KR20220019401A - Method for controlling protective equipment on the radial distribution systems - Google Patents

Abstract

Disclosed is a power distribution system protection device control method. According to the present invention, the power distribution system protection device control method comprises the following steps of: inputting, by a protection device, a setup value for correcting protection coordination standards from a user terminal; and correcting, by the protection device, the protection coordination standards that define protection device operating time for a fault current based on an IEC-VI curve according to the setup value received from the user terminal.

Description

DISTRIBUTION SYSTEM PROTECTIVE EQUIPMENT ON THE RADIAL DISTRIBUTION SYSTEMS

The present invention relates to a distribution system protection device control method, and more particularly, a distribution system that uses IEC-VI characteristic curves to correct the protection coordination standards between various protection groups existing in a distribution line and protects the distribution system from fault currents based on this. It relates to a system protection device control method.

Protective devices in the existing power system do not have an equation for the characteristic curve as a function, and the characteristic curve is selected through the time constant using reactance and capacitance, which are electrical circuit elements. The characteristic curves of analog protection devices were named A, B, C, and D characteristic curves, and protection cooperation was carried out using them. However, analog devices had many considerations, including the return rate. Accordingly, a digital protection device has been developed to eliminate such inconvenience.

Digital protection devices in the transition period, where digital protection devices and analog protection devices are mixed and used in the power system, forcibly use the A, B, C, D characteristic curves of existing analog protection devices for protection cooperation with analog protection devices. formulate For this reason, the problem of non-standardized protection coordination of the existing A, B, C, and D characteristic curves continued. Accordingly, N1, N2, N3, N4 characteristic curves were developed to replace the existing A, B, C, and D characteristic curves and to facilitate cooperation with the fuse, and a function was added to the recloser.

Currently, the transmission and distribution system and distribution system have been converted to most digital protection devices, and in particular, the digital substation relay uses a characteristic curve modified from the strong time characteristic curve proposed by ANSI. As a result, the distribution system must also use the same characteristic curve used in the transmission and distribution system, but the recloser in the distribution system does not include the strong time-limit characteristic curve suggested by ANSI, and the existing N1, N2, N3, N4 As the characteristic curve does not cause any major problems, it is used as it is.

The background technology of the present invention is disclosed in 'SCADA gateway device and its protocol conversion method for accommodating DNP3.0 and IEC 61850' of Korean Patent Application Laid-Open No. 10-1813066 (2017.12.21).

The conventional N1, N2, N3, and N4 characteristic curves have disadvantages of the A, B, C, and D characteristic curves of the existing analog protection devices.

In addition, since the IEC characteristic curve is used for the customer relay characteristic curve, the slope is different from the substation relay, recloser, and customer relay, so it is impossible to cooperate with two or more reclosers.

Therefore, in order to keep the distribution system in line with the internationalization trend and to smoothly cooperate among all protection devices, it is similar to the ANSI strong time characteristic curve used in the transmission and distribution system and the IEC strong time characteristic curve that the recloser of the distribution system already has. The importance of using it to promote protection cooperation is being emphasized.

However, since the current substation characteristic curve, ANSI standard curve, is only included in multi-circuit breakers, directional reclosers, and Epoxy Fault Interrupters (EFIs), protection coordination with the majority of automation reclosers currently installed in distribution lines is smooth. don't Therefore, the need to proceed with protection cooperation through the IEC standard curve similar to the substation ANSI curve was raised.

The present invention has been devised to improve the above problems, and an object according to an aspect of the present invention is to correct the protection coordination standards between various protectors existing in the distribution line using the IEC-VI characteristic curve, and based on this, An object of the present invention is to provide a distribution system protection device control method that protects the distribution system.

A distribution system protection device control method according to an aspect of the present invention includes the steps of: inputting, by the protection device, a set value for correcting a protection coordination standard from a user terminal; and correcting, by the protection device, a protection coordination standard that defines a protection device operating time against a fault current based on an IEC-VI curve according to the set value input from the user terminal.

The set value of the present invention is the time dial ( Time Dial) and Minimum Response Time (MRT).

The protection device of the present invention is characterized in that the protection coordination standard is corrected by reflecting the short-circuit fault current, the ground fault current, and the time dial and the M.R.T according to the configuration of the distribution line in the IEC-VI curve.

