WO2019176312A1 - Power distribution network monitoring system - Google Patents

Abstract

This power distribution network monitoring system (10) has an LTLS (7), a reception part (53a), and a correction unit (56). The LTLS (7) has a detection and power supply part (71), a transmission part (76), and a counter part (75e). The detection and power supply part (71) is installed at each of a plurality of predetermined positions on a power line provided in a power distribution network (100), and performs electrical measurement of the power line at each of the predetermined positions by using the current that flows through the power line. The transmission part (76) transmits a result measured by the detection and power supply part (71). The counter part (75e) counts the number of transmissions made by the transmission part (76). The reception part (53a) receives the transmitted measurement result and the counter value. The correction unit (56) performs a correction of the measurement result on the basis of the counter value when there is timing at which a measurement result was not received by the reception part (53a).

Description

Distribution network monitoring system

The present invention relates to a distribution network monitoring system for detecting an abnormality in the distribution network.

In recent years, a meter reading device with a communication function has been installed in a power consumer linked to a power distribution system, and a system for receiving meter reading information from the meter reading device and managing power distribution equipment has been proposed (for example, see Patent Document 1).
In such a distribution facility management system, power lines are measured by the meter reading device and a DT meter unit provided beside the transformer house.

JP 2014-36482 A

However, in order to make a power generation plan, it is necessary to use an accurate amount of electricity. However, since it cannot be measured on the distribution network, it is difficult to obtain an accurate amount of electricity.
The subject of this invention is providing the distribution network monitoring system which can detect the information regarding the amount of electricity used accurately.

The distribution network monitoring system according to the first invention includes a measuring instrument, a receiving unit, and a correcting unit. The measuring instrument has a measurement unit, a transmission unit, and a counter unit. The measurement unit is installed at a plurality of predetermined positions of the power line provided in the distribution network, and performs electrical measurement of the power line using current flowing through the power line at each predetermined position. A transmission part transmits the measurement result by a measurement part. The counter unit counts the number of transmissions by the transmission unit. The receiving unit receives the transmitted counter value. The correction unit corrects the measurement result based on the counter value when there is an unreceived timing at which the measurement result is not received by the reception unit.

By using the counter value in this way, it is possible to determine whether or not to perform correction when the reception unit cannot receive the measurement result at a predetermined timing.
For example, since the counter value is transmitted together with the measurement result from the measuring instrument, the counter value before the unreceived timing at which the measurement result was not received is compared with the counter value after the timing at which the measurement result was not received. Is called. And if the measurement count counter value has changed, including the number of times the measurement result has not been received from the counter value before the unreceived timing to the counter value after it, the measurement can be performed by the measuring instrument. Therefore, it is possible to determine that the measurement result is accurate because only the reception has failed. In addition, if the measurement count value is not incremented, including the number of times the measurement result was not received from the counter value before the unreceived timing to the counter value after it, the measuring instrument is not transmitting. Therefore, it is determined that the measurement result obtained by the measuring instrument is not accurate, and the measurement result is corrected.

As described above, since the measurement result can be corrected based on the counter value, it is possible to improve the detection accuracy of the information regarding the amount of electricity used.
Note that the counter value only needs to know the number of transmissions, so it does not have to be incremented by one, for example, it may be incremented by two or three, or may be decremented. Any change that shows the number of measurements is sufficient.

A power distribution network monitoring system according to a second aspect of the present invention is the power distribution network monitoring system according to the first aspect of the present invention, and the measuring instrument has a calculation unit. The calculation unit calculates an integrated value of the current measured by the measurement unit. The measurement result includes the integrated value and time information related to the observation time corresponding to the integrated value. The correction unit corrects the observation time.
In this way, the integrated value can be obtained from the measuring instrument, and the accuracy of the observation time of the integrated value measured by the measuring instrument can be improved.

A distribution network monitoring system according to a third aspect of the present invention is the distribution network monitoring system according to the second aspect of the present invention, wherein the correction unit includes a determination unit and a calculation unit. The determination unit determines whether or not to correct the observation time based on the counter value when there is an unreceived timing at which the measurement result is not received by the reception unit. When performing the correction, the arithmetic unit performs correction by subtracting the non-reception time when the measurement result has not been received from the observation time.
Thereby, since the time when measurement is not performed by the measuring instrument can be subtracted from the observation time obtained from the received time information, the observation time can be calculated with high accuracy.

A power distribution network monitoring system according to a fourth aspect is the power distribution network monitoring system according to the third aspect, wherein the counter unit resets the counter value when the transmission unit cannot operate. The determination unit transmits the counter value transmitted after one or more unreceived timings when the counter value is not received from the counter value transmitted before the unreceived timing by the number of unreceived timings. If there is no change including, the determination is made to correct.
As described above, when the counter value is not incremented, for example, from the counter value before the unreceived timing to the counter value after the unreceived timing, transmission by the measuring device is performed. Therefore, it can be determined that the measurement by the measuring instrument is not completed. Therefore, the observation time can be calculated with high accuracy by performing correction.

A distribution network monitoring system according to a fifth aspect is the distribution network monitoring system according to the third aspect, wherein the counter unit resets the counter value when the transmission unit cannot operate. The determination unit transmits the counter value transmitted after one or more unreceived timings when the counter value is not received from the counter value transmitted before the unreceived timing by the number of unreceived timings. If it has changed, the determination is made not to perform correction.
In this way, when the counter value is increased, for example, including the number of times of unreceived timing from the counter value before the unreceived timing to the counter value after, the measurement by the measuring device is performed, Although transmission is also performed, it can be determined that reception is not possible. Therefore, an accurate observation time can be obtained without the need for correction.

A distribution network monitoring system according to a sixth aspect of the present invention is the distribution network monitoring system according to the third aspect of the present invention, further comprising a storage unit. The storage unit stores the counter value and the measurement result received by the receiving unit. The storage unit stores predetermined information indicating that the counter value has not been received when the counter unit has not received the counter value at the timing at which the counter value is scheduled to be received. The calculation unit calculates a non-reception time based on the number of predetermined information.

Thus, by storing predetermined information indicating that the counter value could not be received in the storage unit, it was possible to calculate the time when the measuring device could not be measured based on the number of the predetermined information, and to observe with high accuracy. You can ask for time.
In addition, as predetermined information, a numerical value, a symbol, etc. may be sufficient and it is not specifically limited, For example, zero can be mentioned.

A power distribution network monitoring system according to a seventh aspect of the present invention is the power distribution network monitoring system according to the sixth aspect of the present invention, wherein the storage unit corresponds the integrated value to the observation time after the correction when correction is performed. Add and remember.
Thereby, for example, an accurate observation time can be calculated from measurement results received from a plurality of measuring devices, and an integrated value and an observation time in the distribution network can be obtained with high accuracy.

