CN112054493A - A method for mode operation of in-situ feeder automation function of distribution lines - Google Patents

Abstract

The method comprises the steps of carrying out terminal automation function testing, formulating an automation and protection configuration scheme according to the characteristics of a line, carrying out software updating and parameter setting on the terminal on site, and observing the operation condition. The commissioning method can provide standardized and stylized steps for the distribution line on-site feeder automation commissioning, provides scientific basis for the setting of the switch position, improves the effectiveness and the reasonableness of the setting, and can provide scientific basis for the planning and designing department to carry out line planning and design, the operation and maintenance department to carry out line transformation work and the like.

Description

A method for mode operation of in-situ feeder automation function of distribution lines

technical field

The invention relates to a method for putting into operation mode of an on-site feeder automation function of a distribution line, and belongs to the technical field of distribution line feeder automation.

Background technique

With the development of economy and society, power users have higher power supply reliability requirements for reliable power supply systems, and the processing efficiency of faults has a profound impact on power supply reliability. In-situ feeder automation can realize automatic fault isolation and automatic recovery of non-fault areas through voltage-time terminal control switch opening and closing.

According to the line structure, it can be divided into two types of local feeder automation: single-radiation line and tie line. The local feeder automation line is divided into several sections by the start switch and multiple voltage-time segment switches. The action principle can be summarized as the start switch The two-time reclosing cooperates with the sectional switch to open and close. The first reclosing will block the switch on both sides of the fault point to isolate the fault; the second reclosing will restore the power supply to the non-faulty area on the power supply side. Specifically, when a fault occurs, the start-end switch trips, the voltage-time switch on the whole line loses voltage and opens, the start-end switch recloses for the first time, and each voltage-time type switch is energized and closed one by one until the fault is closed, and the start-end switch trips again. At the same time, the voltage-time switches before and after the fault point are blocked by overcurrent and residual voltage, and will not be closed after the next power on; , if there is a tie line, the tie switch will be closed according to the set time sequence to restore the non-fault area behind the fault point.

The advantages of on-site feeder automation include: 1) The switch has the function of two remotes (telemetry, remote signaling); 2) The voltage type switch has the characteristics of "delayed closing of incoming calls, and release without pressure", and the action is reliable; 3) The outgoing switch can be reclosed twice to complete the fault location and isolation; 4) When the fault is not in the first section of the line, the outgoing switch can always be reclosed successfully.

However, in the actual application process of in-situ feeder automation, it is plagued by problems such as many manufacturers, various terminal control software versions, inconsistent automation logic, difficulty in coordinating protection and automation, and inconsistent on-site operation and maintenance methods, which affect the application of automation. Level. At the same time, the local feeder automation also has the following weaknesses: 1) It is necessary to configure the "delay closing" X time limit of all switches, and two switches cannot be closed at the same time; 2) When adjusting the operation mode, it is necessary to adjust the delay of related switches at the same time parameter configuration. 3) When the power supply side switch at the fault point fails to lock, it will cause the outlet switch to repeatedly reclose to the fault; 4) When the residual voltage of the load side switch at the fault point fails to lock, it will cause the tie switch to be closed to the fault point (two phases of the line voltage used). 5) When the PT on one side of the tie switch is disconnected, if the terminal is not recognized, it will cause the tie switch to close automatically.

SUMMARY OF THE INVENTION

The purpose of the present invention is, in order to realize the mode operation of the automatic line and improve the operation efficiency of the local feeder automation function of the distribution line, the present invention proposes a method for the mode operation of the local feeder automation function of the distribution line.

The technical solution for realizing the present invention is as follows, a method for putting into operation in-situ feeder automation function of distribution lines. Update and parameter setting, observe the operation situation, adopt the technical scheme mainly based on the local feeder automation, realize the mode operation of the automatic line, and improve the operation efficiency of the local feeder automation function of the distribution line.