The short-circuit fault current of the present invention is 2.8 to 4 times or more of the maximum load current at the installation point of the protection device, and is characterized in that it is less than the minimum operating current on the back-up (power side) protection device.

The ground fault current of the present invention is 0.3 times or more of the maximum load current at the installation point of the protection device, and is characterized in that it is less than the minimum operating current on the back-up (power side) protection device.

The distribution line of the present invention is characterized in that one recloser and one pull-in breaker are configured, or two reclosers and one pull-in breaker are configured, or three reclosers and one pull-in breaker are configured. do it with

The time dial and the minimum response time of the IEC-VI curve of the present invention are individually set for instantaneous and delayed interruption when the distribution line has a short circuit and a ground fault.

The present invention further comprises the step of blocking the fault current so that the fault current does not flow to the distribution system according to the protection coordination standard when the protection device detects the fault current.

The distribution system protection device control method according to an aspect of the present invention uses the IEC-VI characteristic curve to correct the protection coordination standards among various protection periods existing in the distribution line, and protects the distribution system from fault currents based on this.

The distribution system protection device control method according to another aspect of the present invention provides protection coordination between one recloser and one EFI unit, protection coordination between two reclosers and one EFI unit, and two reclosers even if the distribution system is changed frequently. For each protection coordination between one EFI unit, it is possible to conduct a protection coordination review in a simple manner.

The distribution system protection device control method according to another aspect of the present invention can minimize the distribution protection coordination operation manpower, and increase the training of the distribution protection coordination operation manpower and the efficiency of the corresponding program.

1 is a block diagram of an apparatus for controlling a distribution system protection device according to an embodiment of the present invention.
2 is a flowchart of a method for controlling a distribution system protection device according to an embodiment of the present invention.
3 is a view showing the configuration of a line having one recloser and one incoming breaker according to an embodiment of the present invention.
4 is a view showing a setting value input screen in a line configuration having one recloser and one incoming breaker according to an embodiment of the present invention.
5 is a diagram showing the configuration of a line having two reclosers and one entry breaker according to an embodiment of the present invention.
6 is a view showing a setting value input screen in a line configuration having two reclosers and one incoming breaker according to an embodiment of the present invention.
7 is a view showing the configuration of a line having three reclosers and one entry breaker according to an embodiment of the present invention.
8 is a view showing a setting value input screen in a line configuration having three reclosers and one incoming breaker according to an embodiment of the present invention.
9 is a diagram illustrating a setting value input screen for an ingress breaker according to an embodiment of the present invention.
10 is a view showing a standard correction result for a fault current due to a short-circuit fault according to an embodiment of the present invention.
11 is a view showing a standard correction result for a fault current due to a ground fault according to an embodiment of the present invention.

Hereinafter, a method for controlling a distribution system protection device according to an embodiment of the present invention will be described in detail with reference to the accompanying drawings. In this process, the thickness of the lines or the size of the components shown in the drawings may be exaggerated for clarity and convenience of explanation. In addition, the terms to be described later are terms defined in consideration of functions in the present invention, which may vary according to intentions or customs of users and operators. Therefore, definitions of these terms should be made based on the content throughout this specification.

1 is a block diagram of an apparatus for controlling a distribution system protection device according to an embodiment of the present invention, and FIG. 2 is a flowchart of a method for controlling a distribution system protection device according to an embodiment of the present invention.

1, the distribution system protection device control apparatus according to an embodiment of the present invention corrects the protection coordination standard between various protection devices existing in the distribution line using the IEC-VI characteristic curve, and based on this, As to protect the distribution system, the user terminal 10, the server 20, and a protection device, for example, includes a recloser 30 and an entry breaker (EFI) (40).

In general, a distribution line consists of an overhead line and an underground line. The recloser 30 is used for the overhead line, and a multi-circuit breaker is used for the underground line.

The composition of the protection device according to each location is shown in Table 1 below.

overhead line underground line substation CB(OCR, OCGR) CB(OCR, OCGR) distribution line Recloser Multi-circuit breaker (MCA) branch of responsibility Fuse, EFI Multi-circuit breaker (MCA) customer protector ASS, Fuse, CB (OCR, OCGR) ASS, Fuse, CB (OCR, OCGR)

Currently, ASS (Auto Sectionalizing), LBS (Load Breaking Switch), and Fuse are not considered for protection coordination. ASS and LBS are currently used for civilian use, and after experiencing a fault current in an internal fault on the customer side including the section function, the system is disconnected after the recloser 30 or the fuse operates.

