JP6547426B2 - Distribution line management system - Google Patents

Description

  The present invention relates to a distribution line management system that supports preventive maintenance of distribution lines.

  Electricity is converted from a high voltage of 6.6kV supplied from a three-phase three-wire high voltage distribution line (hereinafter simply referred to as "distribution line") to a low voltage of 200V or 100V by a pole transformer, It is supplied to general households by drop lines. A ground fault may occur on such a distribution line. A ground fault is a phenomenon in which electricity passing through a wire such as a distribution line flows to the ground through electricity poles and contacts due to the contact of other objects and defects in the equipment itself.

  When a ground fault occurs, a ground fault protection relay located at the substation detects an accident, and the circuit breaker of the corresponding distribution line operates. This causes a local power outage. When a local power failure occurs, the cause point is identified by dividing the section of the accident point and the sound line and transmitting power in stages.

  Also, in the case of a fine ground fault that does not lead to a complete ground fault, the fault current is small or the duration is short. In such a state, the ground conduction state may be canceled before the ground protection relay installed in the substation reaches operation. Therefore, in the case of a fine ground fault, a power failure does not occur in the corresponding area, but depending on the extent of the ground fault current (voltage), there are homes in which a leak breaker operates and a power failure occurs.

  Identification of the cause of the micro ground fault is carried out by visual inspection of the equipment. However, at the time of patrol, there are cases in which the ground conduction state has already been eliminated. For this reason, it is difficult to identify the cause of the micro ground fault.

  As a method of identifying the cause of the power failure due to such a ground fault, there is a system as described below (see, for example, Patent Document 1). According to this system, frequency analysis of zero-phase current is performed, and the harmonic content rate for each order is determined and waveform classification is performed. Then, the degree of coincidence between the selection time appearance ratio of each waveform pattern which is the classification result and the sample data for each accident cause is determined. As a result, when the ground fault occurs, the cause of the accident is estimated after capturing the time-varying accident mode in association with the specific individual electrical events that differ depending on the cause of the accident.

JP, 2009-17637, A

  The method for identifying the cause of the ground fault including the above-mentioned system has the following problems. When a micro ground fault occurs, it is very difficult to identify the cause by patrol among a large number of facilities. In addition, it is also difficult to predict locations that are likely to occur before the occurrence of a ground fault and to prevent the maintenance of distribution lines.

  In this way, if it is not possible to identify the cause and prevent the preventive maintenance of the distribution line, a fine ground fault or a complete ground fault may occur at the same place.

  Also, the system described above determines the coincidence between the waveform sample data of the zero-phase current, which varies depending on the cause of the accident, and the waveform of the zero-phase current that occurs when a ground fault actually occurs. Identify In this system, although it is possible to identify the location and cause of the ground fault, it is not possible to predict the location where the ground fault may occur. For this reason, it is not possible to prevent the maintenance of distribution lines at the fine ground fault stage before the occurrence of a ground fault accident.

  An object of the present invention is to provide a distribution line management system which solves the above-mentioned problems, detects a ground fault of the distribution line, and supports the preventive maintenance of the distribution line.

In order to solve the above problems, the invention according to claim 1 is installed in a customer's home and has a function of checking the amount of electricity supplied from a lead-in wire, as well as detecting the zero-phase current of the lead-in wire and detecting the zero-phase current A smart meter having a function of transmitting a notice of detection and a notice content of the zero-phase current detection from each smart meter are received and stored, and a notice content of a breaker operation received from each customer is stored. When it is detected that the latest zero-phase current detection from the smart meter is stored based on the storage device and the notification content stored in the storage device , the other smart meters are zeroed within a predetermined time. If you have detected phase current, or, if there is a notification of the breaker operation from other demand house, cause location of the zero-phase current generation and a management device determines that the distribution line side A distribution line management system characterized and.

