically balanced, that is, the ratio of a certain current to the average current of each phase is less than the first preset ratio. The first preset ratio is adjustable and the default is 30%.

[0167] (4) When the meter connection method is three-phase four-wire, the phase voltage of phase A, phase voltage of phase B, phase voltage of phase C, phase current of phase A, phase current of phase B, phase current of phase C (reverse current), total active power, active power of phase A, active power of phase B, active power of phase C, total reactive power, reactive power of phase A, reactive power of phase B and reactive power of phase C are all available, and the minimum current is greater than 0.25 amps;

[0168] If ammeter data is missing or the requirements of point (2) are not met, the data will be retrieved again by tracing back one day. The maximum number of days to trace back is the preset number of days. The preset number of days can be adjusted, and the default is 10 days.

[0169] Based on the aforementioned transformer data items, determine whether there are abnormal current, abnormal voltage, or abnormal power, specifically including:

[0170] 1. An abnormal current exists if any of the following conditions are met:

[0171] i. Both of the above data requirements (1) and (4) are met, or both of the above requirements (2) and (4) are met;

[0172] ii. The second preset ratio for load current exceeding the rated current of the energy meter. The second preset ratio is adjustable and the default value is 100%.

[0173] iii. The current imbalance rate of one of the phases A, B and C is greater than the third preset ratio. The third preset ratio is adjustable and the default value is 30%.

[0174] 2. A voltage anomaly exists if any of the following conditions are met:

[0175] i. Both of the above data requirements (1) and (4) are met, or both of the above requirements (2) and (4) are met;

[0176] ii. The voltage of a certain phase is lower than the fourth preset ratio of the rated voltage of the energy meter. The fourth preset ratio is adjustable and the default value is 93% (for three-phase three-wire, the voltage of phases A and C is judged; for three-phase four-wire, the voltage of phases A, B, and C is judged).

[0177] iii. The fifth preset ratio for a certain phase being higher than the rated voltage of the rated energy meter. The fifth preset ratio is adjustable and defaults to 110% (for three-phase three-wire systems, the voltage of phases A and C is determined; for three-phase four-wire systems, the voltage of phases A, B, and C is determined).

[0178] 3. If this condition is met, there is a power anomaly: the ratio of the difference between the total active power and the sum of the three-phase active power to the total active power exceeds the sixth preset ratio. The sixth preset ratio is adjustable and the default value is 10%.

[0179] In a preferred embodiment, the remote detection method for the metering device further includes:

[0180] When the metering device to be tested is a public transformer metering device, the operating status of the transformer substation is obtained;

[0181] Determine whether the operating status of the transformer substation is out of service; if yes, the detection result of the public transformer metering device is out of service, and the detection is stopped; if no, obtain the public transformer three-phase current of the public transformer metering device.

[0182] The system determines whether all three-phase currents of the transformer are less than a preset second current threshold. If so, the transformer metering device detects no load. If not, it acquires the transformer data items corresponding to the second-largest current value data within a second preset time period, the transformer energy meter's built-in clock data, the transformer reverse active power total meter code first data, the transformer reverse active power total meter code second data, the transformer total meter code energy consumption data, and the energy consumption data of each transformer sub-meter code. The transformer data items include: voltage, current, active power, reactive power, and power factor. The transformer reverse active power total meter code first data is the data corresponding to the transformer reverse active power total meter code at a preset first time point. The transformer reverse active power total meter code second data is the data corresponding to the transformer reverse active power total meter code at a preset second time point.

[0183] Based on the phase voltage of phase A, phase voltage of phase B, phase voltage of phase C, phase current of phase A, phase current of phase B, and phase current of phase C of the transformer, the transformer circuit detection result is determined; based on the transformer data item corresponding to the second largest current value data within the second preset time period, the transformer load detection result is determined; based on the built-in clock data of the transformer energy meter, the transformer clock detection result is determined; based on the first and second data of the transformer reverse active power total meter code, the transformer freeze time detection result is determined; based on the energy consumption data of the transformer total meter code and the energy consumption data of each transformer sub-meter code, the transformer total time-of-use meter code comparison detection result is determined.

[0184] If the results of the transformer circuit detection, the transformer load detection, the transformer clock detection, the transformer freeze time detection, and the transformer total time-of-use meter code comparison are all normal, the detection result of the transformer metering device is determined to be normal; otherwise, the detection result of the transformer metering device is determined to be abnormal.

[0185] In this embodiment, when the metering device to be tested is a public transformer metering device, the operating status of the transformer area is obtained. If the operating status of the transformer area is out of service, the detection result of the public transformer metering device is out of service, and the detection is stopped, that is, no further operation is performed; if the operating status of the transformer area is not out of service, the three-phase current of the public transformer of the public transformer metering device is obtained.