In the distribution system, preset correction standards for protection cooperation between substation relays, fuses, reclosers, and customer relays may be prepared. Each protective device can be a main protective device or a secondary protective device.

Since the substation relay is installed at the substation withdrawal point, it can be said that it is the first protection device of the distribution system. Therefore, it is possible to smoothly set the sub-distribution system protection devices only when the substation relay setting is performed accurately.

Currently, the substation relay uses the KEPCO Very Inverse (KVI) curve, which is a modified ANSI standard characteristic curve with the correction criteria shown in Table 2 below.

division Criteria for correction one hour
Tap OCR - Maximum load current × 1.5 or more / CT ratio
- Minimum 2-phase short-circuit current in protection section / 1.5 or less / CT ratio OCGR - Maximum load current × 0.3 or more / CT ratio
- Minimum 1-wire ground fault current in protection section / 1.5 or less / CT ratio one hour
Lever OCR - Operates in less than 0.5 seconds (30cycles) at the substation withdrawal point 3-phase short-circuit current
(If it is difficult to cooperate with the protection of the distribution line, it can be corrected in less than 0.6 seconds) OCGR - Operates in less than 0.5 seconds at maximum 1-line ground fault at the substation withdrawal point instantaneous
Tap OCR - Three-phase short-circuit current of potential recloser installation point × 1.5 or more OCGR - Maximum 1-wire ground fault current of potential recloser installation point × 1.4 or more

Short-circuit faults are protected through an overcurrent relay (OCR), and for earth faults, protection is performed through an overcurrent ground relay (OCGR). The win rate for the maximum load current and fault current is a value calculated through the average value of the experimentally acquired values in consideration of the Current Transformer (CT) error and setting error, and it is determined by OCGR.

The recloser 30 is installed on the main trunk line of the distribution system, and according to the line length and load conditions, one to three units can be installed in Korea. Since many are installed on the main trunk line of the distribution system, the recloser 30 requires cooperation with various protection devices. Table 3 is a correction standard of the recloser (30).

division Criteria for correction Ieast
movement
electric current award - 2.8 times or more, 4.0 times or less of the maximum load current
- Below the set value of the minimum operating current of the phase of the back-up protection device ground fault - Maximum load current × 0.3 or more
- More than the maximum load current of the maximum single-phase branch on the load side of the recloser
- Minimum 1-wire ground fault current / 2 or less in the protection section
- Less than the minimum operating current setting for the back-up protection device ground fault total number of operations - If there is a recloser in the rear
→ Total number of operations of rear rear recloser -1 or less number of instantaneous movements - Less than the total number of operations
- Match the number of instantaneous operation of phase and ground fault time to reclose - More than the time required for the recloser body to prepare for loading
- Time and date due to reclosing of phase and ground faults

When the recloser 30 is the main protection device and the back-up protection device is a substation relay, the cooperation time of at least 3 cycles (0.05 seconds) is required, considering the accident cutoff time, CT error, and setting error. . In addition, when considering the cooperation between the reclosers, the minimum coordination time is slightly different depending on the type of the back protection device recloser 30 made by the manufacturer, and is shown in Table 4.

back protection device main protection device Minimum coordination time difference [cycles] substation relay recloser 3 recloser
KH-ESV, ESV recloser 3.5 recloser
IJB-VE, VWVE, EVR-2 recloser 2.7

This recloser 30 has two Fast and Delay curves, and each curve is selected in consideration of Tables 3 and 4 and Table 5 in consideration of cooperation with the fuse.

Since a fuse is an analog device, it is difficult to accurately calculate it like a digital device. Therefore, the concept of win rate can be introduced because there is a large error in the calculation process compared to digital devices.

Fast Curve Correction Criteria

For single-phase line
fuse

승률 < 퓨즈 최소용융시간
-> 리클로저 Fast 동작회수(1회) : 승률 1.2
-> 리클로저 Fast 동작회수(2회) : 승률 1.8(재폐로시간 약 0.5초)
-> 리클로저 Fast 동작회수(2회) : 승률 1.35(재폐로시간 1초 이상)
- 리클로저 Delay 동작시간 > 퓨즈 최대사고제거시간- Recloser Fast operation time

Win rate < fuse minimum melting time
-> Recloser Fast number of moves (1): Win rate 1.2
-> Recloser Fast operation times (2 times): win rate 1.8 (reclosing time about 0.5 seconds)
-> Recloser Fast operation number (2 times): win rate 1.35 (reclosing time more than 1 second)
- Recloser Delay operation time > Fuse maximum accident removal time

Line fuses are installed only in single phase in the distribution system, and the correction criterion is only the fuse rating. Table 6 is the correction standard for line fuses.