In the invention of claim 1, the smart meter detects the zero phase current of the drop line and transmits a notification of zero phase current detection. The storage device receives and stores the notification content of the zero-phase current detection from each smart meter, and stores the notification content of the breaker operation received from each customer. Management device, when in the notice content stored in the storage device based, there is a breaker operation notification from when other smart meter is detecting zero-phase current, or other demand house, zero It is determined that the cause of the phase current generation is on the distribution line side .
According to the invention of claim 2, in the distribution line management system according to claim 1, when the management device detects that the latest zero-phase current detection from each of the smart meters is stored, within a predetermined time period If the other smart meter does not detect the zero phase current and there is no notification of the breaker operation from another customer's home, the smart meter in which the cause point of the zero phase current generation detects the zero phase current is installed It is determined that the customer is at the customer home of the

The invention according to claim 3 is the distribution line management system according to claim 1 or 2 , wherein the management device is not notified of a breaker operation from another customer home, and a zero-phase by a smart meter of the customer home It is characterized by judging that there is a source point of zero-phase current generation in the home of the customer if there are multiple times of detection of the current.

According to the invention of claim 4 , in the distribution line management system according to any one of claims 1 to 3 , when the management apparatus determines that there is a cause point of the zero phase current generation in the customer house, the demand It is characterized in that a notification of occurrence of a leak is sent to a home.

The invention according to claim 5 is the distribution line management system according to any one of claims 1 to 4 , wherein the management device is generated in the past when the cause point of the zero phase current generation is on the distribution line side. and the installation position of the smart meter that detected the zero-phase current by finely ground fault was, the size of the zero-phase current, accumulated fine ground fault data including the fault point of the fine ground fault, the zero-phase current time and data including the installation position of the detected smart meter and the magnitude of the zero-phase current is compared with the past of the fine ground fault data, identifies a fault point of the fine ground fault, characterized in that.

According to the invention of claim 1, according to the notification content of zero-phase current detection from the smart meter and the notification content of the breaker operation received from the consumer, the cause point of the zero-phase current generation, that is, It can be checked whether there is a cause such as a leak in the indoor wiring on the distribution line side .
According to the second aspect of the invention, the cause of the zero-phase current generation, that is, the fine ground fault of the distribution line or the like, according to the notification content of the zero-phase current detection from the smart meter and the notification content of the breaker operation received from the customer. It can be checked whether there is a source location such as a leak in the indoor wiring at the home of the demand home.

According to the invention of claim 3 , when there is no notification of the breaker operation from another customer's home, and there is a plurality of times of detection of the zero phase current, it is determined that there is a cause point of the zero phase current generation in the customer home. Therefore, it enables reliable identification of the cause of zero-phase current generation.

According to the invention of claim 4 , when it is determined that the home of the zero-phase current is present in the customer's home, the zero-phase current is caused to occur due to the earth leakage, and the customer is notified automatically of the earth leakage occurrence. It can be carried out.

According to the invention of claim 5 , when the zero phase current is detected, the past ground fault data and the current ground fault data are compared to identify the present ground fault accident point, Enables quick response to the occurrence of micro ground faults.

BRIEF DESCRIPTION OF THE DRAWINGS It is a block diagram which shows the distribution line management system by embodiment of this invention. It is a block diagram which shows an example of a smart meter. It is a perspective view which shows an example of a zero phase current transformer. It is a figure which shows an example of customer data. It is a figure which shows an example of meter data. It is a figure which shows an example of high voltage | pressure distribution line data. It is a figure which shows an example of transformer data. It is a figure which shows an example of distribution pole data. It is a figure which shows an example of low voltage | pressure distribution line data. It is a figure showing an example of drawing-in pillar data. It is a figure which shows an example of zero phase current data. It is a figure which shows an example of breaker operation | movement data. It is a flowchart which shows an example of a ground fault detection process. It is a flowchart which shows an example of a ground fault detection process. It is a figure which shows the mode of the ground fault occurrence. It is a figure which shows an example of arrangement | positioning data. It is a figure which shows an example of arrangement | positioning data. It is a figure which shows an example of arrangement | positioning data. It is a figure which shows an example of arrangement | positioning data.

  Next, embodiments of the present invention will be described in detail with reference to the drawings. A distribution line management system according to this embodiment is shown in FIG. The distribution line management system shown in FIG. 1 detects an indication of a ground fault of the distribution line 101 supported by the distribution poles 111A to 111D, and supports the preventive maintenance of the distribution line 101. In FIG. 1, distribution columns 111A to 111D and a distribution line 101 are shown as a part of the 6 kV distribution system, but the distribution system is not limited to this. This distribution line management system includes the smart meters 201A and 201B installed in the customers' homes 202A and 202B, the communication device 31 installed in the management department of the power company, the storage device 32, the management device 33, and the terminal 34. And have.