The terminal automation function test is to carry out a unified test of the automation functions of all manufacturers to determine the automation software versions of each manufacturer that can be run on site; the function verification includes: terminal voltage loss (including short delay) trip logic, Incoming call delay closing, fault blocking logic, liaison switch locking and power transmission logic, terminal debugging mode logic; during the test, no less than 4 intelligent terminals should carry out joint debugging, and the debugging content includes contact mode test and single radiation mode test.

The contact mode includes a start switch CB, a contact switch LL, and the rest are segment switches D01, D02, etc. The debugging should simulate faults in at least three areas, between the start switch CB and the segment switch D01. , between the segment switch D01 and the segment switch D02, and between the segment switch D02 and the tie switch LL.

The single radiation mode includes a start switch CB, a tie switch LL, and the rest are segment switches D01, D02, etc. The debugging should simulate faults in at least four areas, the difference between the start switch CB and the segment switch D01. The faults in four areas, including the area surrounded by the three switches D01, D02, and D03, the area behind the switch D02, and the area behind the switch D03.

The formulating automation and protection configuration scheme includes single radiating lines and tie lines.

In the process of formulating the plan, the following principles are followed: 1) Give full play to the automation function of the local feeder to minimize the scope of power outages; 2) Combine automation and protection to minimize the number of trips to improve the user's experience with electricity; 3 ) The solution must be in line with the characteristics of the circuit, and the switch position should not be moved as much as possible.

(1) Single radiation line automation and protection configuration scheme

The line contains 3 large branches, a total of 6 automatic switches D01, F01, F02, F03, F04 and F09 are set up, of which D01, F01 are located on the main line, and the other 4 switches are located on the three branch lines, of which F02, F03 switches On the same branch line; the configuration protection automation scheme is as follows:

1) The outlet switch is set to protect, the overcurrent stage I is 2100A/0s; the overcurrent stage II is 1200A/0.2s; the overcurrent stage III is 330A/0.5s;

2) D01 switch does not switch on protection, switch on automatic function, X time limit is 21s, Y time limit is 5s, and zero sequence protection alarm is 3A/20s;

3) F02 switch does not switch on protection, switch on automatic function, X time limit is 14s, Y time limit is 5s, and zero sequence protection alarm is 3A/18s;

4) Four switches such as F03, F01, F04, and F09 are all switched on for protection and automation. The overcurrent stage I cooperates with the overcurrent stage II of the outgoing switch, and the overcurrent stage II cooperates with the overcurrent stage III of the outgoing switch;

(2) Contact line automation and protection configuration scheme

The line is a hand-in-hand connection line. The line is connected to another 10kV line on the opposite side, including a large branch. A total of 3 automatic switches, D01, D02 and tie switch L30 are set up; the settings of each switch are as follows:

1) The outlet switch is set to protect, and the overcurrent stage I exits; the overcurrent stage II is 1500A/0.2s; the overcurrent stage III is 330A/0.4s;

2) D01 switch protection, overcurrent I stage 1200A/0s; overcurrent II stage 300A/0.2s, zero sequence protection alarm 3A/18s;

3) D02 switch does not switch on protection, switch on automatic function, X time limit is 7s, Y time limit is 5s, and zero sequence protection alarm is 3A/20s;

4) The tie switch L30 is switched to the automatic mode of the tie switch, the X time limit is 21s, and the Y time limit is 5s.

The software update and parameter setting for the terminal are as follows: firstly, according to the software version that has passed the test, the software of the corresponding model terminal is updated, including checking the point table with the master station; then according to the protection automation configuration scheme, set Protection of fixed value and automation parameter information; if conditions permit, the relevant fault sequence should be set on this basis, and then the terminal is tested on a single unit. After the test is successful, the terminal can be put into automatic operation and the automation function is officially activated.

For the observation of operation conditions, after the automation function is put into operation, the remote signaling and telemetry information of the terminal and the main station should be checked in a timely manner, and the operation conditions should be tracked and observed; especially after a fault occurs, it should be checked whether the fault point is consistent with the automatic positioning results, and the protection and Whether the automated action is correct; if an abnormal situation occurs, find the problem and adjust and optimize it according to the situation.