Criteria for correction

fuse capacity

0.75- More than the maximum load current at the installation point
- At least 1 wire ground fault current in the protection section
- Maximum accident removal time of main protection device (fuse) < Minimum melting time of secondary protection device (fuse)

0.75

The customer relay is installed on the load. In particular, when the customer relay operates as the main protection device, the back-up protection device generally becomes the recloser 30 or the substation relay. Cooperation is not easy. Therefore, the protection of the customer relay can be performed smoothly only when the setting of the upper level protection devices is performed smoothly. These customer relay correction standards are shown in Table 7.

division Criteria for correction instantaneous
Tap OCR - Receiver transformer secondary side 3-phase short-circuit current × 1.5 times or more OCGR - Minimum tap one hour
Tap OCR - Maximum load current × 1.5 times or more
- In case of variable load: Maximum load current × 2 times or more
- Minimum short-circuit current of power receiving facility / 1.5 or less OCGR - Max load current × 0.3 or less
- Load unbalance current × 1.5 times or more one hour
Lever OCR - Operates within 0.6 seconds at 3-phase short-circuit current on the secondary side of the receiving transformer OCGR - Operates within 0.2 seconds at the maximum 1-line ground fault current and 1-wire ground fault current on the primary side of the receiving transformer

In general, various constraints for applying the Kepco-VI curve (N1, N2, N3, N4), which are the existing protection coordination curves, are specified above. Satisfying all of these complicated conditions for cooperation can be a significant burden on actual users, for example, system operation personnel.

Therefore, in this embodiment, the IEC-VI curve is applied to all protection devices of the distribution line to unify the cooperation method according to the series connection relationship of the protection devices of the distribution line, and the protection coordination standard is set according to the configuration of the number of serially operated units of the protection device. correct

Accordingly, the user terminal 10 receives a set value for correcting the protection coordination standard from the user as described above (S10).

The user terminal 10 may display an input screen of an individual protection device for receiving the setting value from the user, and receives the setting value through the input screen. The set value includes the IEC-VI curve, the short-circuit fault current range and the ground fault current range for selecting the minimum operating current, and the time dial and the minimum Response time (Minimum Response Time, MRT) may be included. This will be described later.

First, the user terminal 10 receives an IEC-VI curve as a T/C curve as shown in Table 8 below.

division input comparison T/C IEC-VI curve - Recloser and multi-circuit breaker are the same
- Input the same value of phase, instantaneous and ground fault
- Ground instantaneous, same ground fault input

The set value for correcting the protection coordination standard may include the time dial and the minimum response time of the IEC-VI curve according to the serial number of protection devices in the distribution line for selecting the minimum operating current of individual protection devices as described above. .

First, in order to select the minimum operating current (Pick-up Current) of the individual protection device, the user terminal 10 receives the short-circuit fault current range and the ground fault current range from the user. This is as shown in Table 8.

division input note award
(paragraph
breakdown
electric current) - 2.8~4 times or more of the maximum load current at the installation point of the protection device
- Less than the minimum operating current on the back-up (power side) protection device
example
- Protection device 1: [Upper] 365 / [Ground fault] 80
- Protection device 2: [Upper] 330 / [Earth fault] 70
- Protection device 3: [Upper] 295 / [Ground fault] 65
- Protection device 4: [Upper] 270 / [Ground fault] 55
(Protective device 1 at the most power side, Protection device 4 at the lowest load side) ground fault
(Earth fault
breakdown
electric current) - At least 0.3 times the maximum load current at the installation point of the protection device
- Less than the minimum operating current on the back-up (power side) protection device

That is, as shown in Table 9, the short-circuit fault current should be input as 2.8~4 times or more of the maximum load current at the installation point of the protection device and below the minimum operating current on the back-up (power side) protection device.

In addition, the ground fault current must be input as 0.3 times or more of the maximum load current at the installation point of the protection device, and must be input below the minimum operating current on the back-up (power side) protection device.