[0186] If the three-phase current of the transformer is less than the preset second current threshold, the test result of the transformer metering device under no-load conditions is directly generated. If the three-phase current of the transformer is less than the preset second current threshold, the data used for testing is acquired. The second current threshold is adjustable, with a default value of 0.03 amps.

[0187] It should be noted that the phase voltage of phase A of the public transformer refers to the phase voltage of item A as statistically recorded by the public transformer metering device; similarly, the phase voltage of phase B of the public transformer, the phase voltage of phase C of the public transformer, the phase current of phase A of the public transformer, the phase current of phase B of the public transformer, the phase current of phase C of the public transformer, the public transformer data items, the built-in clock data of the public transformer energy meter, the public transformer zero-point meter code data, the public transformer frozen meter code data, the total meter code energy consumption data of the public transformer, and the energy consumption data of each public transformer sub-meter code are all relevant data statistically recorded by the public transformer metering device.

[0188] When acquiring the phase voltage of transformer A, phase voltage of transformer B, phase voltage of transformer C, phase current of transformer A, phase current of transformer B, and phase current of transformer C, the data at 0:00 on the same day should be used.

[0189] The data item corresponding to the second largest current value of the public transformer metering device within the second preset time period is obtained. The data item corresponding to the second largest current value among the 24 hourly data of the previous day's electricity meter is taken. The data item includes voltage, current, active power, reactive power, and power factor.

[0190] The first time point for obtaining the first data of the reverse active power total meter code of the public transformer is 0:00 on the 1st of the current month; the second time point for obtaining the second data of the reverse active power total meter code of the public transformer is 0:00 on the 1st of the previous month.

[0191] There are five testing items for the metering device of the public transformer: public transformer circuit test, public transformer load test, public transformer clock test, public transformer freeze time test, and public transformer total time-division meter code comparison test.

[0192] In a preferred embodiment, determining the transformer circuit detection result based on the transformer A-phase voltage, transformer B-phase voltage, transformer C-phase voltage, transformer A-phase current, transformer B-phase current, and transformer C-phase current includes:

[0193] Calculate the phase angle of phase A of the common transformer based on the phase voltage and phase current of phase A of the common transformer;

[0194] Calculate the phase angle of phase B of the common transformer based on the phase voltage and phase current of phase B of the common transformer;

[0195] Calculate the phase angle of the C phase of the common transformer based on the phase voltage and phase current of the C phase of the common transformer;

[0196] The step of determining the transformer load detection result based on the transformer data item corresponding to the second largest current value data within the second preset time period includes:

[0197] If the power system corresponding to the public transformer metering device is a three-phase four-wire system, then determine whether at least one of the public transformer phase A angle, the public transformer phase B angle, and the public transformer phase C angle is within a preset first included angle range; if yes, then determine that the public transformer circuit detection result is abnormal; if no, then determine that the public transformer circuit detection result is normal.

[0198] If the power system corresponding to the public transformer metering device is a three-phase three-wire system, then determine whether the phase angle of phase A of the public transformer is within the preset second included angle range; if yes, then determine that the detection result of the public transformer circuit is abnormal; if no, then

[0199] Determine whether the phase angle of phase C of the public transformer is within the preset third included angle range; if yes, determine that the detection result of the public transformer circuit is abnormal; if no, determine that the detection result of the public transformer circuit is normal.

[0200] The step of determining the public transformer clock detection result based on the built-in clock data of the public transformer energy meter includes:

[0201] Determine whether the built-in clock data of the public transformer energy meter is inconsistent with the actual time; if yes, determine that the public transformer clock detection result is abnormal; if no, determine that the public transformer clock detection result is normal.

[0202] The step of determining the transformer freeze time detection result based on the first data of the transformer reverse active power total meter and the second data of the transformer reverse active power total meter includes:

[0203] Calculate the reverse travel difference between the first data of the reverse active power total meter code of the public transformer and the second data of the reverse active power total meter code of the public transformer;

[0204] Determine if the reverse travel difference is not zero; if yes, then the public transformer freezing time detection result is determined to be abnormal; if no, then the public transformer freezing time detection result is determined to be normal.

[0205] The step of determining the comparison and detection result of the total time-of-use meter code of the public transformer based on the energy consumption data of the total meter code and the energy consumption data of each of the individual meter codes of the public transformer includes:

[0206] Determine whether the sum of the total energy consumption data of the public transformer and the energy consumption data of each of the public transformer sub-meters is not equal; if so, determine that the comparison and detection result of the total and sub-meter codes of the public transformer is abnormal; if not, determine that the comparison and detection result of the total and sub-meter codes of the public transformer is normal.

[0207] In this embodiment, the relevant data in the public transformer circuit detection needs to meet the following data requirements:

[0208] (1) When the meter connection method is three-phase three-wire, the phase current of phase B, the active power of phase B and the reactive power of phase B cannot have data at the same time, and the amount of data is greater than 0.