A distribution network monitoring system according to an eighth aspect of the present invention is the distribution network monitoring system according to any one of the first to seventh aspects of the present invention, wherein the measuring device further includes a power feeding unit. The power supply unit supplies power to the measurement unit and the transmission unit using a current flowing through the power line. When the current flowing through the power line is equal to or less than a predetermined value, power is not supplied from the power supply unit to the measurement unit and the transmission unit.
Thereby, when disconnection occurs, the counter value cannot be transmitted from the transmission unit.
The predetermined value can be set to 2A, for example.

A distribution network monitoring system according to a ninth aspect of the present invention is the distribution network monitoring system according to any one of the first to eighth aspects of the present invention, further comprising a repeater. The repeater receives measurement results and counter values from a plurality of measuring devices and transmits them to the receiving unit.
As a result, the receiving unit can receive measurement results and counter values from a plurality of measuring devices via the repeater, and can accurately determine the integrated values and observation times of the power lines at a plurality of locations.

A distribution network monitoring system according to a tenth aspect of the present invention is the distribution network monitoring system according to the seventh aspect of the present invention, wherein the transmission unit transmits identification information unique to the measuring device together with the measurement result and the counter value. A memory | storage part matches and memorize | stores identification information and an installation place about a some measuring device. The power distribution network monitoring system further includes a section calculation unit. The interval calculation unit corresponds to the integrated value and the integrated value in the entire predetermined interval based on the integrated value of each measuring device and the observation time after correction, the identification information of each measuring device, and the installation location. Calculate the observation time.

Thus, since the installation location where the measuring device is installed is stored, the integrated value and the observation time can be obtained with high accuracy in the entire distribution network.
(The invention's effect)
ADVANTAGE OF THE INVENTION According to this invention, the distribution network monitoring system which can detect the information regarding electricity usage accurately can be provided.

The block diagram which shows the structure of the power distribution network monitoring system in embodiment concerning this invention. The figure which shows the installation place in the data collection repeater of FIG. 1, and the distribution network of LTLS. It is a block diagram which shows the structure of the data collection repeater and LTLS of FIG. The block diagram which shows the structure of the power management center of FIG. The flowchart which shows the operation | movement of LTLS of the power distribution network monitoring system of FIG. The figure which shows the setting information preserve | saved in management DB of the power management center of FIG. The figure which shows the storage table preserve | saved at management DB of the power management center of FIG. The figure which shows the positional infomation table preserve | saved in management DB of the power management center of FIG. FIG. 2 is a flowchart showing the operation of the LTLS in FIG. 1. The flowchart which shows operation | movement of the data collection repeater of FIG. The flowchart which shows operation | movement of the power management apparatus of FIG. The figure which shows the flow of the correction | amendment determination processing of FIG. The figure which shows an example of the history data introduced in the process of FIG. The figure which shows an example of the table produced in the process of FIG. The figure which shows an example of the history data introduced in the process of FIG. The figure which shows an example of the table produced in the process of FIG. The figure which shows an example of the state of each apparatus when abnormality generate | occur | produces in a power line. (A), (b) The figure for demonstrating the observation time calculation process in the power management apparatus of FIG. (A), (b) The figure for demonstrating the observation time calculation process in the power management apparatus of FIG. The figure for demonstrating the observation time calculation process in the power management apparatus of FIG. The flowchart which shows the observation time calculation process in the power management apparatus of FIG. The figure which shows the user setting item in the process of FIG. The figure which shows the data inquired in the process of FIG. The figure which shows the result data calculated in the process of FIG. The figure which shows the flow of the composite process in operation | movement of the power management apparatus of FIG. It is a figure which shows the power distribution network as an example of the object area in the process of FIG. The flowchart which shows operation | movement of the power management apparatus in the modification of embodiment concerning this invention. The figure which shows the flow of the correction | amendment determination processing of FIG. The figure which shows the user setting item in the process of FIG. The figure which shows the abnormality determination table in the process of FIG.

Below, the distribution network monitoring system which concerns on embodiment of this invention is demonstrated based on drawing.
<Configuration>
(Outline of distribution network monitoring system 10)
FIG. 1 is a block diagram showing a configuration of a power distribution network monitoring system 10 according to an embodiment of the present invention.

The distribution network monitoring system 10 in the embodiment according to the present invention is provided in the distribution network 100 shown in FIG. The distribution network monitoring system 10 monitors the distribution network system by using a plurality of LTLS (Low Tension Line Sensors) (an example of a measuring instrument) installed at predetermined positions of the distribution lines constituting the distribution network 100, and And the observation time corresponding to the current amount.
As shown in FIG. 1, the distribution network monitoring system 10 according to the present embodiment includes a power management center 5, a plurality of data collection relays 6 (an example of a relay), and a plurality of LTLSs 7.

The power management center 5 manages the power in each area, and calculates the amount of current used in the distribution network 100 (see FIG. 2) in the area and the observation time corresponding to the amount of current used.
As shown in FIG. 1, one or more data collection repeaters 6 are installed for each area, and collect data from a plurality of LTLSs 7.
The LTLS 7 is a power source (battery) -less type measuring instrument and is a type of current sensor using a CT power feeding method. The LTLS 7 is operated by a current flowing through the power line, and performs electrical measurement of the power line. A plurality of LTLSs 7 are installed for each electrical area flowing through the power line, and the current flowing through the power line is measured. Data relating to the current value of the power line measured by the LTLS 7 is sent to the power management center 5 via the data collection relay 6. As will be described in detail later, the power management center 5 calculates data indicating the measurement result of the current value and an observation time corresponding to the current amount.

Here, the area shown in FIG. 1 indicates, for example, an area transmitted from a predetermined substation or an area of a municipality such as a city or a town.
In each of the areas A-1... An, one data collection repeater 6 is provided for each area, and data of a plurality of LTLS 7 installed in one area is provided as one data collection repeater. 6 is collecting.

In the area B-1, a plurality of data collection repeaters 6 are provided, and a plurality of data collection repeaters 6 collect data of a plurality of LTLS 7 installed in one area. In the case of the area B-1, the plurality of LTLS 7 are divided into groups, and each data collection repeater 6 collects data of the plurality of LTLS 7 belonging to the group.
Only one data collection repeater 6 may be provided in the area, or a plurality of data collection repeaters 6 may be provided.

(Installation of data collection repeater 6 and LTLS7)
FIG. 2 is a diagram showing the installation locations of the data collection repeater 6 and the LTLS 7 in the power distribution network 100. In FIG. 2, a power pole 101 on the upstream side in the power transmission direction and a power pole 102 on the downstream side are shown, and the distribution lines 103, 104, 105 are arranged as three trunk lines constituting three phases of RTS between the power pole 101 and the power pole 102. Is over. Electricity flows in the direction from the utility pole 101 to the utility pole 102. The distribution line 103 is an R-phase distribution line, the distribution line 104 is an S-phase distribution line, and the distribution line 105 is a T-phase distribution line.

In addition, a distribution line 106 is branched from the distribution line 105 as a service line (branch line), and two distribution lines 107 are branched from the distribution line 106 as a house line, and are connected to the electrical equipment in the house 108.
The data collection repeater 6 is installed in each of the utility pole 101 and the utility pole 102. In order to make a distinction by location, the data collection repeater 6 installed on the utility pole 101 is designated 6a, and the data collection repeater 6 installed on the utility pole 102 is designated 6b.