  In the 6 kV distribution system, the transformers 121 and 122 installed in the utility poles 111A and 111C convert high-voltage electricity of 6.6 kV into low-voltage electricity of 100 V and 200 V, respectively. The converted electricity is supplied to the customer homes 202A and 202B through the drop lines 132A and 132B and the smart meters 201A and 201B. Although illustration is omitted, each other customer's home also receives the supply of electricity through the service line and the smart meter.

  The smart meters 201A and 201B are electronic watt-hour meters. The smart meters 201A and 201B are connected to the transformers 121 and 122, respectively, by lead wires 132A and 132B. Hereinafter, the smart meter 201A will be described as a representative example. The smart meter 201A is an electronic watt-hour meter internally provided with a measurement function, a calculation function, and a communication function. An example of such a smart meter 201A is shown in FIG. The smart meter 201A includes a transformer 201a, a current transformer 201b, a zero-phase current transformer 201c, a voltage input unit 201d, a current input unit 201e, a zero-phase current input unit 201f, a conversion unit 201g, a processing unit 201h, and a storage unit 201i. , A display unit 201j and a communication unit 201k.

  The transformer 201a of the smart meter 201A is provided on the lead-in line 132A. Thereby, the transformer 201a detects the voltage of the lead-in wire 132A. Moreover, the current transformer 201b is similarly provided in the lead-in wire 132A. The current transformer 201b detects the current flowing through the lead-in wire 132A.

A zero-phase current transformer (ZCT) 201c is provided in the lead-in wire 132A. Thus, the zero-phase current transformer 201c detects the zero-phase current of the lead-in wire 132A. An example of the zero phase current transformer 201c is shown in FIG. Zero-phase current transformer 201c is provided with a torus 201c ₁ and coil 201c _2. Toric 201c ₁ is formed of a magnetic material, the coil 201c ₂ is formed linear conductor wound in a torus 201c _1. In FIG. 3, there is shown a coil 201c ₂ formed of a linear conductor having winding, coils 201c ₂ are linear conductors are wound in forming the entire torus 201c _1.

The toric 201c ₁ drop line 132A extending therethrough. Thus, the zero-phase current transformer 201c detects the difference in magnetic flux between the load current flowing through the lead-in wire 132A toward the home side and the load current returning from the home side and flowing through the lead-in line 132A. That is, when a fine ground fault or a leak occurs in the distribution line 101 or the indoor wiring of the customer's house, electricity flows to the ground, and the geomagnetism changes. As a result, a weak current flows to each customer home, and this weak current flows to the smart meters of each customer home including the smart meter 201A. That is, a difference occurs in the reciprocating load current flowing through the lead-in wire 132A. Coil 201c ₂ detects a zero-phase current by magnetic flux generated by the difference in the load current. Coil 201c ₂ outputs a zero-phase current detected in the zero-phase current input 201f.

  The voltage input unit 201a of the smart meter 201A is an interface that receives the detection voltage of the transformer 20a, and outputs the detection voltage to the conversion unit 201g. The current input unit 201b is an interface that receives the detection current of the current transformer 201b, and outputs the detection current to the conversion unit 201g. Further, the zero-phase current input unit 201 f is an interface that receives the zero-phase current from the zero-phase current transformer 201 c, and outputs the zero-phase current to the conversion unit 201 g.

  The conversion unit 201g generates digital voltage data and current data from the detection voltage from the voltage input unit 201d and the detection current from the current input unit 201e, and sends the data to the processing unit 201h. Also, the conversion unit 201 g generates digital zero-phase current data from the zero-phase current from the zero-phase current input unit 201 f and sends the data to the processing unit 201 h.

  The storage unit 201i stores in advance a process required for the smart meter 201A, for example, a process for calculating an amount of used power, which is an amount of used power.

  The display unit 201j includes a display panel (not shown) such as a liquid crystal display, and displays the amount of used electric power and the like on the display unit 201j under the control of the processing unit 201h. The communication unit 201k enables communication between the processing unit 201h and the management department of the power company via the communication network NW.