[0209] (2) When the meter connection method is three-phase three-wire, there are data for phase voltage of phase A, phase voltage of phase C, phase current of phase A, phase current of phase C, total active power, active power of phase A, active power of phase C, total reactive power, reactive power of phase A and reactive power of phase C, and the minimum current is greater than 0.25 amps.

[0210] (3) When the meter connection method is three-phase four-wire, the phase voltage of phase A, phase voltage of phase B, phase voltage of phase C, phase current of phase A, phase current of phase B, phase current of phase C (reverse current), total active power, active power of phase A, active power of phase B, active power of phase C, total reactive power, reactive power of phase A, reactive power of phase B and reactive power of phase C are all available, and the minimum current is greater than 0.25 amps;

[0211] If ammeter data is missing or the requirements of point (2) are not met, the data will be retrieved one day prior, with the maximum number of days to be retrieved being the preset number of days. The preset number of days can be adjusted, and the default is 10 days.

[0212] In the load testing of public transformers, the relevant data must meet the following requirements:

[0213] (1) When the meter connection method is three-phase three-wire, the phase current of phase B, the active power of phase B and the reactive power of phase B cannot have data at the same time, and the amount of data is greater than 0.

[0214] (2) When the meter connection method is three-phase three-wire, there are data for phase voltage of phase A, phase voltage of phase C, phase current of phase A, phase current of phase C, total active power, active power of phase A, active power of phase C, total reactive power, reactive power of phase A and reactive power of phase C, and the minimum current is greater than 0.25 amps.

[0215] (3) When the meter connection method is three-phase four-wire, the currents of phase A and phase C are basically balanced, or when the meter connection method is three-phase four-wire, the currents of phase A, phase B and phase C are basically balanced, that is, the ratio of a certain current to the average current of each phase is less than the first preset ratio. The first preset ratio is adjustable and the default is 30%.

[0216] (4) When the meter connection method is three-phase four-wire, the phase voltage of phase A, phase voltage of phase B, phase voltage of phase C, phase current of phase A, phase current of phase B, phase current of phase C (reverse current), total active power, active power of phase A, active power of phase B, active power of phase C, total reactive power, reactive power of phase A, reactive power of phase B and reactive power of phase C are all available, and the minimum current is greater than 0.25 amps;

[0217] If ammeter data is missing or the requirements of point (2) are not met, the data will be retrieved again by tracing back one day. The maximum number of days to trace back is the preset number of days. The preset number of days can be adjusted, and the default is 10 days.

[0218] Based on the aforementioned transformer data items, determine whether there are any abnormal current, voltage, or power conditions, specifically including:

[0219] 4. An abnormal current exists if any of the following conditions are met:

[0220] iv. Both of the above data requirements (1) and (4) are met, or both of the above requirements (2) and (4) are met;

[0221] v. A second preset ratio where the load current is higher than the rated current of the energy meter;

[0222] vi, the current imbalance rate of one phase among phases A, B and C is greater than the third preset ratio;

[0223] 5. A voltage anomaly exists if any of the following conditions are met:

[0224] iv. Both of the above data requirements (1) and (4) are met, or both of the above requirements (2) and (4) are met;

[0225] v. The voltage of a certain phase is lower than the fourth preset ratio of the rated voltage of the energy meter (for three-phase three-wire, the voltage of phases A and C is determined; for three-phase four-wire, the voltage of phases A, B, and C is determined).

[0226] vi. The fifth preset ratio when a certain phase is higher than the rated voltage of the rated energy meter (for three-phase three-wire, determine the voltage of phases A and C; for three-phase four-wire, determine the voltage of phases A, B, and C).

[0227] 6. If this condition is met, then there is a power anomaly: the ratio of the difference between the total active power and the sum of the three-phase active power to the total active power exceeds the sixth preset ratio.

[0228] In a preferred embodiment, the remote detection method for the metering device further includes:

[0229] When the metering device to be tested is a low-voltage metering device, the built-in clock data of the low-voltage energy meter, the low-voltage zero-point meter code data, the low-voltage frozen meter code data, the low-voltage total meter code energy consumption data, and the energy consumption data of each low-voltage sub-meter code are acquired.

[0230] Based on the built-in clock data of the low-voltage energy meter, the low-voltage clock detection result is determined; based on the low-voltage zero-point meter code data and the low-voltage freeze meter code data, the low-voltage freeze time detection result is determined; based on the low-voltage total meter code energy consumption data and the energy consumption data of each of the low-voltage sub-meter codes, the low-voltage total time-sharing meter code comparison detection result is determined.

[0231] If the low-voltage clock detection result, the low-voltage freeze time detection result, and the low-voltage total time-of-use meter code comparison detection result are all normal, the detection result of the low-voltage metering device is determined to be normal; otherwise, the detection result of the low-voltage metering device is determined to be abnormal.