The LTLS 7 is a clamp type and is detachably installed on a distribution line (an example of a power line). The LTLS 7 is installed in the vicinity of the utility pole 101 and in the vicinity of the utility pole 102 in each of the distribution lines 103, 104, and 105. Further, in FIG. 2, the LTLS 7 is installed on the distribution line 106.
Here, a to f are given to the codes of the LTLS 7 in order to distinguish them by places. The LTLS 7 installed near the power pole 101 of the distribution line 103 is 7a, the LTLS installed near the power pole 101 of the distribution line 104 is 7b, and the LTLS 7 installed near the power pole 101 of the distribution line 105 is 7c. To do. LTLS7 installed in the vicinity of the utility pole 102 of the distribution line 103 is 7d, LTLS7 installed in the vicinity of the utility pole 102 of the distribution line 104 is 7e, and LTLS7 installed in the vicinity of the utility pole 102 of the distribution line 105 is 7f. To do. Moreover, the LTLS7 installed in the distribution line 106 is 7 g.

In FIG. 2, the data of the LTLS 7a, 7b, 7c, and 7g is transmitted to the data collection repeater 6a, and the data of the LTLS 7d, 7e, and 7f is transmitted to the data collection repeater 6b. Communication between the LTLS 7 and the data collection repeater 6 is performed wirelessly as described later.
(LTLS7)
FIG. 3 is a block diagram showing the configuration of the data collection repeater 6 and the LTLS 7 in the area An.

As shown in FIG. 2, the LTLS 7 has a clip-type mounting structure and is detachably attached to the distribution lines 103, 104, 105, 106, and the like.
As illustrated in FIG. 3, the LTLS 7 includes a detection / power feeding unit 71, a measurement unit 72, a charging unit 73, a switching unit 74, a control unit 75, and a transmission unit 76.
The detection / power feeding unit 71 detects a magnetic flux generated when a current flows through the power line, and measures a current value flowing through the power line every predetermined time (for example, 10 seconds). The detection / power supply unit 71 converts magnetic flux into electrical energy, and supplies the converted electrical energy to the measurement unit 72, the control unit 75, and the transmission unit 76. Note that the detection / power supply unit 71 is switched by the switching unit 74 between supplying electric energy to the measurement unit 72, the control unit 75, and the transmission unit 76 and storing the electric energy in the charging unit 73.

The measuring unit 72 operates by feeding power from the detection / power feeding unit 71 and measures the electrical energy sent from the detection / power feeding unit 71. The measurement unit 72 is provided with a calculation unit (not shown), which calculates the effective value of the current from the detected current waveform.
The charging unit 73 is a capacitor or the like that temporarily stores electrical energy sent from the detection / power feeding unit 71, and when the power feeding from the detection / power feeding unit 71 stops, the measurement unit 72 and the transmission unit 76. To supply power.

The switching unit 74 is controlled by the control unit 75 so that the destination of the electrical energy sent from the detection / power feeding unit 71 is switched between the measurement unit 72 and the charging unit 73. Thereby, the electrical energy generated in the detection / power feeding unit 71 can be switched to be supplied to either the measurement unit 72 or the charging unit 73.
The control unit 75 controls each unit included in the LTLS 7 and controls the switching unit 74 to switch the supply destination of the electrical energy converted in the detection / power feeding unit 71. And the control part 75 transmits the integrated value which integrated the data of the current effective value measured in the measurement part 72 to the receiving part 61a of the data collection repeater 6 every predetermined time (for example, 5 minutes) progress. The transmitter 76 is controlled.

The control unit 75 includes a timer unit 75a, an arithmetic processing unit 75b, and a memory holding unit 75c. The timer unit 75a takes the timing of the measurement by the measurement unit 72 and the timing of the data communication interval by the transmission unit 76. The measurement unit 72 measures a current value at intervals of 10 seconds, for example, and the transmission unit 76 transmits data at intervals of 5 minutes, for example. The calculation processing unit 75b includes an integrated value calculation unit 75d and a counter unit 75e. The integrated value calculation unit 75d calculates the integrated value from the measurement value obtained by the measurement unit 72. The counter unit 75 e counts the number of data transmissions by the transmission unit 76. The memory holding unit 75c stores and stores the integrated value by the integrated value calculating unit 75d and the value of the communication number counter by the counter unit 75e.

The transmission unit 76 adds the ID (Identification) (an example of identification information) and time information unique to the LTLS 7 to the integrated value (an example of the measurement result) and the value of the communication count counter, and obtains data as measurement data, for example, every 5 minutes It transmits to the collection repeater 6. This measurement data is transmitted to the power management apparatus 51 via the data collection repeater 6. The time information, integrated value, transmission count counter value, and ID are transmitted in association with each other.

(Data collection repeater 6)
As shown in FIG. 3, the data collection repeater 6 includes a communication unit 61, a management DB (Data base) 62, and a communication unit 63.
The communication unit 61 communicates with a plurality of LTLS 7. The communication unit 61 includes a reception unit 61a and receives measurement data (sensor ID, counter value, and integrated value) transmitted from a plurality of LTLSs 7 by radio.

The management DB 62 stores and manages setting information 91 transmitted from the power management apparatus 51. FIG. 5 is a diagram showing the setting information 91.
In the setting information 91, the relay management code (A01_01) and time information of the data collection relay 6 are recorded. The setting information 91 is updated by storing the setting information received from the power management apparatus 51.

The communication unit 63 communicates with the power management device 51. The communication unit 63 includes a reception unit 63a and a transmission unit 63b. The receiving unit 63a receives a setting request from the power management apparatus 51 of the power management center 5. The setting request requests setting of the management code of the data collection repeater 6. The transmission unit 63b adds a relay management code (an example of relay identification information) to the measurement data (LTLSID, integrated value, counter value, and time information) received from the LTLS 7, and transmits the result to the power management center 5.

(Power Management Center 5)
As shown in FIG. 1, the power management center 5 includes a power management device 51 and a display / input unit 52. The power management apparatus 51 uses the measurement information received from the data collection repeater 6 to calculate an integrated value of current in the distribution network and an observation time corresponding to the integrated value. The display / input unit 52 inputs a data confirmation section when the user calculates the observation time.

FIG. 4 is a block diagram showing the configuration of the power management center 5 and the maintenance management center 4. As shown in FIG. 4, the power management apparatus 51 includes a communication unit 53, a management DB 54 (an example of a storage unit), a correction unit 56, a section calculation unit 57, a timer unit 58, a counter setting unit 59, Have
The communication unit 53 communicates with the data collection repeater 6. The communication unit 53 includes a reception unit 53a and a transmission unit 53b. As shown in FIG. 1, the receiving unit 53a receives the sensor ID, time information, integrated value, communication count counter value, and repeater management code transmitted from the transmitting unit 63b of the plurality of data collection repeaters 6. The transmission unit 53b transmits a setting request to each data collection repeater 6.