The technical solution based on the on-site feeder automation is as follows:

When a fault occurs, the outlet switch with protection is tripped first, the whole line is powered off, the voltage time switch arranged on the line detects the loss of voltage and trips, the outlet switch is reclosed, and each voltage time switch restores power supply step by step until it is closed. When the fault trips again, the voltage-time switch controller FTU locks the switch through the residual voltage, and will not close the switch next time when the power is turned on, thus completing the function of the first reclosing to locate the fault; Close the switch again and gradually restore the non-faulty area.

The beneficial effect of the present invention is that, the method of the present invention realizes the automated line mode commissioning according to the steps of carrying out the terminal automatic function test, formulating the automation and protection configuration scheme according to the line characteristics, performing software update and parameter setting on the line on site, and observing the operation situation. , which improves the commissioning efficiency of the local feeder automation function of the distribution line and improves the operation reliability. The method proposed by the invention can provide standardized and stylized steps for the commissioning of the local feeder automation of the distribution line, provide a scientific basis for the setting of the switch position, improve the effectiveness and rationality of the setting, and can be used for planning and design departments. Provide scientific basis for line planning and design, and operation and maintenance departments to carry out line renovation work.

Description of drawings

Fig. 1 is the schematic diagram of the commissioning steps of the power distribution automation terminal of the present invention;

Figure 2 is a schematic diagram of the fault point between the start-end switch and the segment switch of the tie line;

Figure 3 is a schematic diagram of a fault point between two segment switches of a tie line;

Figure 4 is a schematic diagram of the fault point between the tie line segment switch and the tie switch;

Figure 5 is a schematic diagram of the fault point between the start switch and the segment switch of a single radiation line;

6 is a schematic diagram of a fault point between multiple segment switches of a single radiation line;

Figure 7 is a schematic diagram of the fault point in the rear side of the single-radiation line segment switch to the end area;

Figure 8 is a schematic diagram of the fault point in the area behind the single-radiation line segment switch;

Fig. 9 is a schematic diagram of physical simulation platform wiring;

Figure 10 is a schematic diagram of an automated tester combined testing method;

Figure 11 is the version number of the local automation program of a certain type of terminal;

Figure 12 is a schematic diagram of the structure of a single radiation circuit;

Figure 13 is a diagram of the automation and protection configuration of a 10kV single-radiation in-situ feeder;

Figure 14 is the configuration diagram of local feeder automation and protection of a 10kV tie line;

Figure 15 is a schematic diagram of the automatic operation of a single-radiation line in-situ feeder;

Fig. 16 is a schematic diagram of the local feeder automation of the hand-in-hand distribution line.

Detailed ways

As shown in FIG. 1 , a method for putting into operation in-situ feeder automation function of a distribution line in this embodiment includes the following steps: 1) carrying out a terminal automation function test; 2) formulating an automation and protection configuration scheme according to line characteristics; 3) Perform software update and parameter setting on the terminal on site; 4) Observe the operation and other steps.

Step 1 Carry out the terminal automation function test:

Due to the large number of distribution automation equipment manufacturers, according to incomplete statistics, there are more than 400 distribution automation equipment manufacturers nationwide. At present, there is no national standard for local feeder automation products. Each manufacturer's equipment appearance, structure and function The settings and automation logic are different. Therefore, before the automation is put into operation on site, the automation functions of all manufacturers must be tested uniformly to determine the automation software version of each manufacturer that can be run on site. Among them, functional verification includes: terminal voltage loss (including short delay) trip logic, incoming delay closing, fault blocking logic, contact switch blocking and power transmission logic, terminal debugging mode logic, etc.

In the test process, no less than 4 intelligent terminals should carry out joint debugging, and the content of debugging includes two types of test: contact mode test and single radiation mode test.