[0232] In a preferred embodiment, determining the low-voltage clock detection result based on the built-in clock data of the low-voltage energy meter includes:

[0233] Determine whether the built-in clock data of the low-voltage energy meter is inconsistent with the actual time; if yes, determine that the low-voltage clock detection result is abnormal; if no, determine that the low-voltage clock detection result is normal.

[0234] The step of determining the low-pressure freeze time detection result based on the low-pressure zero-point meter code data and the low-pressure freeze meter code data includes:

[0235] Determine whether the low-pressure zero-point meter code data and the low-pressure freeze meter code data are unequal; if so, determine that the low-pressure freeze time detection result is abnormal; if not, determine that the low-pressure freeze time detection result is normal.

[0236] The step of determining the low-voltage total time-of-use meter code comparison and detection result based on the low-voltage total meter code energy consumption data and the energy consumption data of each of the low-voltage sub-meter codes includes:

[0237] Determine whether the sum of the energy consumption data of the total low-voltage meter code and the energy consumption data of each of the individual low-voltage meter codes is not equal; if yes, then determine that the comparison and detection result of the total low-voltage meter code is abnormal; if no, then determine that the comparison and detection result of the total low-voltage meter code is normal.

[0238] Example 2

[0239] Please refer to Figure 2 This is a schematic diagram of the structure of a remote detection device for a metering device according to an embodiment of the present invention, including: a data acquisition module and a detection module;

[0240] The data acquisition module acquires the historical line-time energy consumption data of the plant / station metering device within a first preset time period when the metering device to be tested is a plant / station metering device; when the historical line-time energy consumption data is not all zero, it acquires the plant / station forward active total meter code data, plant / station reverse active total meter code data, plant / station main meter energy consumption data, plant / station auxiliary meter energy consumption data, plant / station energy meter built-in clock data, plant / station zero-point meter code data, plant / station frozen meter code data, plant / station total meter code energy consumption data, and energy consumption data of each plant / station sub-meter code of the plant / station metering device.

[0241] The detection module determines whether all historical line energy consumption data are zero. If so, it determines that the detection result of the substation metering device is no load. If not, it determines the substation circuit detection result based on the substation forward active power total meter data and the substation reverse active power total meter data; it determines the main and auxiliary meter energy consumption comparison detection result based on the substation main meter energy consumption data and the substation auxiliary meter energy consumption data; it determines the substation clock detection result based on the substation energy meter's built-in clock data; and it determines the substation zero-point meter data and the... The system freezes meter readings at the plant / station and determines the plant / station freeze time detection result. Based on the total energy consumption data of the plant / station's total meter readings and the energy consumption data of each of the plant / station's sub-meter readings, the system determines the plant / station's total time-of-use meter reading comparison detection result. If the plant / station circuit detection result, the main / sub-meter energy consumption comparison detection result, the plant / station clock detection result, the plant / station freeze time detection result, and the plant / station total time-of-use meter reading comparison detection result are all normal, the detection result of the plant / station metering device is determined to be normal; otherwise, the detection result of the plant / station metering device is determined to be abnormal.

[0242] Example 3

[0243] Accordingly, embodiments of the present invention provide a terminal device, the terminal device including a processor, a memory, and a computer program stored in the memory and configured to be executed by the processor, wherein the processor executes the computer program to implement the remote detection method of the metering device described in the above embodiments of the invention.

[0244] It should be noted that the device embodiments described above are merely illustrative. The units described as separate components may or may not be physically separate, and 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 modules can be selected to achieve the purpose of this embodiment according to actual needs. Furthermore, in the accompanying drawings of the device embodiments provided by this invention, the connection relationships between modules indicate that they have communication connections, which can be specifically implemented as one or more communication buses or signal lines. Those skilled in the art can understand and implement this without any creative effort.

[0245] Those skilled in the art will clearly understand that, for convenience and brevity, the specific working process of the device described above can be referred to the corresponding process in the foregoing method embodiments, and will not be repeated here.

[0246] The terminal device may be a desktop computer, laptop, handheld computer, or cloud server, etc. The terminal device may include, but is not limited to, a processor and a memory.

[0247] The processor can be a Central Processing Unit (CPU), or other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. The general-purpose processor can be a microprocessor or any conventional processor. The processor is the control center of the device, connecting various parts of the device via various interfaces and lines.

[0248] The memory can be used to store the computer program. The processor implements various functions of the device by running or executing the computer program stored in the memory and calling data stored in the memory. The memory may mainly include a program storage area and a data storage area. The program storage area may store the operating system, at least one application program required for a function, etc.; the data storage area may store data created based on the use of the mobile phone, etc. In addition, the memory may include high-speed random access memory, and may also include non-volatile memory, such as hard disk, RAM, plug-in hard disk, smart media card (SMC), secure digital (SD) card, flash card, at least one disk storage device, flash memory device, or other volatile solid-state storage device.