The management DB 54 stores setting information 92, a storage table 93, and a location management information table 94. FIG. 6 is a diagram showing the setting information 92. FIG. 7 is a diagram showing the storage table 93. FIG. 8 is a diagram showing the location management information table 94.
The setting information 92 includes the relay management code of the data collection repeater 6 provided in each area code, the LTLSD of the LTLS 7 for collecting data in each data collection repeater 6, and further includes time information. It is. For example, the setting information 92 includes relay management codes (A01_01,..., A01_n) and (A02_01, A02_02,..., A02_n) corresponding to the area code (A01) and area code (A02), LTLSID ( 001, 002,..., 00n) and (001, 002,..., 00n) and time information (2018/2/7/10: 00: 00).

For example, in the area code A01, the data collection repeater 6 with the relay management code A01_01 collects data from the LTLS 7 with the LTLSID of 001 and 002. In the area code A02, the data collection repeater 6 with the relay management code A02_01 collects data from the LTLS7 with the LTLSID of 001, and the data collection repeater 6 with the relay management code A02_02 collects the data from the LTLS7 with the LTLSID of 002. collect.

The storage table 93 includes a relay management code provided for each area code, an LTLSID of the LTLS 7 from which the data collection repeater 6 having each relay management code collects data, a measurement time and an integrated value of each LTLS 7. And a communication counter. For example, the storage table 93 includes an integrated value from the time 11:00 to 12:00 of the LTLS 7 in which LTLSID is 001 and a communication count counter.

The communication number counter is incremented as described later each time communication is performed, but the setting information 92 also indicates a value of 0 (zero). The value of 0 (zero) in the communication number counter is a counter setting unit 59 (described later) when the power management apparatus 51 does not receive measurement data at the timing at which measurement data is to be received from the data collection repeater 6. ) Is stored.

Further, the storage table 93 includes a flag Cd. The flag Cd is attached to data in which the measured data counter value is 0 (zero), measurement data cannot be received due to disconnection, and current value measurement by the LTLS 7 is not performed. Data whose flag Cd is not attached when the value of the communication counter is 0 (zero) is data for which it is determined that the LTLS 7 is operating because the measurement data cannot be received due to a communication error. Based on the flag Cd, the measurement result is corrected.

Each time the measurement information and the relay management code of the LTLS 7 are received from the data collection repeater 6, the latest measurement information is sequentially stored in the storage table 93.
In the position management information table 94, each installation location of the plurality of LTLSs 7 is stored as a position code, and a relay management code of the data collection relay 6 that collects data from each LTLS 7 is also stored. Thereby, the position of each LTLS 7 can be confirmed.

The setting information 92, the storage table 93, and the location management information table 94 are updated when new information is received.
The correction unit 56 corrects the measurement result based on the value of the communication number counter stored in the management DB 54 and calculates the observation time of the integrated value. The correction unit 56 includes a determination unit 56a and a calculation unit 56b.

The determination unit 56a determines whether or not to perform correction based on the value of the communication number counter. Whether the determination unit 56a adds the flag Cd to the data whose communication counter value is 0 (zero) and excludes it from the observation time, or does not add the flag Cd and does not exclude it from the observation time. Determine whether. That is, it is determined whether or not the LTLS 7 is operating for data whose communication counter value is 0 (zero). If it is determined that the LTLS 7 is not operating, the flag Cd is added to the measurement data. When it is determined that the LTLS 7 is operating, the flag Cd is not given to the measurement data.

The calculation unit 56b calculates the true observation time by subtracting the time corresponding to the data to which the flag Cd is given by the determination unit 56a from the observation time based on the received measurement data.
The section calculation unit 57 specifies the ratio of the observation time in the target section based on the integrated value of the plurality of LTLS7, the true observation time, and the information regarding the installation location of each LTLS7.
The timer unit 58 checks whether or not measurement data is transmitted from the data collection repeater 6 at a reception timing every 5 minutes.

When the counter setting unit 59 detects that the measurement data is not received at the timing scheduled to be received by the timer unit 58, the counter setting unit 59 sets the communication number counter at the reception timing to 0 (zero) and stores it in the management DB 54. . For example, at time 11:30 in FIG. 7, since the measurement data is not received from the LTLS 7 via the data collection repeater 6, the communication number counter is set to 0. At this time, since the integrated value data is not received, an integrated value 110 of 11:25, which is the reception timing immediately before 11:30, is stored as the integrated value.

<Operation>
The operation of the distribution network monitoring system 10 in the embodiment according to the present invention will be described below.
(Operation of LTLS7)
FIG. 9 is a flowchart showing the operation of the LTLS 7 of the distribution network monitoring system 10 of the present embodiment.

The LTLS 7 is activated and waits until a predetermined time (for example, 10 seconds) elapses in step S11. During this predetermined time, charging is performed and electric energy is stored in the charging unit 73.
Next, when a predetermined time has elapsed, in step S12, the control unit 75 determines whether or not the current flowing through the power line is 2A or more. Here, when 2 A or more, the LTLS 7 is operable, but when smaller than 2 A, charging cannot be performed and the LTLS 7 cannot operate.

If it is determined in step S12 that the current is 2 A or more, the current flowing through the power line is measured by the detection / power feeding unit 71 and the measurement unit 72 in step S13.
Next, in step S14, the timer unit 75a of the control unit 75 determines whether 5 minutes have elapsed.
If it is determined in step S14 that 5 minutes have not elapsed, the control returns to step S11 and waits for the next measurement. Thus, the current value of the power line is measured every predetermined time (for example, 10 seconds) until 5 minutes elapse.

If it is determined in step S14 that 5 minutes have elapsed, in step S15, the integrated value calculation unit 75d calculates the integrated value of the current value.
Next, in step S <b> 16, the integrated value, the communication count counter, and LTLSID are transmitted to the data collection repeater 6.
Next, in step S17, the counter unit 75e increments the communication number counter. For example, when the first transmission is performed in step S13, the value of the communication number counter is transmitted as 1, and after the transmission, the value of the communication number counter is incremented to 2.

After step S17, control returns to step S11, and the LTLS 7 enters a measurement standby state. Thereby, the LTLS 7 measures the current of the power line every 10 seconds and transmits the integrated value, the counter value, and the LTLSID to the data collection repeater 6 every 5 minutes.
In step S12, if the current flowing through the power line is smaller than 2A, the control proceeds to step S18, the LTLS 7 is shut down, and at that time, the counter unit 75e resets the communication number counter value, and the communication number counter Returned to 1. The power management apparatus 51 can determine whether or not the LTLS 7 has been shut down by the communication number counter.

(Operation of data collection repeater 6)
FIG. 10 is a flowchart showing the operation of the data collection repeater 6 of the distribution network monitoring system 10 of the present embodiment.
When the process starts, in step S21, the data collection repeater 6 enters a reception standby state.

Next, in step S22, it is determined whether or not measurement data is received. If measurement data is received from the LTLS 7, the measurement data is received in step S23. That is, the data collection repeater 6 is in a standby state until data is received.
Next, in step S24, the data collection repeater 6 adds the relay management code (A01_01) extracted from the management DB 62 to the measurement data and transmits the measurement data to the power management apparatus 51.