  The processing unit 201 h is an arithmetic circuit such as a CPU. When receiving the voltage data and the current data from the conversion unit 201g, the processing unit 201h calculates the amount of used power and the like based on these data. The processing unit 201 h displays the calculated power consumption and the like on the display unit 201 j. Further, the processing unit 201 h controls the communication unit 201 k to transmit voltage data and the like for each predetermined time to the communication network NW.

  Further, when the processing unit 201h receives the zero-phase current from the conversion unit 201g, the processing unit 201h immediately controls the communication unit 201k to notify the management department of a notification indicating the magnitude of the zero-phase current, the time of occurrence, the meter number of itself, Send towards.

  As described above, the smart meter 201A combines the function as a watt-hour meter and the function to detect the zero-phase current.

  The management department installed in the power company includes the communication device 31, the storage device 32, the management device 33, and the terminal 34. The communication device 31, the storage device 32, the management device 33, and the terminal 34 are connected by an in-house communication network LAN and are in a communicable state. That is, the communication device 31 enables mutual communication between the storage device 32, the management device 33, and the terminal 34. The communication device 31 also enables communication between the storage device 32 and the smart meters 201A and 201B using the communication network NW.

  The storage device 32 is a server that stores various data. The data stored in the storage device 32 includes customer data. An example of this customer data is shown in FIG. The customer data stores a customer number, an address, and a name for identifying a customer receiving electricity from the electric power company. In the customer data, the contact point of the customer by e-mail or the like is stored. Furthermore, in the customer data, a meter number for identifying a smart meter installed in the customer's home is stored.

  Data stored in the storage device 32 includes meter data. An example of this meter data is shown in FIG. In the meter data, the meter number of the smart meter installed in the home of the customer is stored. Also, in the meter data, when the smart meter is drawing electricity from the electricity pole, the electricity pole number for identifying this drawing pole is stored, and when electricity is supplied directly from the transformer, An equipment number for identifying this transformer is stored. Furthermore, in the meter data, GPS (Global Positioning System) coordinates representing the installation position where the smart meter is installed are stored.

  The data stored in the storage unit 32 includes high voltage distribution line data. An example of this high voltage distribution line data is shown in FIG. The high voltage distribution line data includes a high voltage distribution line number for identifying high voltage distribution lines respectively installed in the distribution system, and for identifying a power pole installed for supporting the high voltage distribution lines, that is, a distribution pole The telephone pole number is stored.

  The data stored by the storage device 32 includes transformer data. An example of this transformer data is shown in FIG. The transformer data stores the pole number of the distribution pole where the transformer is installed. Also, in the transformer data, a low voltage distribution line number for identifying a low voltage distribution line connected to the secondary side (output side) of the transformer is stored.

  The data stored in the storage unit 32 includes distribution pole data. An example of this distribution pole data is shown in FIG. In the distribution pole data, the pole number of the distribution pole is stored. Further, in the distribution pole data, when, for example, a transformer is installed in the distribution pole, the equipment number of the transformer is stored as the installation equipment. Furthermore, in the distribution pole data, GPS coordinates representing the installation position of the distribution pole are stored.

  The data stored in the storage unit 32 includes low voltage distribution line data. An example of this low voltage distribution line data is shown in FIG. The low voltage distribution line data stores the number of the low voltage distribution line and the equipment number of the transformer that outputs the electricity to the low voltage distribution line. Further, in the low voltage distribution line data, the utility pole number supporting the low voltage distribution line is stored.

  Data stored in the storage device 32 includes drop-in column data. An example of this drop-in column data is shown in FIG. The telephone pole number of the lead-in pole is stored in the lead-in pole data. Furthermore, GPS coordinates representing the installation location of the lead-in pole are stored in the lead-in pole data.

  The data stored in the storage device 32 includes zero-phase current data. An example of this zero-phase current data is shown in FIG. The zero-phase current data stores the date and time when the zero-phase current was detected. Further, in the zero phase current data, the meter number of the smart meter that detected the zero phase current and the current value of the zero phase current at this time are stored. When the storage device 32 receives the notification of the zero phase current detection from the smart meter, the storage device 32 updates the zero phase current data according to the content of the notification. That is, the storage device 32 reflects the contents of the notification of the detection of the zero phase current such as the meter number and the current value from the smart meter in the zero phase current data.