Claims

1. A remote detection method for a metering device, characterized in that, include: When the metering device to be tested is a plant metering device, the historical electricity consumption data of the plant metering device within a first preset time period is obtained. Determine whether all the historical row electricity consumption data are zero. If so, determine that the detection result of the plant metering device is no load. If not, acquire the plant metering device's forward active total meter code data, reverse active total meter code data, plant main meter energy consumption data, plant auxiliary meter energy consumption data, plant energy meter built-in clock data, plant zero-point meter code data, plant frozen meter code data, plant total meter code energy consumption data, and energy consumption data of each plant sub-meter code. Based on the positive active power total meter data and the reverse active power total meter data of the power plant, determine the power plant circuit detection results; Based on the power consumption data of the main meter and the power consumption data of the auxiliary meter of the plant, the power consumption comparison test results of the main and auxiliary meters are determined. The plant clock detection result is determined based on the built-in clock data of the plant's power meter; The plant freezing time detection result is determined based on the plant zero-point meter code data and the plant freezing meter code data. Based on the total energy consumption data of the plant and the energy consumption data of each sub-meter of the plant, the comparison and detection results of the total time-of-use meter codes of the plant are determined. If the detection results of the plant circuit, the comparison detection results of the main and auxiliary meter power consumption, the detection results of the plant clock, the detection results of the plant freeze time, and the comparison detection results of the plant total time-of-use meter code are all normal, the detection results of the plant metering device are determined to be normal; otherwise, the detection results of the plant metering device are determined to be abnormal.

2. The remote detection method for a metering device as described in claim 1, characterized in that, Before acquiring the first historical electricity consumption data of the plant metering device within the first preset time period, the method further includes: Obtain the operating status of the plant; Determine whether the plant is in a shutdown state; if so, the metering device detects that the plant is in a shutdown state and stops detecting; if not, continue detecting. The step of determining the substation circuit detection result based on the substation's forward active power total meter data and the substation's reverse active power total meter data includes: Based on the forward active power meter data and the reverse active power meter data of the substation, determine whether the 10kV outgoing lines, 10kV station service transformers, 10kV connecting transformers, and 10kV arc suppression devices in the substation are all operating with reverse active power; if so, the substation circuit detection result is determined to be abnormal; if not, then... Determine whether the 10kV capacitor bank and 35kV reactor in the substation are both operating in the forward reactive power direction, or both operating in the reverse active power direction, or both operating in the forward active power direction; if so, the substation circuit detection result is determined to be abnormal; if not, then... Determine whether both the 10kV and 35kV main transformers in the substation are operating in the positive active direction; if so, the substation circuit detection result is abnormal; if not, then... Determine whether the 500kV, 220kV, 110kV, and 35kV main transformer high-voltage lines in the substation are all operating in reverse active power; if yes, then the substation circuit detection result is determined to be abnormal; if not, then... Determine whether the 500kV main transformer intermediate frequency, 220kV main transformer intermediate frequency, and 110kV main transformer intermediate frequency in the substation are all generating positive active power. If yes, then the substation circuit detection result is determined to be abnormal; otherwise, Determine whether the 500kV, 220kV, 110kV, 35kV, and 10kV main transformers in the substation are all operating in the positive direction with active power; if yes, then the substation circuit test result is determined to be abnormal; if no, then the substation circuit test result is determined to be normal. The step of determining the main and auxiliary meter power consumption comparison test results based on the power consumption data of the main meter and the auxiliary meter of the plant includes: Calculate the first main-to-sub-meter energy consumption difference between the main meter energy consumption data and the sub-meter energy consumption data of the plant; Determine whether the difference in energy consumption between the first main and secondary meters exceeds a preset first difference value; if yes, determine that the energy consumption comparison detection result of the main and secondary meters is abnormal; if no, determine that the energy consumption comparison detection result of the main and secondary meters is normal. The step of determining the plant clock detection result based on the built-in clock data of the plant's power meter includes: Determine whether the built-in clock data of the power meter in the plant is inconsistent with the actual time; if yes, determine that the clock detection result of the plant is abnormal; if no, determine that the clock detection result of the plant is normal. The step of determining the plant freezing time detection result based on the plant zero-point meter code data and the plant freezing meter code data includes: Determine whether the zero-point meter code data and the freeze meter code data of the plant are not equal; if so, determine that the freeze time detection result of the plant is abnormal; if not, determine that the freeze time detection result of the plant is normal. The step of determining the comparison and detection result of the total time-of-use meter codes of the plant based on the total energy consumption data of the plant and the energy consumption data of each of the plant's sub-meter codes includes: Determine whether the total energy consumption data of the plant / station is not equal to the sum of the energy consumption data of each sub-meter of the plant / station; if so, determine that the comparison and detection result of the total time-of-use meter of the plant / station is abnormal; if not, determine that the comparison and detection result of the total time-of-use meter of the plant / station is normal. Wherein, "reverse active energy flow" means that the direction of reactive energy flow is the direction of inflow into the bus; "forward reactive energy flow" means that the direction of reactive energy flow is the direction of outflow from the bus; "reverse active energy flow" means that the direction of active energy flow is the direction of inflow into the bus; and "forward active energy flow" means that the direction of active energy flow is the direction of outflow from the bus.