Thus, the data collection repeater 6 transmits the measurement data sent every 5 minutes to the power management apparatus 51 every 5 minutes.
(Operation of the power management device 51)
FIG. 11 is a flowchart showing the operation of the power management device 51 of the distribution network monitoring system 10 of the present embodiment.

When the process starts, in step S31, the power management apparatus 51 enters a reception standby state.
Next, in step S32, it is determined whether or not measurement data has been received. If the reception unit 53a receives measurement data from the data collection repeater 6, the measurement data is received and measurement data is received in step S33. Are stored in the storage table 93 of the management DB 54.

Next, in step S34, the determination unit 56a of the correction unit 56 performs a correction determination process. The correction determination process is a process for determining whether or not the observation time includes the time when the measurement data cannot be received. In the correction determination process, the above determination is made based on whether or not the LTLS 7 was operating when the measurement data could not be received. Details will be described later.
After the process of step S34, control returns to step S31.

On the other hand, if the receiving unit 53a has not received data in step S32, the timer unit 58 determines in step S35 whether or not 5 minutes have elapsed. In step S32, it is determined whether or not the measurement data is received at the reception timing for receiving the measurement data.
If 5 minutes has not elapsed in step S35, the control returns to step S31, and the power management apparatus 51 enters a standby state.

On the other hand, if 5 minutes have passed in step S35, the counter setting unit 59 sets the communication counter to 0 in step S36, assuming that the measurement data could not be received at the scheduled reception timing, Store in the management DB 54. After the process of step S36, control returns to step S31, and the power management apparatus 51 enters a standby state.
(Correction judgment processing)
Next, the correction determination process in step S34 will be described. The correction determination process is started with the measurement data stored in the management DB 54 in step S33 as a trigger.

FIG. 12 is a diagram illustrating a flow of the correction determination process.
When the process starts, first, in step S61, the determination unit 56a introduces the history of the LTLS 7 having the same ID from the storage table 93. FIG. 13 is a diagram illustrating an example of introduced history data 200. FIG. 13 shows the measurement time, integrated value (data Ah), and communication number counter of LSLT 7 whose LSLT ID is 001. FIG. 13 shows history data 200 from 11:00 to 12:00.

Next, in step S62, the determination unit 56a extracts data until the communication count counter is other than 0 except for the latest received data, and creates the table 201. FIG. 14 is a diagram showing the table 201. In the table 201, data up to 11:45 where the communication number counter is other than 0 (zero) is extracted from the history data 200 except the latest received data at 12:00. End data (11:45 data) is set as IDgood.

Next, in step S63, the determination unit 56a counts the number of times the communication number counter is 0 (zero) in the extracted data range table 201, and sets it as Cn.
Next, in step S64, the determination unit 56a determines whether or not Cn is equal to or greater than 0. If Cn is equal to or greater than 0, that is, in the extracted data range table 201, the communication number counter is 0 (zero). ) Exists, control proceeds to step S66.

In step S65, the determination unit 56a sets the value of the latest reception data communication counter to IDnew. In the example shown in FIG. 14, since the latest received data is 12:00 data, IDnew is set in the data flag of 12:00.
Next, in step S66, the determination unit 56a determines whether or not IDnew− (Cn + 1) = IDgood. In the example illustrated in FIG. 14, the IDnew communication count counter is 23, Cn = 2, and the IDgood communication count counter is 20. Therefore, IDnew− (Cn + 1) = 23− (2 + 1) = 20, which matches IDgood. Therefore, the control proceeds to step S67, and the determination unit 56a determines that the measurement data could not be received due to a communication abnormality or the like although the LTLS 7 is operating normally.

That is, even when the power management apparatus 51 is not receiving, if the LTLS 7 is operating normally, transmission is performed and the communication counter is incremented. For this reason, when the communication number counter at the timing at which reception is possible has been incremented by the number of times at which reception was not possible from the communication number counter immediately before the timing at which reception is not possible, the LTLS 7 is transmitting, It can be determined that the power management apparatus 51 has failed to receive due to a communication failure or the like.

On the other hand, if IDnew− (Cn + 1) = IDgood is not satisfied in step S66, the control proceeds to step S68, and the determination unit 56a cannot receive measurement data because the LTLS7 has not been operated due to the occurrence of a power line disconnection or the like. It is determined that
A case where it is determined that the LTLS 7 has not been operated will be described using data of another example. FIG. 15 is a diagram illustrating an example of the history data 202 introduced in step S61 when it is determined that the power line is disconnected. FIG. 15 shows history data 202 from 11:00 to 12:00. Next, in step S62, the determination unit 56a extracts data until the communication count counter is other than 0 except for the latest received data, and the table 203 shown in FIG. 16 is created. In the table 203, data up to 11:45 is extracted from the history data 202, except for the latest received data at 12:00, in which the communication count counter is other than 0 (zero). Then, the communication number counter of the end data (11:45 data) is set as IDgood.

Next, in step S63, the determination unit 56a counts the number of times the communication number counter is 0 (zero) in the extracted data range table 203, and sets it as Cn.
Next, in step S64, the determination unit 56a determines whether or not Cn is equal to or greater than 0. If Cn is equal to or greater than 0, that is, in the extracted data range table 203, the communication number counter is 0 (zero). ) Exists, control proceeds to step S66.

In step S66, the determination unit 56a sets the value of the latest reception data communication count counter to IDnew. In the example shown in FIG. 16, since the latest received data is 12:00 data, IDnew is set in the data flag of 12:00.
Next, in step S66, the determination unit 56a determines whether or not IDnew− (Cn + 1) = IDgood. In the example illustrated in FIG. 16, the IDnew communication count counter is 1, Cn = 2, and the IDgood communication count counter is 20. Therefore, IDnew− (Cn + 1) = 1− (2 + 1) = − 2, which does not match IDgood. Therefore, the control proceeds to step S68, and the determination unit 56a determines that the LTLS 7 has not been operated.

That is, when the LTLS 7 is not operating, the measurement number counter value is reset. Therefore, if the communication counter at the timing at which reception is possible has not been incremented by the number of times at which communication could not be received from the communication counter immediately before the timing at which reception is not possible, the LTLS 7 is not operating due to power line disconnection, etc. Can be determined.

Next, in step S70, the determination unit 56a adds the flag Cd to the measurement data determined to have not been operated by the LTLS 7, and stores the measurement data in the storage table 93.
After steps S67, S70, and S69, the control returns to step S31 shown in FIG. 11, and the power management apparatus 51 enters a reception standby state.
Next, the reason for determining whether or not the LTLS 7 was operating based on the value of the communication number counter will be described in more detail.