(1) Contact mode

The contact mode includes a start switch CB, a contact switch LL, and all the rest are segment switches D01, D02, etc. The debugging should simulate faults in at least three areas. The distance between the start switch CB and the segment switch D01 Faults in three areas between segment switch D01 and segment switch D02, and between segment switch D02 and tie switch LL.

Fault section 01: The fault is located between the start switch CB and the segment switch D01, as shown in Figure 2.

At this time, the actions of each switch are as follows: ① The switch CB at the starting end trips, and the switch D01 and switch D02 lose power immediately. After the power loss, they are all opened after the delay time Δt, and the switch LL does not operate and maintains the original opening state; ② The starting end The switch CB is reclosed for the first time. If the fault is a transient fault, the reclosing is successful, and the switch _D01 and switch _D02 are powered on successively. Power supply; if the fault is a permanent fault, the reclosing fault still exists, the start-end switch CB trips for the second time, and the switch _D01 receives the residual voltage signal and automatically blocks immediately; Then, after the sectional switch D02 is energized, the sectional switch D02 and the sectional switch will be restored after the power delay time limit Δt _D02 . Power supply for the line between D02. At this point, the automatic action process of the local feeder is over.

Fault section 02: The fault is located between the segment switch D01 and the segment switch D02, as shown in FIG. 3 .

At this time, the actions of each switch are as follows: ① The switch CB at the starting end trips, and the switch D01 and switch D02 lose power immediately. After the power loss, they are all opened after the delay time Δt, and the switch LL does not operate and maintains the original opening state; ② The starting end The switch CB is reclosed for the first time, and the reclosing is successful. After the switch D01 is electrified, the switch _D01 is closed after the delay time Δt. If the fault is a transient fault, the switch D02 is closed after the delay time Δt _D02 . Line fault automatically restores power supply; if the fault is a permanent fault, the fault still exists after D01 is energized and closed, the start switch CB trips for the second time, and the switch D01 and switch D02 receive the residual voltage signal at the same time, and automatically block immediately; ③Start switch CB is reclosed for the second time to restore the power supply of the line between the start switch CB and the section switch D01; ④ The tie switch LL is closed after the power delay time limit Δt _LL time limit, and the tie switch LL and the tie switch LL are restored from the opposite side line. Power supply to the line between segment switch D02. Section switch D01 and section switch D02 are both blocked, and the fault is located between the two switches. At this point, the automatic action process of the local feeder is over.

Fault section 03: The fault is located between the section switch D02 and the tie switch LL, as shown in Figure 4.

At this time, the actions of each switch are as follows: (1) The start switch CB trips, and the segment switch D01 and switch D02 lose power immediately. After the power loss, they are all opened after the delay time Δt, and the switch LL does not operate, maintaining the original opening state; ②The first reclosing of the start switch CB, the reclosing is successful, after the switch D01 is energized, the switch D01 is closed after the power delay time limit Δt _D01 , and then the switch D02 is closed after the power delay time limit Δt _D02 , if the fault is Instantaneous fault, the line fault automatically restores power supply; if the fault is a permanent fault, the reclosing fault still exists, the start switch CB trips for the second time, and the switch D02 and switch LL receive the residual voltage signal, and automatically block immediately; ③ The start switch CB is reclosed for the second time to restore the power supply of the line between the start switch CB and the segment switch D01. After the switch D01 is energized, _D01 is closed after the delay time Δt, and then the switch D02 is energized after the delay time. The time limit Δt _D02 is closed, and the power supply is restored in the non-fault area. Section switch D02 and tie switch LL are blocked, and the fault is located between the two switches. So far, the automatic action process of the local feeder is over.

The opening delay time Δt is used to avoid voltage sags caused during grid fault handling and fluctuations caused during grid operation; in some embodiments, the delay time Δt satisfies: 0.3s≤Δt≤1s. In some embodiments, the delay time Δt satisfies: 0.3s≤Δt≤0.5s. In some embodiments, the delay time Δt satisfies: Δt=0.5s.