3. The remote detection method for a metering device as described in claim 1, characterized in that, Also includes: The metering device to be tested is a dedicated transformer metering device, which acquires the user's operating status. Determine whether the user's running status is in a stopped state; If yes, the detection result of the dedicated transformer metering device is shutdown, and the detection is stopped; if no, the dedicated transformer three-phase current of the dedicated transformer metering device is obtained. Determine whether all three-phase currents of the transformer are less than a preset first current threshold. If yes, the detection result of the transformer metering device is no load. If no, acquire the transformer data items corresponding to the second largest current value data of the transformer A phase voltage, transformer B phase voltage, transformer C phase voltage, transformer A phase current, transformer B phase current, transformer C phase current, transformer second largest current value data within a second preset time period, transformer built-in clock data, transformer zero-point meter code data, transformer frozen meter code data, transformer total meter code energy consumption data, and energy consumption data of each transformer sub-meter code. The transformer data items include: voltage, current, active power, reactive power, and power factor. Based on the phase voltage of phase A, phase voltage of phase B, phase voltage of phase C, phase current of phase A, phase current of phase B, and phase current of phase C of the dedicated transformer, the detection result of the dedicated transformer circuit is determined; based on the dedicated transformer data item corresponding to the second largest current value data within the second preset time period, the detection result of the dedicated transformer load is determined; based on the built-in clock data of the dedicated transformer energy meter, the detection result of the dedicated transformer clock is determined; based on the dedicated transformer zero-point meter code data and the dedicated transformer frozen meter code data, the detection result of the dedicated transformer frozen time is determined; based on the total meter code energy consumption data of the dedicated transformer and the energy consumption data of each dedicated transformer sub-meter code, the detection result of the total time-sharing meter code comparison of the dedicated transformer is determined. If the detection results of the dedicated transformer circuit, the dedicated transformer load, the dedicated transformer clock, the dedicated transformer freeze time, and the dedicated transformer total time-of-use meter code comparison are all normal, the detection result of the dedicated transformer metering device is determined to be normal; otherwise, the detection result of the dedicated transformer metering device is determined to be abnormal.

4. The remote detection method for a metering device as described in claim 3, characterized in that, The determination of the transformer circuit detection result based on the phase voltage of phase A, the phase voltage of phase B, the phase voltage of phase C, the phase current of phase A, the phase current of phase B, and the phase current of phase C of the transformer includes: Calculate the phase angle of phase A of the dedicated transformer based on the phase voltage and phase current of phase A of the dedicated transformer; Calculate the phase angle of phase B of the dedicated transformer based on the phase voltage and phase current of phase B of the dedicated transformer; Calculate the phase angle of the C phase of the dedicated transformer based on the phase voltage and phase current of the C phase of the dedicated transformer; If the power system corresponding to the dedicated transformer metering device is a three-phase four-wire system, then determine whether at least one of the phase angles of the dedicated transformer A phase, the dedicated transformer B phase, and the dedicated transformer C phase is within a preset first included angle range; if yes, then determine that the detection result of the dedicated transformer circuit is abnormal; if no, then determine that the detection result of the dedicated transformer circuit is normal. If the power system corresponding to the dedicated transformer metering device is a three-phase three-wire system, then determine whether the phase angle of phase A of the dedicated transformer is within the preset second included angle range; if yes, then determine that the detection result of the dedicated transformer circuit is abnormal; if no, then Determine whether the phase angle of phase C of the special transformer is within the preset third included angle range; if yes, determine that the detection result of the special transformer circuit is abnormal; if no, determine that the detection result of the special transformer circuit is normal. The step of determining the transformer load detection result based on the transformer data item corresponding to the second largest current value data within the second preset time period includes: Based on the data items of the dedicated transformer, determine whether there is an abnormal current, voltage, or power; if so, determine that the load detection result of the dedicated transformer is abnormal; if not, determine that the load detection result of the dedicated transformer is normal. The step of determining the transformer clock detection result based on the built-in clock data of the transformer energy meter includes: Determine whether the built-in clock data of the dedicated transformer energy meter is inconsistent with the actual time; if yes, determine that the dedicated transformer clock detection result is abnormal; if no, determine that the dedicated transformer clock detection result is normal. The step of determining the transformer freeze time detection result based on the transformer zero-point meter code data and the transformer freeze meter code data includes: Determine whether the zero-point meter code data and the freeze meter code data of the special transformer are not equal; if so, determine that the freeze time detection result of the special transformer is abnormal; if not, determine that the freeze time detection result of the protected special transformer is normal. The step of determining the comparison and detection result of the total and time-of-use meter codes of the dedicated transformer based on the total meter code energy consumption data and the energy consumption data of each of the dedicated transformer sub-meter codes includes: Determine whether the sum of the total energy consumption data of the dedicated transformer and the sum of the energy consumption data of each of the dedicated transformer sub-meters is not equal; if yes, then determine that the comparison and detection result of the total and sub-meter codes of the dedicated transformer is abnormal; if no, then determine that the comparison and detection result of the total and sub-meter codes of the dedicated transformer is normal.