FIG. 17 is a diagram illustrating an example of the state of each device when an abnormality occurs. In FIG. 17, at time 9:00, the integrated value 100Ah of the current measured by the LTLS 7 for the previous 5 minutes and the value (1) of the number of times of measurement counter are transmitted to the data collection repeater 6, and the data collection repeater 6 The integrated value 100Ah and the measurement counter value (1) are transmitted to the power management apparatus 51. At time 9:00, the power management apparatus 51 receives the integrated value 100Ah and the value (1) of the measurement number counter, and stores them in the storage table 93 together with the LTLSID and the relay management code. In FIG. 17, it is assumed that there is no time lag due to transmission / reception for easy understanding.

In the next 5 minutes, the LTLS 7 measures 40 Ah, and the integrated value 140 Ah combined with 100 Ah for the previous 5 minutes and the incremented measurement count counter value (2) are sent via the data collection relay 6 at time 9:05. To the power management apparatus 51. The power management apparatus 51 receives the integrated value 140Ah and the incremented measurement number counter value (2).
At time 9:10, which is the next reception timing, the power management apparatus 51 has not received the integrated value and the measurement count counter value from the data collection repeater 6. Therefore, the power management apparatus 51 stores the integrated value 140Ah and a value of 0 as the measurement number counter in the storage table 93.

At time 9:15, which is the next reception timing, the power management apparatus 51 receives the integrated value 300Ah and the value (4) of the measurement number counter.
When applied to the equation of step S66 described in FIG. 12, IDnew = 4 (counter value at 9:15), IDgood = 2 (counter value at 9:05), and Cn = 1, so IDnew− (Cn + 1) = 4- (1 + 1) = 2, which matches IDgood.

That is, as shown in FIG. 17, it can be seen that the LTLS 7 has normally incremented the measurement counter value from (2) to (3) at time 9:10. For this reason, between time 9:05 and 9:15, the LTLS 7 normally measures the current value and transmits data at time 9:10, but the data does not reach the power management apparatus 51. It can be confirmed that the measurement data could not be received due to the occurrence of a communication failure or the like.

At time 9:20, the power management apparatus 51 receives the integrated value 400Ah and the measurement count counter value (5). However, at time 9:25 and time 9:30, the power management apparatus 51 does not receive data. First, at time 9:35, the integrated value 450Ah and the measurement counter value (1) are received. Here, if it is applied to the equation of step S66 described in FIG. 12, IDnew = 1 (counter value at 9:35), IDgood = 5 (counter value at 9:20), and Cn = 2, so IDnew− (Cn + 1) = 1− (2 + 1) = − 2, which does not match IDgood. That is, as shown in the operation of the LTLS 7 in FIG. 17, it can be seen that the communication number counter value is reset between 9:20 and 9:35. Since the reset of the communication counter value is performed by the shutdown in step S18 when the current value is smaller than 2A, it can be determined that the LTLS 7 has not been operated due to the occurrence of a disconnection or the like.

As described above, when the integrated value and the measurement number counter value cannot be received at the reception timing every 5 minutes, it is possible to determine whether or not the LTLS 7 has been operated based on the value of the measurement number counter immediately before and after that. .
(Observation time calculation process)
First, after describing the necessity of correcting measurement data, the operation in the observation time calculation process will be described.

FIG. 18A is a graph showing an example of the relationship between the integrated value and the observation time when there is no unreceived timing at which no measurement data is received at the data confirmation time T0. FIG. 18B is a diagram illustrating a correspondence relationship between the integrated value and the observation time when there is no unreceived timing at which measurement data is not received. 18A and 18B, the integrated value and the observation time in the measurement data received by the power management apparatus 51 correspond to each other. For example, in the data shown in FIG. 17, the integrated value received at 9:00 is the integrated value of current for 5 minutes from 8:55 to 9:00, and the integrated value received at 9:05 is 8: It is the integrated value of current in 10 minutes from 55 to 9:05.

As described above, when there is no non-reception timing at which the measurement data is not received, the integrated value received by the power management apparatus 51 is the integrated value of the current at the observation time obtained from the time information when the integrated value is received. It has become.
On the other hand, if there is an unreceived timing at which the measurement data is not received at the data confirmation time T0, as described above, it is determined whether the LTLS 7 is operating.

As shown at time 9:10 in FIG. 17, when the measurement number counter is incremented including the timing when measurement data cannot be received, the LTLS 7 operates normally and the integrated value is calculated. The integrated value 300Ah received at 9:15 is an integrated value of current for an observation time of 20 minutes from 8:55 to 9:15.
However, if the measurement number counter is not incremented including the timing at which measurement data could not be received as shown at times 9:25 and 9:30 in FIG. 17, the LTLS 7 does not operate normally and the integrated value Therefore, the accumulated value 450Ah received at 9:35 is not the accumulated value of the current for the observation time of 40 minutes from 8:55 to 9:35. Therefore, the observation time of the integrated value 450Ah needs to be subtracted from 40 minutes by the time during which the LTLS 7 is not operating (10 minutes).

That is, since the current value is calculated as an integrated value, it increases even if there is an unmeasurable interval, so it can be measured at the data confirmation time T0 shown in FIGS. 19 (a) and 19 (b). There are no section T1 and sections T2-1 and T2-2 in which true values can be measured. Thus, the data confirmation time T0 may include a time that cannot be measured due to disconnection or the like.

Therefore, as shown in FIG. 20, the interval T0 ′ (= T2-1 + T2-2) in which the integrated value A0 ′ (= A0) can be measured by subtracting the interval T1 that cannot be measured from the data confirmation time T0. The time (true observation time T0 ') using the current corresponding to the measured integrated value can be obtained.
Next, the flow of the observation time calculation process will be described. FIG. 21 is a flowchart showing the observation time calculation process.

First, in step S81, the user sets a data confirmation section in which the observation time is arbitrarily calculated from the display / input unit 52. FIG. 22 is a diagram showing setting items 301 by the user. As shown in FIG. 22, the start time and the end time are input as the data confirmation section T0. In FIG. 22, 11:00 is input as the start time and 12:00 is input as the end time.

Next, in step S82, the calculation unit 56b inquires data of the T0 section of the storage table 93 of the management DB 54. FIG. 23 is a diagram showing data in the T0 section inquired from the storage table 93 of the management DB 54. As shown in FIG.
Next, in step S83, the calculation unit 56b calculates a deletion time T1 to be deleted from the data confirmation interval using an expression of Cd × transmission time = T1. In the example shown in FIG. 23, since Cd = 3 and the transmission time is every 5 minutes, 3 × 5 = 15 (minutes) is calculated.

Next, in step S84, the calculation unit 56b subtracts the deletion time T1 from the data confirmation interval T0 (calculates T0-T1) to calculate the observation time T0 ′.
Next, in step S85, the calculation unit 56b stores the calculated observation time in the management DB 54. FIG. 24 is a diagram showing the result data 303 stored in the management DB 54. The result data 303 shows the measured LSLTID of the LSLT 7, the data confirmation interval T0, the number of Cd, the deletion time T1, and the observation time T0 ′.

Thus, it is calculated that the current integrated value 140Ah (190-50) in the data confirmation section T0 = 60 minutes until 11:00 or 12:00 is a value obtained at the observation time T0 ′ = 45 minutes. it can.
If the flag Cd is not included in the inquiry data 302, T1 = 0, and the data confirmation section T0 matches the observation time T0 ′ of the integrated value.