(2) Single radiation mode

The single radiation mode includes a start switch CB, a tie switch LL, and the rest are segment switches D01, D02, etc. The debugging should simulate faults in at least four areas. Between the start switch CB and the segment switch D01, Faults in four areas: the area surrounded by the three switches D01, D02, and D03, the area behind the switch D02, and the area behind the switch D03.

Fault section 01: The fault is located between the start switch CB and the segment switch D01, as shown in Figure 5.

At this time, the actions of each switch are as follows: ① The start switch CB trips, and the segment switches D01, D02, and D03 lose power immediately, and they all open after the delay time Δt after power loss; ② The start switch CB is reclosed for the first time, if the fault occurs It is a transient fault, the reclosing is successful, the switch D01, switch D02, and switch D03 are energized successively, and they are closed after the respective power-on delay time limits Δt _D01 , Δt _D02 , and Δt _D03 , and the line fault automatically restores power supply; if the fault occurs It is a permanent fault, the reclosing fault still exists, the switch CB trips for the second time, and the switch D01 receives the residual voltage signal, and automatically locks it immediately. The fault point is located between the start switch CB and the segment switch D01, so far the automatic action process of the local feeder is over.

Fault section 02: The fault is located in the area surrounded by the three switches D01, D02 and D03, as shown in Figure 6.

At this time, the actions of each switch are as follows: ① The start switch CB trips, and the segment switches D01, D02, and D03 lose power immediately, and they all open after the delay time Δt after power loss; ② The start switch CB is reclosed for the first time, and the reclosing After the switch D01 is energized, the switch _D01 closes after the delay time Δt, if the fault is a transient fault, the switch _D02 is closed after the delay time Δt, and the switch D03 is closed after the delay time Δt. _D03 is closed for a time limit, and the line fault automatically restores power supply; if the fault is a permanent fault, the fault still exists after D01 is powered on and closed, the start switch CB trips for the second time, and the switch D01 receives the residual voltage overcurrent signal, D02, D03 After receiving the residual voltage signal, the three switches are automatically blocked immediately; ③ The start switch CB is reclosed for the second time, and the line power supply between the start switch CB and the segment switch D01 is restored. The fault is located in the area between the rear side of sectional switch D01 and switches D02 and D03. At this point, the automatic action process of the local feeder is over.

Fault section 03: The fault is located in the area behind the segment switch D02, as shown in Figure 7.

At this time, the actions of each switch are as follows: ① The start switch CB trips, and the segment switches D01, D02, and D03 lose power immediately, and they all open after the delay time Δt after power loss; ② The start switch CB is reclosed for the first time, and the reclosing After the switch D01 is energized, _D01 closes after the delay time Δt, if the fault is a transient fault, the switch _D02 is closed after the delay time Δt, and then D03 is energized after the delay time Δt _D03 is closed at time limit, and the line fault will automatically restore power supply; if the fault is a permanent fault, the fault still exists after D02 is energized and closed, the start switch CB will trip for the second time, and the switch D02 will receive the residual voltage overcurrent signal and automatically automatically Blocking; ③ The start switch CB is reclosed for the second time, and the line power supply between the start switch CB and the segment switch D01 is restored, and then D03 is powered on after the power-on delay time limit Δt _D03 is closed, and the non-fault area resumes power supply. The fault is located in the area between the rear sides of the sectional switch D02, and the automatic action process of the local feeder has ended.

Fault section 04: The fault is located in the area behind the segment switch D03, as shown in Figure 8.

At this time, the actions of each switch are as follows: ① The start switch CB trips, and the segment switches D01, D02, and D03 lose power immediately, and they all open after the delay time Δt after power loss; ② The start switch CB is reclosed for the first time, and the reclosing Success, after switch D01 is energized, _D01 closes after the power-on delay time Δt, D02 is powered on after the power-on delay time Δt _D02 is closed, if the fault is a transient fault, D03 is powered on after the power-on delay time Δt _D03 is closed at time limit, and the line fault will automatically restore power supply; if the fault is a permanent fault, the fault still exists after D03 is energized and closed, the start switch CB will trip for the second time, and the switch D03 will receive the residual voltage overcurrent signal and automatically lock immediately ; ③ The second reclosing of the start switch CB to restore the power supply of the line between the start switch CB and the segment switch D01, and then the power supply of D02 is closed after the power delay time limit Δt _D02 , and the power supply is restored to the non-fault area. The fault is located in the area between the rear sides of the sectional switch D03, and the automatic action process of the local feeder has ended.