Accordingly, within the input range of the above short-circuit fault current and ground fault current, protection device 1 is set to [phase] (short-circuit fault current) 365 / [ground fault] (ground fault current) 80, and protection device 2 is [phase] ] 330 / [Ground fault] is set to 70, protection device 3 is set to [phase] 295 / [ground fault] 65, and protection device 4 can be input as [phase] 270 / [ground fault] 55, and it is far from the power supply. It can be seen that the short-circuit fault current and the ground fault current decrease as the temperature increases.

On the other hand, the protection device may include the recloser 30 and the inlet breaker 40 . A plurality of reclosers 30 may be connected in series. In this case, when the distribution line consists of one recloser 30 and one pull-in circuit breaker 40, two reclosers 30 and one pull-in circuit breaker 40, and It may be included as a case in which the closure 30 is three and the inlet breaker 40 is configured as one.

3 is a view showing the configuration of a line having one recloser and one entry breaker according to an embodiment of the present invention, and FIG. 4 is one recloser and one entry breaker according to an embodiment of the present invention. It is a view showing the setting value input screen in the person-to-person line configuration, and FIG. 5 is a view showing the line configuration in which two reclosers and one entry breaker according to an embodiment of the present invention are shown, and FIG. 6 is one of the present invention It is a view showing a setting value input screen in a line configuration in which there are two reclosers and one incoming breaker according to the embodiment, and FIG. 6 is three reclosers and one incoming breaker according to an embodiment of the present invention. It is a view showing the line configuration, and FIG. 8 is a view showing a setting value input screen in a line configuration having three reclosers and one incoming breaker according to an embodiment of the present invention, and FIG. 9 is an embodiment of the present invention It is a diagram showing the setting value input screen for the inlet breaker according to the example.

3 to 9 , the user terminal 10 has one recloser (R/C) 30 shown in FIG. 3 and one entry breaker (EFI) 40 on a distribution line composed of one unit. For example, a setting value may be input based on an input screen as shown in FIG. 4 .

A protection coordination correction value for a distribution line having one recloser (R/C) 30 and one entry breaker (EFI) 40 may be input as shown in Table 9 below.

division Time Dial M.R.T. note RA
(recloser) Instantaneous block (F) 0.10 0.12 Phase, Ground
Enter the same value Delay blocking (D) 0.12 0.14 Automatic EFI 0.05 0.05

That is, referring to Table 10, the time dial for instantaneous interruption is 0.10 and the minimum response time is 0.12, the time dial for delay interruption is 0.12, and the minimum response time is 0.14 in case of short circuit and ground fault. Also, the automatic EFI's time dial is 0.05 and M.R T is 0.05.

The user terminal 10 receives the set value input based on the input screen as shown in FIG. 6 for the distribution line in which the recloser 30 shown in FIG. can

division Time Dial M.R.T. note RA1
(Power side recloser) Instantaneous block (F) 0.16 0.18 Phase, Ground
Enter the same value Delay blocking (D) 0.18 0.20 RA2
(load side recloser) Instantaneous block (F) 0.10 0.12 Delay blocking (D) 0.12 0.14 Automatic EFI 0.05 0.05

That is, referring to Table 11, the time dial for instantaneous interruption of the recloser (RA1) 30 is 0.16 and the minimum response time is 0.18, and the time dial for delay interruption is 0.18 and the minimum response time is 0.20. In addition, the time dial for instantaneous interruption of the recloser (RA2) 30 is 0.10 and the minimum response time is 0.12, and the time dial for delay interruption is 0.12 and the minimum response time is 0.14. Also, the automatic EFI's time dial is 0.05 and M.R T is 0.05.

The user terminal 10 receives the set value input based on the input screen as shown in FIG. 8 for the distribution line having three reclosers 30 shown in FIG. can

division Time Dial M.R.T. note RA1
(Power side recloser) Instantaneous block (F) 0.21 0.24 Phase, Ground
Enter the same value Delay blocking (D) 0.23 0.26 RA2
(middle recloser) Instantaneous block (F) 0.16 0.18 Delay blocking (D) 0.18 0.20 RA3
(Power side recloser) Instantaneous block (F) 0.10 0.12 Delay blocking (D) 0.12 0.14 Automatic EFI 0.05 0.05

That is, referring to Table 12, the time dial for instantaneous shutoff of the recloser (RA1) is 0.21 and the minimum response time is 0.24, and the time dial for delay cutoff is 0.23 and the minimum The response time is 0.26. In addition, the time dial for instantaneous interruption of the recloser (RA2) is 0.16 and the minimum response time is 0.18, the time dial for delay interruption is 0.18 and the minimum response time is 0.20, for instantaneous interruption of the recloser (RA3) The time dial is 0.10 and the minimum response time is 0.12, the time dial for delay blocking is 0.12 and the minimum response time is 0.14. Also, the automatic EFI's time dial is 0.05 and M.R T is 0.05.