(Composite processing)
Next, composite processing in the power management apparatus 51 will be described.
FIG. 25 is a diagram illustrating a flow of composite processing of the power management apparatus 51.
When the composite processing is started, in step S71, the section calculation unit 57 collects the result data 303 of each of the plurality of LTLSs 7 belonging to the target section. The target section is input by the user using the display / input unit 52.

FIG. 26 is a diagram illustrating a power distribution network 100 as an example of a target section. In FIG. 26, the plurality of distribution lines 103 as the trunk line described in FIG. 2, the plurality of distribution lines 106 as service lines, the plurality of distribution lines 107 as house lines, and the house 108 are shown. For example, the power distribution network 100 shown in FIG. 26 is one area. The LTLS 7 installed on the distribution line 103 is indicated as Lt1 to Lt6. The LTLS 7 installed on the distribution line 106 is indicated as Ls1 to Ls5. The LTLS 7 installed in the distribution line 107 is indicated as Lh1 to Lh5.

For example, the section calculation unit 57 uses the result data 303 obtained from the data confirmation sections 11:00 to 12:00 of Lt1 to Lt6, Ls1 to Ls5, and Lh1 to Lh5 shown in the power distribution network 100 of FIG. collect.
Next, the section calculation unit 57 calculates the ratio of the observation time T0 ′ in the target section to the data confirmation section T0. In the distribution network 100 shown in FIG. 26, the current value of R is the current value of Lt1, the current value of Lt2, the current value of Lt3, the current value of Lt4, the current value of Lt5, and the current value of Lt6. It is the sum of the values. The current value of Lt1 is a value obtained by adding the current value of Ls1, the current value of Ls2, the current value of Ls3, the current value of Ls4, and the current value of Ls5. The current value of Ls5 is a value obtained by adding the current value of Lh1, the current value of Lh2, the current value of Lh3, the current value of Lh4, and the current value of Lh5.

Using these relationships, for example, the ratio of the observation time T0 ′ to the total data confirmation interval T0 of the R phase can be calculated.
Next, the section calculation unit 57 causes the display / input unit 52 to display the ratio of the observation time T0 ′ to the data confirmation section T0 in the target section together with the integrated value of the entire R phase. Similar to the R phase, the total ratio in the T phase and the S phase can be calculated.

Thereby, the usage amount (integrated value) in the power distribution network 100 and the time during which the current corresponding to the usage amount is used can be calculated with high accuracy, and a power generation plan can be made with high accuracy.
For this reason, the power distribution network monitoring system 10 of the present embodiment is also useful for a smart city where a smart home or the like provided with a smart meter is set up.
[Other Embodiments]
As mentioned above, although one Embodiment of this invention was described, this invention is not limited to the said embodiment, A various change is possible in the range which does not deviate from the summary of invention.

(A)
In the above embodiment, the correction determination process is performed based on the communication count counter value. However, the present invention is not limited to this, and the correction is also performed based on the number of the communication count counter on the management DB 54 being 0 (zero). A determination as to whether or not to do so may be made.
FIG. 27 is a flowchart showing the process of the management DB 54 to which step S37 of the correction determination process based on the number of 0 (zero) on the management DB 54 is added. As illustrated in FIG. 27, the correction determination process in step S <b> 37 is started by using the communication count counter value stored in step S <b> 36 as 0 (zero) as a trigger.

FIG. 28 is a diagram showing a flow of correction determination processing based on the number of 0 (zero) on the management DB 54.
When the process starts, first, in step S41, the determination unit 56a reflects the setting by the user. The setting is input in advance from the display / input unit 52 by the user. FIG. 29 is a diagram illustrating settings by the user. The setting (i) includes a target period in which it is determined that the LTLS 7 has not been moved due to disconnection of the power line or the like, and a threshold (the number of consecutive 0 data (X)). In FIG. 29, the target period of setting (i) is set to 30 minutes, and the threshold is set to 3 times.

Next, in step S42, the determination unit 56a introduces the history of the LTLS 7 having the same ID. An example of the history data of the LTLS 7 having the same ID is data as shown in FIG.
Next, in step S43, the determination unit 56a creates the determination table 97 on the management DB 54. FIG. 30 is a diagram showing the determination table 97 in the setting (i).

The extracted data table 97a of the determination table 97 shows LTLSID, the integrated value in the period of setting (i), and the communication count counter. The continuous 0 data table 97b shows the maximum number M0 of continuous 0 (zero) in the period of setting (i) and the setting value (X).
Next, in step S44, the LTLS7 non-operation determination process is started, and in step S45, the determination unit 56a extracts data for the period of setting (i) from the latest storage table, and the extracted data of the determination table 97 This is reflected in the table 97a. FIG. 30 is a diagram showing a determination table 97 created based on the setting (i) shown in FIG. 29 and reflecting data from 11:30 to 12:00. In the extracted data table 97a shown in FIG. 30, the integrated value and the communication count counter from 11:30 to 12:00 of the LTLS 7 with the LTLSID of 001 are shown starting from the latest data reception time of 12:00. Since the target period is set to 30 minutes in the setting (i), the determination table 97 is updated every 30 minutes. Specifically, the history is referred to when the reception timing reaches 12:00, and the determination table 97 is created from the measurement data from 11:30 to 12:00.

Next, in step S46, the determination unit 56a extracts the maximum number (M0) of 0 (zero) when the communication number counter is continuously 0 (zero) from the extraction data table 97a, This is reflected in the continuous 0 data table 97b of the determination table 97. In the extracted data table 97a of FIG. 30, since the communication counter of 11:50, 11:55, and 12:00 is 0 (zero), the maximum number M0 of consecutive 0s is 3 times.

Next, in step S47, the determination unit 56a compares the set value X in the setting (i) with the maximum number M0 and determines whether M0 is equal to or greater than X. When M0 is equal to or greater than X, the determination unit 56a determines that the LTLS 7 has not moved due to a disconnection of the power line or the like. In the example illustrated in FIG. 30, M0 is 3 times and is equal to or greater than 3 that is the set value of X, and therefore the determination unit 56a determines that the LTLS 7 has not moved.

Therefore, in the next step S48, the flag Cd is written in the data with the communication counter value of 0 and stored in the storage table 93.
On the other hand, if M is smaller than X in step S47, even if the value of the communication counter is 0, it is considered intermittent because it is intermittent, and the correction is performed without adding the flag Cd. The determination process ends.

Thus, when the case where the power management apparatus 51 cannot receive data at the timing of every 5 minutes continues for a predetermined number of times or more, it can be determined that the LTLS 7 has not been operated, and the flag Cd is added. be able to. As a result, the true observation time T0 ′ can be obtained by deleting from the data confirmation section T0 as the time T1 when the time to which the flag Cd is given could not be measured.
In FIG. 27, two determination processes (step S34 and step S37) are performed by the determination unit 56a, but only one of them may be performed.