Among them, the opening delay time Δt is used to avoid the voltage sag caused in the process of grid fault processing and the fluctuation caused by the grid operation process. In some embodiments, the delay time Δt satisfies: 0.3s≤Δt≤1s. In some embodiments, the delay time Δt satisfies: 0.3s≤Δt≤0.5s. In some embodiments, the delay time Δt satisfies: Δt=0.5s.

(3) Specific implementation of terminal test

The terminal function test can be carried out in a variety of ways. In some embodiments, a physical simulation platform test method is used to carry out the terminal automation function test, and the physical simulation platform builds a distribution line simulation system, as shown in Figure 9. In the figure, E is Power supply, L1, L2, L3 are the three lines powered by power supply E, K1 simulates the start switch of line L2, K2, K3 respectively simulate the segment switch of line L2, K4 simulates the contact switch of line L2 and line L1, each switch The opening and closing are controlled by the terminal of the model to be tested. In the test process, the fault between the K1 and K2 switches is simulated; the fault between the K2 switch and the K3 switch; the fault between the K3 switch and the K4 switch (contact switch). For the faults in each section of the test, each switch is controlled by the intelligent terminal, and the switch action should be consistent with the action in the above-mentioned fault conditions. During the test, if a functional error is found, the software problem should be found, and the on-site modification and adjustment should be carried out in time. .

In some embodiments, a combined testing method of multiple automated functional testers is used. The automatic tester can output any changing three-phase current and three-phase voltage signals, and also contains a simulated circuit breaker, which can simulate the switch controlled by the terminal. The joint test method requires at least four automated testers and four terminals, and wiring between the two needs to be done. The wiring includes data lines such as current, voltage, and signal, as shown in Figure 10. The terminal 01 and the simulated circuit breaker act as the start switch, the terminals 02, 03 and the simulated circuit breaker act as two segment switches, and the terminal 04 and the simulated circuit breaker act as the tie switch; The circuit breaker status output sequence simulates 5 different types of faults, including normal status, faults between terminals, and faults on the opposite side of the tie switch. Each sequence is based on the local feeder automation logic to simulate the current, voltage and Changes in switch position.

Before the test, each automatic tester must set up multiple sets of voltage and current output solutions, each set of solutions corresponds to a fault occurrence section, during the test process, observe the terminal control switch action of each switch; If the ground-type automation action logic is consistent, it means that the terminal software is correct; otherwise, technicians need to adjust the terminal software on-site, and finally determine the correct software version for all actions.

Figure 11 shows the automation software version of a certain type of smart terminal.

Step 2 Develop an automation and protection configuration scheme:

Before the local feeder automation is put into operation, the protection configuration scheme and automation scheme should be determined according to the line structure and switch distribution characteristics. In the process of formulating the scheme, the following principles should be followed: 1) Give full play to the local feeder automation function and minimize the 2) The combination of automation and protection, to minimize the number of trips, to improve the user's power experience; 3) The solution must be in line with the characteristics of the line, and the switch position should not be moved as much as possible.

(1) Single Radiation Line Configuration Scheme

A line is a single-radiation line, the line contains 3 large branches, a total of 6 automatic switches D01, F01, F02, F03, F04 and F09 are set, of which D01, F01 are located on the main line, and the other 4 switches are located on the three branch lines. On the line, the switches F02 and F03 are located on the same branch line. Figure 12 shows a schematic diagram of the circuit.