  The data stored in the storage unit 32 includes breaker operation data. An example of this breaker operation data is shown in FIG. The breaker operation data stores the date and time when the breaker operated. Further, the breaker operation data stores a customer number for identifying a consumer operating the breaker. When the storage device 32 receives the notification of the breaker operation from the terminal 34, the storage device 32 updates the breaker operation data by this notification. That is, the storage device 32 reflects the content of the notification from the customer on the breaker operation data.

  The terminal 34 is a computer used by a person in charge of the management department. Various data are displayed on the terminal 34 by the management device 33. For example, the terminal 34 causes the management device 33 to display that the customer has been notified of the occurrence of the leakage. Further, an instruction to the management apparatus 33 is input to the terminal 34 by a person in charge. For example, an instruction such as termination of the ground fault detection process to be described later is input to the terminal 34. Furthermore, when the person in charge receives notification of the breaker operation from the customer, the terminal 34 receives notification of the breaker operation by the person in charge. Thus, the terminal 34 sends this notification to the storage device 32.

  The management device 33 is a computer that detects a ground fault occurring in a 6.6 kV distribution system, in particular, a fine ground fault or a leak due to an indoor wiring of a home of a customer. For this purpose, the management device 33 performs ground fault detection processing. This ground fault detection process is shown in FIG. 13 and FIG. After performing the ground fault detection process, the management device 33 periodically refers to the zero-phase current data of the storage device 32 (step S1) and checks whether the smart meter has detected the zero-phase current (step S2). At step S2, the management device 33 checks whether the smart meter has detected the zero phase current, depending on whether the latest zero phase current is recorded.

  If no zero-phase current is detected in step S2, the management device 33 returns the process to step S1. When the zero-phase current is detected in step S2, the management device 33 checks whether another smart meter has detected the zero-phase current within a predetermined time set in advance (step S3). If the other smart meter does not detect the zero phase current at step S3, the management device 33 checks whether the smart meter checked at step S2 has detected the zero phase current in the past (step S4). In step S4, if the zero phase current has not been detected in the past, the management device 33 returns the process to step S1. Since zero phase current is frequently detected when a micro ground fault or leakage occurs, the management apparatus 33 does not generate a micro ground fault or leakage for detection of the zero phase current only once. to decide.

  If the zero-phase current has been detected in the past in step S4, the management device 33 checks whether or not the breaker has operated at another customer's home (step S5). In step S5, the management device 33 refers to the breaker operation data of the storage device 32. Then, if the breaker does not operate in another customer's home, the management device 33 determines that the cause of the generation of the zero-phase current is in the customer's home. If the breaker is not operating in step S5, the management device 33 checks the contact point of the smart meter consumer checked in step S2 (step S6). In step S6, the management device 33 refers to the customer data in the storage device 32, and checks the contact point of the customer based on the meter number of the smart meter recorded in the zero-phase current data. The management device 33 transmits a message indicating the occurrence of a leakage to the contact address checked in step S6 (step S7). At step S7, the management device 33 notifies the contact address checked at step S6 of the occurrence of the leakage by e-mail or the like. At the same time, the management device 33 notifies the terminal 34 that the customer has been notified of the occurrence of the leakage.

  When step S7 ends, the management device 33 checks whether there is an instruction to end the ground fault detection process from the terminal 34 (step S8). If there is no instruction to end the process at step S8, the management device 33 returns the process to step S1. Further, when an instruction to end the process is given in step S8, the management device 33 ends the ground fault detection process.

  On the other hand, when another smart meter detects the zero-phase current in step S3, the management device 33 selects the smart meter extracted in steps S2 and S3, that is, all the smarts that detect the zero-phase current within the predetermined time. The GPS coordinates of the meter are checked (step S9). In step S9, the management device 33 refers to the meter data of the storage device 32 according to the meter number of the smart meter extracted in steps S2 and S3, and detects all zero-phase currents in the latest time zone. Find out the GPS coordinates of.

  On the other hand, when the breaker is operating in step S5, the management device 33 checks the GPS coordinates of the home of the customer at which the breaker has operated (step S10). In step S10, the management device 33 refers to the customer data according to the customer number of the breaker operation data and checks the meter number of the smart meter. Further, the management device 33 refers to the meter data of the storage device 32 according to the meter number to check the GPS coordinates of the corresponding smart meter, that is, the GPS coordinates of the home of the customer.