In addition, the user terminal 10 may receive a setting value for the entry breaker 40 based on the input screen as shown in FIG. 9 .

The server 20 provides a list of protection devices in the entire distribution system according to a request from the user terminal 10 so that the user can select these protection devices.

That is, the user accesses the server 20 through the user terminal 10, selects any one of the list of protection devices registered in the server 20, and refers to the distribution line of the protection device as described above. can be entered.

The user terminal 10 may output the corrected protection coordination standard through the protection device. The user terminal 10 may provide the protection cooperation standard in various forms including text or images. For example, the user terminal 10 may express the corrected protection coordination standard in a graph format.

The user terminal 10 may include a personal computer, a personal digital assistant (PDA), a laptop computer, a smart phone, and the like. The user terminal 10 is not limited to the above embodiment, and various memories and processors are mounted therein to process inputted information, and transmit and receive information to and from the server 20 or a protection device through a wired/wireless communication network through a communication device It is not particularly limited as long as it can be done.

The protection device receives the setting value for correcting the protection coordination standard from the user terminal 10, and defines the protection device operation time against the fault current based on the IEC-VI curve according to the setting value input from the user terminal 10. The protection coordination standard is corrected (S20).

Then, when the protection device detects a fault current, it blocks the fault current in accordance with the protection coordination standard so that the fault current does not flow in the distribution system (S30)

That is, when the recloser 30 receives the setting value from the server 20 as described above, according to the setting value input from the user terminal 10, the recloser 30 determines the operation time of the protection device against the fault current based on the IEC-VI curve. The defined protection coordination standard is corrected, and when a fault current is input, it opens and closes based on the protection coordination standard to protect the distribution system.

The recloser 30 includes a control unit 31 and a blocking unit 32 .

The control unit 31 corrects the protection coordination standard based on the set value input from the user terminal 10 . In addition, the control unit 31 detects the fault current and applies the fault current to the protection coordination standard to close or open the blocking unit 32 .

That is, as described above, the control unit 31 receives the IEC-VI curve, the short-circuit fault current and the ground fault fault current for selecting the minimum operating current of the corresponding protection device, the time dial according to the configuration of the distribution line, and the minimum response time.

Accordingly, the control unit 31 corrects the protection coordination standard by reflecting the short-circuit fault current, the ground fault current, the time dial and the minimum response time according to the configuration of the distribution line in the IEC-VI curve.

The blocking unit 32 is closed or opened according to the control signal of the control unit 31 to block the fault current to protect the distribution system.

When the incoming circuit breaker 40 receives the setting value from the server 20 as described above, it corrects the protection coordination standard using the corresponding setting value, and opens and closes based on the protection coordination standard when a fault current is input to protect the distribution system.

The pull-in circuit breaker 40 includes a control unit 41 and a blocking unit 42 .

The control unit 41 corrects the protection coordination standard based on the set value input from the user terminal 10 . In addition, the control unit 41 detects the fault current and applies the fault current to the protection coordination standard to close or open the blocking unit 42 .

That is, as described above, the control unit 41 receives the IEC-VI curve, the short-circuit fault current and the ground fault fault current for selecting the minimum operating current of the corresponding protection device, the time dial according to the configuration of the distribution line, and the minimum response time.

Accordingly, the control unit 41 corrects the protection coordination standard by reflecting the short-circuit fault current, the ground fault current, the time dial and the minimum response time according to the configuration of the distribution line in the IEC-VI curve.

The blocking unit 42 is closed or opened according to the control signal of the control unit 41 to block the fault current to protect the distribution system.

10 is a view showing a standard correction result for a fault current due to a short-circuit fault according to an embodiment of the present invention, and FIG. 11 is a view showing a standard correction result for a fault current due to a ground fault according to an embodiment of the present invention. the drawing shown. 10 and 11, Lever is the same value as the time dial described above.