5. The remote detection method for a metering device as described in claim 1, characterized in that, Also includes: When the metering device to be tested is a public transformer metering device, the operating status of the transformer substation is obtained; Determine whether the operating status of the transformer area is out of service; If yes, the detection result of the public transformer metering device is shutdown, and the detection is stopped; if no, the public transformer three-phase current of the public transformer metering device is obtained. The system determines whether all three-phase currents of the transformer are less than a preset second current threshold. If so, the transformer metering device detects no load. If not, it acquires the transformer data items corresponding to the second-largest current value data within a second preset time period, the transformer energy meter's built-in clock data, the transformer reverse active power total meter code first data, the transformer reverse active power total meter code second data, the transformer total meter code energy consumption data, and the energy consumption data of each transformer sub-meter code. The transformer data items include: voltage, current, active power, reactive power, and power factor. The transformer reverse active power total meter code first data is the data corresponding to the transformer reverse active power total meter code at a preset first time point. The transformer reverse active power total meter code second data is the data corresponding to the transformer reverse active power total meter code at a preset second time point. Based on the phase voltage of phase A, phase voltage of phase B, phase voltage of phase C, phase current of phase A, phase current of phase B, and phase current of phase C of the transformer, the transformer circuit detection result is determined; based on the transformer data item corresponding to the second largest current value data within the second preset time period, the transformer load detection result is determined; based on the built-in clock data of the transformer energy meter, the transformer clock detection result is determined; based on the first and second data of the transformer reverse active power total meter code, the transformer freeze time detection result is determined; based on the energy consumption data of the transformer total meter code and the energy consumption data of each transformer sub-meter code, the transformer total time-of-use meter code comparison detection result is determined. If the results of the transformer circuit detection, the transformer load detection, the transformer clock detection, the transformer freeze time detection, and the transformer total time-of-use meter code comparison are all normal, the detection result of the transformer metering device is determined to be normal; otherwise, the detection result of the transformer metering device is determined to be abnormal.

6. The remote detection method for a metering device as described in claim 5, characterized in that, The step of determining the transformer circuit detection result based on the phase voltage of transformer A, the phase voltage of transformer B, the phase voltage of transformer C, the phase current of transformer A, the phase current of transformer B, and the phase current of transformer C includes: Calculate the phase angle of phase A of the common transformer based on the phase voltage and phase current of phase A of the common transformer; Calculate the phase angle of phase B of the common transformer based on the phase voltage and phase current of phase B of the common transformer; Calculate the phase angle of the C phase of the common transformer based on the phase voltage and phase current of the C phase of the common transformer; The step of determining the transformer load detection result based on the transformer data item corresponding to the second largest current value data within the second preset time period includes: If the power system corresponding to the public transformer metering device is a three-phase four-wire system, then determine whether at least one of the public transformer phase A angle, the public transformer phase B angle, and the public transformer phase C angle is within a preset first included angle range; if yes, then determine that the public transformer circuit detection result is abnormal; if no, then determine that the public transformer circuit detection result is normal. If the power system corresponding to the public transformer metering device is a three-phase three-wire system, then determine whether the phase angle of phase A of the public transformer is within the preset second included angle range; if yes, then determine that the detection result of the public transformer circuit is abnormal; if no, then Determine whether the phase angle of phase C of the public transformer is within the preset third included angle range; if yes, determine that the detection result of the public transformer circuit is abnormal; if no, determine that the detection result of the public transformer circuit is normal. The step of determining the public transformer clock detection result based on the built-in clock data of the public transformer energy meter includes: Determine whether the built-in clock data of the public transformer energy meter is inconsistent with the actual time; if yes, determine that the public transformer clock detection result is abnormal; if no, determine that the public transformer clock detection result is normal. The step of determining the transformer freeze time detection result based on the first data of the transformer reverse active power total meter and the second data of the transformer reverse active power total meter includes: Calculate the reverse travel difference between the first data of the reverse active power total meter code of the public transformer and the second data of the reverse active power total meter code of the public transformer; Determine if the reverse travel difference is not zero; if yes, then the public transformer freezing time detection result is determined to be abnormal; if no, then the public transformer freezing time detection result is determined to be normal. The step of determining the comparison and detection result of the total time-of-use meter code of the public transformer based on the energy consumption data of the total meter code and the energy consumption data of each of the sub-meter codes of the public transformer includes: Determine whether the sum of the total energy consumption data of the public transformer and the energy consumption data of each of the public transformer sub-meters is not equal; if so, determine that the comparison and detection result of the total and sub-meter codes of the public transformer is abnormal; if not, determine that the comparison and detection result of the total and sub-meter codes of the public transformer is normal.