  Upon completion of step S9 or step S10, that is, if it is determined in steps S2 to S5 that the origin of the generation of the zero-phase current is on the distribution line side, the management device 33 uses the GPS coordinates checked in these steps. Micro ground fault data representing the current micro ground fault is created (step S11). In step S11, the management device 33 sets data representing a list of smart meters that have detected the zero-phase current in the current micro ground fault as micro ground fault data. Further, in this embodiment, micro ground fault data includes arrangement data in which the installation position of the smart meter detecting the zero-phase current and the installation position of the smart meter at the customer's house where the breaker operates are entered on the GPS coordinates. Let's do it.

  Here, a specific example of arrangement data will be described. As shown in FIG. 15, the 6.6 kV high voltage distribution line 101 of the distribution system is supported by the distribution poles 111A to 111D. A transformer 121 is installed in the distribution pole 111A. The transformer 121 converts the high voltage of 6.6 kV into a low voltage of 100 V or 200 V, and outputs low voltage electricity to the low voltage distribution line 131A and the lead-in line 132A. Electricity is supplied to the home 202A of the customer's home through the lead-in line 132A and the smart meter 201A. Similarly, the transformer 122 installed in the distribution pole 111C converts the high voltage of 6.6 kV into a low voltage and outputs it to the low voltage distribution line 131B and the lead-in line 132B. Electricity is supplied to the customer home 202B through the lead-in line 132B and the smart meter 201B.

The low voltage distribution line 131A is supported by the draw-in columns 112A to 112C. And, draw-in pillar 1
From 12A, electricity is supplied to the customer home 202C through the lead-in line 132C and the smart meter 201C, and electricity is supplied to the customer home 202D through the lead-in column 112B and the smart meter 201D.

  In such a state, when a fine ground fault occurs in the high voltage distribution line 101 as a ground fault, for example, the smart meters 201A, 201C, and 201D detect zero-phase current. In addition, the breaker operates in the home 202B of the customer. Then, in the previous step S11, the management device 33 creates micro ground fault data, and as shown in FIG. 16, creates arrangement data from the GPS coordinates of the smart meters 201A to 201D and adds it to the micro ground fault data. Do. In FIG. 16, triangle marks indicate smart meters 201A to 201D.

  When step S11 is completed, the management device 33 checks the distribution poles and the drop columns of the distribution system in which each smart meter that has detected the zero-phase current receives the supply of electricity (step S12). In step S12, the management device 33 refers to the meter data of the storage device 32 using the meter number used in step S10, and checks the telephone pole number of the lead-in pole. After that, the management device 33 refers to the low voltage distribution line data of the storage device 32 using the power pole number of the lead-in pole, and the transformer outputting the number of the low voltage distribution line and the low voltage distribution line. And the pole number of the service pole supporting the low voltage distribution line. Thereafter, the management device 33 uses the telephone pole number of each lead-in pole and refers to the lead-in pole data of the storage unit 32 to check the GPS coordinates of each lead-in pole. Thereafter, the management device 33 uses the transformer device number and refers to the transformer data of the storage device 32 to find out the pole number of the distribution pole in which the transformer is installed. After that, the management device 33 refers to the high voltage distribution line data of the storage device 32 using the power pole number of the power distribution pole to find out the number of the high voltage distribution line. Then, using the high voltage distribution line number, the management device 33 refers to the high voltage distribution line data of the storage device 32 to check the power pole number of each distribution pole, and further uses the power pole number to Refer to distribution pole data and find out the GPS coordinates of each distribution pole.

  Thus, at step S12, the management device 33 checks the GPS coordinates of the distribution pole and the GPS coordinates of the lead-in pole.

  When step S12 is completed, the management device 33 adds the distribution pole and the draw-in pole of the distribution system examined in this step to the fine ground fault data (step S13). At step S13, the management device 33 adds the GPS coordinates of the distribution pole and the lead-in pole to the ground fault data. The management device 33 also writes the distribution pole and the draw-in pole in the arrangement data by the GPS coordinates of the lead-in pole and the distribution pole. Furthermore, the management device 33 connects the lead-in poles and the distribution poles of the distribution system in the arrangement data based on the low-voltage distribution line data and the high-voltage distribution line data checked in step S12. An example of the entry result of step S13 is shown in FIG. For the smart meter, a lead-in pole and a distribution pole are entered based on GPS coordinates.