(B)
In the distribution network monitoring system 10 of the above embodiment, the measurement information of the LTLS 7 is once collected by the data collection repeater 6 and then transmitted to the power management device 51, but this is not a limitation.
For example, the data collection repeater 6 may not be provided in the distribution network monitoring system 10, and in this case, the measurement information is directly transmitted from the LTLS 7 to the power management apparatus 51 via the radio.

(C)
In the above embodiment, when data is not received at the timing of data reception, the power management apparatus 51 stores a value of 0 in the communication count counter as an example of the predetermined information, but is limited to a value of 0. There may be no value, a value that is not used in the communication counter, a symbol, or the like. In short, it is only necessary to store information that can detect that data is not received.

(D)
In the above-described embodiment, the power management device 51 is provided with the correction unit 56 and the power management device 51 determines the correction. However, the present invention is not limited to this.
For example, the correction unit 56 may be provided in the data collection relay device 6 and the correction determination may be performed by the data collection relay device 6. Further, only the result data calculated by the data collection repeater 6 may be transmitted from the data collection repeater 6 to the power management apparatus 51.

(E)
In the above embodiment, the LTLS 7 that measures current is used, but a sensor that can measure voltage may be used. Thereby, since a value can be made to correspond with an electric power meter, and consistency with a meter can be aimed at, accuracy can be improved more.
(F)
The LTLS 7 of the above embodiment cannot operate when the current is smaller than 2A, but a sensor that can measure from 0A may be used. Thereby, the accuracy of the measurement data can be ensured without correcting the time when the power line smaller than 2A is disconnected.

(G)
The LTLS 7 of the above embodiment performs only transmission, but may be bidirectional communication with the data collection repeater 6. Thereby, a reception error can be detected, and measurement data can be retransmitted.
(H)
In the above embodiment, as shown in FIG. 14 and FIG. 16, the correction determination is performed using the communication number counter value immediately before and after the measurement data whose communication number counter value is 0 (zero). It is not limited to immediately before and immediately after, using the value of the communication number counter before (for example, two before) and after (for example, two after) the measurement data whose communication number counter is 0 (zero). Also good. In this case, when the value of the subsequent communication number counter is incremented from the value of the previous communication number counter including the number of 0 (zero), it is determined that the communication is abnormal, and the value is incremented. If not, it can be determined that a disconnection has occurred.

(I)
In the above embodiment, the control method and the observation time detection method of the distribution network monitoring system are controlled according to the flowcharts shown in FIGS. 9, 10, 11, 12, 21, 25, 27, and 28. In addition, although an example in which the observation time detection method is implemented has been described, the present invention is not limited to this.

For example, as an observation time detection program for causing a computer to execute an observation time detection method implemented according to the flowcharts shown in FIGS. 9, 10, 11, 12, 21, 21, 25, 27, and 28, the present invention is It may be realized.
In addition, one usage form of the observation time detection program may be an aspect in which the program is recorded on a recording medium such as a ROM readable by a computer and operates in cooperation with the computer.

Also, one use form of the observation time detection program is an aspect in which it is transmitted through a transmission medium such as the Internet or a transmission medium such as light, radio wave, and sound wave, read by a computer, and operated in cooperation with the computer. Also good.
The computer described above is not limited to hardware such as a CPU, and may include firmware, an OS, and peripheral devices.

As described above, the observation time detection method may be realized by software or hardware.

The distribution network monitoring system of the present invention has an effect of being able to detect information on the amount of electricity used with high accuracy, and is useful in performing maintenance management and the like in making a power generation plan and the like.

7 LTLS
DESCRIPTION OF SYMBOLS 10 Distribution network monitoring system 53a Receiving part 56 Correction | amendment part 71 Detection and electric power feeding part 75e Counter part 76 Transmission part 100 Distribution network

Claims (10)

1. A measurement unit that is installed at a plurality of predetermined positions of a power line provided in a distribution network and performs electrical measurement of the power line using current flowing through the power line at each of the predetermined positions, and a measurement result by the measurement unit A transmission unit for transmitting, and a counter unit for counting the number of transmissions by the transmission unit, wherein the transmission unit transmits a counter value together with the measurement result,
   A receiving unit that receives the transmitted measurement result and the counter value;
   A correction unit that corrects the measurement result based on the counter value when there is an unreceived timing at which the measurement result is not received by the reception unit;
   Power distribution network monitoring system with
2. The measuring device has a calculation unit that calculates an integrated value of the current measured by the measurement unit,
   The measurement result includes the integrated value and information related to an observation time corresponding to the integrated value,
   The correction unit corrects the observation time;
   The power distribution network monitoring system according to claim 1.
3. The correction unit is
   A determination unit that determines whether to correct the observation time based on the counter value when there is an unreceived timing at which the measurement result is not received by the reception unit;
   When performing the correction, and having a calculation unit that performs correction to subtract the non-reception time in which the measurement result was not received from the observation time,
   The power distribution network monitoring system according to claim 2.
4. The counter unit resets the counter value when the transmission unit cannot operate,
   The determination unit
   The counter value transmitted after one or more unreceived timings when the counter value was not received is the number of times of the unreceived timing from the counter value transmitted before the unreceived timing. If there is no change including the minute, determine to perform the correction,
   The distribution network monitoring system according to claim 3.
5. The counter unit resets the counter value when the transmission unit cannot operate,
   The determination unit
   The counter value transmitted after one or more unreceived timings when the counter value was not received is the number of times of the unreceived timing from the counter value transmitted before the unreceived timing. If it has changed including the minute, it is determined not to perform the correction,
   The distribution network monitoring system according to claim 3.
6. A storage unit for storing the counter value and the measurement result received by the reception unit;
   In the storage unit, when the counter value is not received by the receiving unit at a timing at which the counter value is scheduled to be received, predetermined information indicating that the counter value has not been received is stored.
   The calculation unit calculates the unreceived time based on the number of the predetermined information.
   The distribution network monitoring system according to claim 3.
7. When the correction is performed, the storage unit stores the integrated value and the corrected observation time in association with each other.
   The power distribution network monitoring system according to claim 6.
8. The measuring device further includes a power supply unit that supplies power to the measurement unit and the transmission unit using a current flowing through the power line,
   When the current flowing through the power line is equal to or less than a predetermined value, power is not supplied from the power supply unit to the measurement unit and the transmission unit.
   The distribution network monitoring system according to any one of claims 1 to 7.
9. A relay that receives the measurement results and the counter values from a plurality of the measuring devices and transmits the results to the receiving unit;
   The distribution network monitoring system according to any one of claims 1 to 8.
10. The transmission unit transmits identification information unique to the measuring device together with the measurement result and the counter value,
    The storage unit stores the identification information and installation locations in association with each other for a plurality of the measuring devices,
    Based on the integrated value of each measuring device and the corrected observation time, the identification information of each measuring device, and the installation location, the integrated value in the entire predetermined section, and the integrated An interval calculation unit for calculating an observation time corresponding to the value;
    The power distribution network monitoring system according to claim 7.

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