7. The remote detection method for a metering device as described in claim 1, characterized in that, Also includes: When the metering device to be tested is a low-voltage metering device, the built-in clock data of the low-voltage energy meter, the low-voltage zero-point meter code data, the low-voltage frozen meter code data, the low-voltage total meter code energy consumption data, and the energy consumption data of each low-voltage sub-meter code are acquired. Based on the built-in clock data of the low-voltage energy meter, determine the low-voltage clock detection result; based on the low-voltage zero-point meter code data and the low-voltage freeze meter code data, determine the low-voltage freeze time detection result. Based on the energy consumption data of the total low-voltage meter code and the energy consumption data of each of the sub-low-voltage meter codes, the comparison and detection results of the total low-voltage meter code and the sub-low-voltage meter code are determined. If the low-voltage clock detection result, the low-voltage freeze time detection result, and the low-voltage total time-of-use meter code comparison detection result are all normal, the detection result of the low-voltage metering device is determined to be normal; otherwise, the detection result of the low-voltage metering device is determined to be abnormal.

8. The remote detection method for a metering device as described in claim 7, characterized in that, Based on the built-in clock data of the low-voltage energy meter, the low-voltage clock detection result is determined, including: Determine whether the built-in clock data of the low-voltage energy meter is inconsistent with the actual time; if yes, determine that the low-voltage clock detection result is abnormal; if no, determine that the low-voltage clock detection result is normal. The step of determining the low-pressure freeze time detection result based on the low-pressure zero-point meter code data and the low-pressure freeze meter code data includes: Determine whether the low-pressure zero-point meter code data and the low-pressure freeze meter code data are unequal; if so, determine that the low-pressure freeze time detection result is abnormal; if not, determine that the low-pressure freeze time detection result is normal. The step of determining the low-voltage total time-of-use meter code comparison and detection result based on the low-voltage total meter code energy consumption data and the energy consumption data of each of the low-voltage sub-meter codes includes: Determine whether the sum of the energy consumption data of the total low-voltage meter code and the energy consumption data of each of the individual low-voltage meter codes is not equal; if yes, then determine that the comparison and detection result of the total low-voltage meter code is abnormal; if no, then determine that the comparison and detection result of the total low-voltage meter code is normal.

9. A remote detection device for a metering instrument, characterized in that, include: Data acquisition module and detection module; The data acquisition module acquires the historical line-time energy consumption data of the plant / station metering device within a first preset time period when the metering device to be tested is a plant / station metering device; when the historical line-time energy consumption data is not all zero, it acquires the plant / station forward active total meter code data, plant / station reverse active total meter code data, plant / station main meter energy consumption data, plant / station auxiliary meter energy consumption data, plant / station energy meter built-in clock data, plant / station zero-point meter code data, plant / station frozen meter code data, plant / station total meter code energy consumption data, and energy consumption data of each plant / station sub-meter code of the plant / station metering device. The detection module determines whether all historical line energy consumption data are zero. If so, it determines that the detection result of the plant metering device is no load. If not, it determines the plant circuit detection result based on the plant's forward active power total meter data and the plant's reverse active power total meter data; and determines the main and auxiliary meter energy consumption comparison detection result based on the plant's main meter energy consumption data and the plant's auxiliary meter energy consumption data. The plant clock detection result is determined based on the built-in clock data of the plant's power meter; The plant freezing time detection result is determined based on the plant zero-point meter code data and the plant freezing meter code data. Based on the total energy consumption data of the plant and the energy consumption data of each sub-meter of the plant, the comparison and detection results of the total time-of-use meter codes of the plant are determined. If the detection results of the plant circuit, the comparison detection results of the main and auxiliary meter power consumption, the detection results of the plant clock, the detection results of the plant freeze time, and the comparison detection results of the plant total time-of-use meter code are all normal, the detection results of the plant metering device are determined to be normal; otherwise, the detection results of the plant metering device are determined to be abnormal.

10. A terminal device, characterized in that, It includes a processor, a memory, and a computer program stored in the memory and configured to be executed by the processor, wherein the processor executes the computer program to implement the remote detection method for a metering device as described in any one of claims 1 to 8.

Images