  When step S13 is completed, the management device 33 adds the necessary data to the micro ground fault data (step S14). In step S14, the management device 33 adds, for example, the magnitude of the zero-phase current detected by each smart meter to the micro ground fault data. At the same time, the management device 33 also writes in the placement data the magnitude of the zero-phase current detected by each smart meter. An example of the entry result in step S14 is shown in FIG. In the arrangement data of FIG. 18, the management device 33 writes the magnitude of each zero-phase current and the breaker operation.

When step S14 is completed, the management device 33 examines the ground fault point of the micro ground fault using the micro ground fault data created in this step (step S15). In step S15, the management device 33 compares the ground position data of the micro ground fault data with items such as the installation position of the smart meter and the magnitude of the zero-phase current with the ground fault data as the accumulated data in the past. Identify the entangled point. The accumulated data in the past is obtained by accumulating data indicating what zero-phase current has flowed to each smart meter due to the occurrence of a ground fault, the breaker has operated, and the like. The comparison items include the following.
・ Sensing intensity of zero phase current transformer when micro ground fault occurs (zero phase current)
・ Length of distribution line ・ Position of transformer ・ Installation place of smart meter ・ Position of lead-in column

  Furthermore, the management device 33 may use the arrangement data in step S15. In the placement data, the installation positions of the smart meter, the distribution pole, and the lead-in pole are all shown in GPS coordinates. As a result, the length of the distribution line can also be calculated by using the GPS coordinates of the distribution pole. Then, the management device 33 reads out, from the storage device 32, candidates for past arrangement data in which the patterns of the installation positions of the distribution poles and the dropout columns are similar. Thereafter, the management device 33 compares the present arrangement data with the read arrangement data. At this time, the management device 33 calculates the difference between each zero-phase current, the difference between the installation positions of each smart meter, the difference between the lengths of the low voltage distribution line and the high voltage distribution line, etc. select. Then, the management device 33 specifies the ground fault point described in the selected past arrangement data as the current ground fault point.

  When step S15 is completed, the management device 33 notifies the terminal 34 that a micro ground fault has occurred (step S16). In step S16, the management device 33 sends, to the terminal 34, the arrangement data created in step S14, a message notifying that a fine ground fault has occurred at the ground fault point identified in step S15, and the like.

  When step S16 ends, the management device 33 returns the process to step S8. Thereafter, the management device 33 receives, from the terminal 34, data indicating the result of processing the current micro ground fault, for example, data indicating response result information (reception date and time, cause of failure) at the time of failure repair. Thereafter, as illustrated in FIG. 19, for example, the management device 33 marks the ground fault location on the GPS coordinates, and accumulates the micro ground fault data in the storage device 32.

  Next, the operation of the distribution line management system according to this embodiment will be described. Each smart meter installed in the power distribution system functions as a watt-hour meter, and detects zero-phase current generated in a fine ground fault of the distribution wiring and the indoor wiring of the customer's home. Then, when a fine ground fault occurs in a high voltage distribution line or the like of the distribution system, a smart meter installed in the distribution system detects zero-phase current due to the fine ground fault. And the smart meter which detected the zero phase current transmits the notification of zero phase current detection to the memory | storage device 32 of a management section. When the storage device 32 receives the notification of the zero phase current detection, the storage device 32 updates the zero phase current data.

  In addition, when a fine ground fault occurs in the distribution system etc., the breaker may operate in the home of the customer. In this case, when the customer notifies the management department of the breaker operation, the person in charge operates the terminal 34 to input the notification of the breaker operation. Thus, the terminal 34 sends the input notification to the storage device 32. When the storage device 32 receives the notification of the breaker operation, the storage device 32 updates the breaker operation data based on the content of the notification.

  On the other hand, the management device 33 of the management department is performing ground fault detection processing. Then, when the zero-phase current data of the storage device 32 is updated, the management device 33 detects that the latest zero-phase current data is recorded. At this time, when the smart meter detects the zero-phase current only once, the management device 33 does not determine that a ground fault has occurred or a leak. In addition, when there is a plurality of detections of the zero-phase current, and the other smart meter does not detect the zero-phase current, or when the breaker is not operating at another customer's home, the management device 33 It is judged that there is a leak due to indoor wiring at a customer's house where a smart meter that has detected a phase current is installed, and this customer is notified of the occurrence of the leak by e-mail or the like.