That is, the recloser 30 and the pull-in circuit breaker 40 may set the operation time for the fault current as shown in FIGS. 10 and 11 based on the input set value.

In FIG. 10, when the recloser 30 is one unit and the entry breaker 40 is configured as one unit, the recloser 30 is two units and the entry breaker 40 is configured as one unit, and the recloser ( In a distribution line in which 30) is three and the pull-in circuit breaker 40 is one Time was shown.

In FIG. 11 , when the recloser 30 is one unit and the entry breaker 40 is configured as one unit, the recloser 30 is two units and the entry breaker 40 is configured as one unit, and the recloser ( In a distribution line in which 30) is three and the lead-in circuit breaker 40 is one Time was shown.

That is, when a fault current is detected, the recloser 30 and the pull-in breaker 40 can protect the distribution system by blocking the flow of the fault current to the distribution system according to the operation time set for the fault current.

As described above, the distribution system protection device control device according to an embodiment of the present invention uses the IEC-VI characteristic curve to correct the protection coordination standards among various protection groups existing in the distribution line, and protects the distribution system from fault current based on this. do.

In addition, the distribution system protection device control device according to an embodiment of the present invention protects cooperation between one recloser 30 and one EFI unit, even if the distribution system is changed frequently, and between two recloser 30 units and one EFI unit. Protection cooperation and protection cooperation between two reclosers 30 and one EFI unit can be performed simply by protection cooperation review.

In addition, the distribution system protection device control apparatus according to an embodiment of the present invention can minimize the distribution protection coordination operation manpower, and increase the efficiency of the training and the corresponding program for the distribution protection coordination operation manpower.

Implementations described herein may be implemented in, for example, a method or process, an apparatus, a software program, a data stream, or a signal. Although discussed only in the context of a single form of implementation (eg, discussed only as a method), implementations of the discussed features may also be implemented in other forms (eg, as an apparatus or program). The apparatus may be implemented in suitable hardware, software and firmware, and the like. A method may be implemented in an apparatus such as, for example, a processor, which generally refers to a computer, a microprocessor, a processing device, including an integrated circuit or programmable logic device, and the like. Processors also include communication devices such as computers, cell phones, portable/personal digital assistants (“PDA”) and other devices that facilitate communication of information between end-users.

Although the present invention has been described with reference to the embodiments shown in the drawings, this is merely exemplary and those of ordinary skill in the art to which the art pertains are aware that various modifications and equivalent other embodiments are possible therefrom. will understand Accordingly, the true technical protection scope of the present invention should be defined by the following claims.

10: user terminal
20: server
30: recloser
40: incoming breaker

Claims (8)

inputting, by the protection device, a set value for correcting the protection coordination standard from the user terminal; and
and correcting, by the protection device, a protection coordination standard that defines a protection device operating time for a fault current based on an IEC-VI curve according to the set value received from the user terminal. The method of claim 1, wherein the set value is
The time dial and minimum response time of the IEC-VI curve according to the IEC-VI curve, the short-circuit fault current range and the ground fault current range for selection of the minimum operating current, and the number of serially operated protection devices of the distribution line Distribution system protection device control method comprising (Minimum Response Time, MRT). The method of claim 2, wherein the protection device is
A distribution system protection device control method, characterized in that the protection coordination standard is corrected by reflecting the time dial and the MRT according to the short-circuit fault current, the ground fault current, and the configuration of the distribution line in the IEC-VI curve. The method according to claim 2, wherein the short-circuit fault current is 2.8 to 4 times or more of the maximum load current at the installation point of the protection device and less than or equal to the minimum operating current in the back-up (power side) protection device. The method according to claim 2, wherein the ground fault current is 0.3 times or more of the maximum load current at the installation point of the protection device and less than or equal to the minimum operating current of the back-up (power side) protection device. 3. The method of claim 2, wherein the distribution line is
Distribution system protection device control, characterized in that one recloser and one incoming breaker, two reclosers and one incoming breaker, or three reclosers and one incoming breaker method. The time dial of the IEC-VI curve and the minimum response time are
Distribution system protection device control method, characterized in that the distribution line is individually set for instantaneous interruption and delayed interruption when the distribution line is a short-circuit failure and a ground-fault failure. The distribution system protection according to claim 1, further comprising the step of blocking the fault current so that the fault current does not flow in the distribution system according to the protection coordination standard when the protection device detects the fault current. How to control the device.

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