  On the other hand, when a plurality of smart meters detect the zero phase current and the breaker operates at another customer's home, the management device 33 determines that a micro ground fault has occurred and detects the zero phase current. Or, create fine ground fault data representing a smart meter installed in the home of the customer whose breaker operation has occurred. In addition, the GPS coordinates of the smart meter create arrangement data in which these smart meters are filled. Furthermore, the management device 33 adds a pull-in pole, a distribution pole, and the like to the micro ground fault data, and adds a magnitude of the zero-phase current and the like. Thereafter, the ground fault data is specified by comparing the ground fault data with the past ground fault data. Then, the terminal 34 is notified that a micro ground fault has occurred at the ground fault point.

  When the processing of the ground fault is completed, data of the ground fault is recorded in the storage device 32 from the management device 33, and is used as accumulated data of the fault.

  Thus, according to this embodiment, the smart meter is provided with the function of a zero-phase current transformer for detecting a ground fault current, and a zero due to a change in geomagnetism when a microground fault occurs in a distribution line or indoor wiring The sensing information of the phase current transformer is transmitted to the server of the power company through the smart meter. Then, by comparing the data stored in the server of the power company with a predetermined item and making a comprehensive judgment, it is possible to specify the cause of the micro ground fault. This enables quick response to the occurrence of micro ground faults, that is, maintenance of distribution lines.

  In addition, according to this embodiment, there is no similar detection of the ground in the surroundings, and if the ground is frequently generated only indoors of a certain customer, it is possible that the electric leakage may occur indoors. It is possible to notify the corresponding customer that there is a sex. That is, the series of processes of steps S3 to S5 enables reliable determination of the occurrence of the leakage.

  Furthermore, according to this embodiment, based on the accumulated GPS coordinate data, it is possible to predict, at the stage of micro ground fault occurrence, a portion where the possibility of ground fault occurrence is high before ground fault occurrence. And since the occurrence place of a micro ground fault is specified, the place which needs patrol can be narrowed down and the preventive maintenance of a distribution line can be performed.

101 Distribution Line 111A-111D Distribution Pole 121, 122 Transformer 201A, 201B Smart Meter 31 Communication Device 32 Storage Device 33 Management Device 34 Terminal

Claims (5)

A smart meter installed in a customer's home and having a function of checking the amount of electric power supplied from a lead-in, and a function of detecting a zero-phase current of the lead-in and transmitting a notification of the zero-phase current detection;
A storage device that receives and stores notification content of the zero-phase current detection from each of the smart meters, and stores notification content of a breaker operation received from each of the consumers;
When it is detected that the latest zero-phase current detection from the smart meter is stored based on the notification content stored in the storage device, another smart meter detects the zero-phase current within a predetermined time. A management device that determines that the cause point of the zero-phase current generation is on the distribution line side, when there is a notification of breaker operation from another customer's home , or
A distribution line management system comprising: When the management device detects that the latest zero-phase current detection from each of the smart meters is stored, the other smart meters have not detected the zero-phase current within a predetermined time, and When there is no notification of the breaker operation from the home of the customer, it is determined that the cause of the zero-phase current generation is in the home of the customer where the smart meter detecting the zero-phase current is installed,
The distribution line management system according to claim 1, characterized in that: If there is no notification of a breaker operation from another customer's house and the detection of the zero-phase current by the smart meter of the customer's house has been made multiple times, the management device causes the zero-phase current to occur at the customer's house. Judge as there is,
The distribution line management system according to claim 1 or 2 , characterized in that: When the management device determines that there is a cause point of the zero-phase current generation in the customer home, the management device notifies the customer home occurrence of the electric leakage occurrence.
The distribution line management system according to any one of claims 1 to 3 , characterized in that: The management device, when the cause portions of the zero-phase current generator is in the distribution line side, and installation position of the smart meter which detects the zero-phase current by finely ground fault that occurred in the past, the size of the zero-phase current accumulates fine ground fault data including the fault point of the fine ground fault, the data including the magnitude of the zero-phase current and the installation position of the smart meter which detects the zero-phase current time, past the fine ground Compare the data to identify the ground fault fault point,
The distribution line management system according to any one of claims 1 to 4 , characterized in that:

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