After calculation and analysis, it is found that four switches, such as switches F01, F03, F04 and F09, are in roughly the same position, and the positions are within the effective range of the hierarchical protection configuration. Therefore, these four switches are set to protect, so that the four switches can be guaranteed. Subsequent faults are directly isolated by these four switch actions, which reduces the range of power outages and reduces the number of front-end switch actions. The D01 and F02 switches are set with automatic logic, which can ensure that when the part between these two switches and the four switches set for protection fails, the power supply in the upstream non-faulty area will not be dragged down.

Based on this idea, configure the protection automation scheme as follows, as shown in Figure 13.

1) The outlet switch is set to protect, the overcurrent stage I is 2100A/0s; the overcurrent stage II is 1200A/0.2s; the overcurrent stage III is 330A/0.5s;

2) D01 switch does not switch on protection, switch on automatic function, X time limit is 21s, Y time limit is 5s, and zero sequence protection alarm is 3A/20s;

3) F02 switch does not switch on protection, switch on automatic function, X time limit is 14s, Y time limit is 5s, and zero sequence protection alarm is 3A/18s;

4) Four switches such as F03, F01, F04, and F09 are all switched on for protection and automation. The overcurrent stage I cooperates with the overcurrent stage II of the outgoing switch, and the overcurrent stage II cooperates with the overcurrent stage III of the outgoing switch.

(2) Contact line configuration scheme

The line is a hand-in-hand connection line, and the line is connected to another 10kV line on the opposite side, including a large branch, and a total of 3 automatic switches, D01, D02 and tie switch L30. Since the D01 switch is set not far from the outgoing switch of this line, in order to make full use of each switch, when formulating the plan, D01 is set to protect and reclose twice, and the outgoing switch is also set to protect. Because it is too close to the D01 switch, it cannot pass through. The current realizes grading protection, so the quick-break protection of the 913 switch in the station is withdrawn, and the D01 relies on the time difference to achieve incomplete coordination. The other two switches D02 and L30 are put into operation respectively with automatic logic, and fault isolation is realized through the local type voltage and time type action logic. and automatic power recovery.

The protection automation scheme of each switch configuration is as follows, as shown in Figure 14.

1) The outlet switch is set to protect, and the overcurrent stage I exits; the overcurrent stage II is 1500A/0.2s; the overcurrent stage III is 330A/0.4s;

2) D01 switch protection, overcurrent I stage 1200A/0s; overcurrent II stage 300A/0.2s, zero sequence protection alarm 3A/18s;

3) D02 switch does not switch on protection, switch on automatic function, X time limit is 7s, Y time limit is 5s, and zero sequence protection alarm is 3A/20s;

4) The tie switch L30 is switched to the automatic mode of the tie switch, the X time limit is 21s, and the Y time limit is 5s.

Step 3 Perform software update and parameter setting on the line on site:

Due to the needs of automation construction, most of the automatic switches in actual production are put into operation in the power grid before the automation coordination logic is realized. Therefore, the operation of the automation function requires the settings of the switches and controllers in operation. Therefore, after the previous work is fully prepared, the next step is to update the software and set parameters for the automation equipment running the line on site.

The setting method is as follows: First, according to the software version that has passed the test, update the software of the corresponding type of terminal, including checking the point table with the master station; then, according to the protection automation configuration scheme, set the protection settings, automation parameters and other information. If conditions permit, the relevant fault sequence should be set on this basis, and then the terminal is tested on a single unit. After the test is successful, the terminal can be put into automatic operation and the automation function is officially activated.

In the process of putting into operation, the following matters should be noted: 1) When updating the software version or setting parameters, exit the terminal opening and closing pressure plate; 2) For the switch with double-sided PT, check the aviation plug of the double-sided PT switch and the terminal of the terminal. The correctness of the connection of the plug connector; 3) Knife switches should be provided on both sides of the tie switch; 4) If the voltage loss opening can be set, the value should be between 0.3s-1.0s, etc.

Step 4 Observe the operation:

After the automation function is put into operation, the remote signaling and telemetry information of the terminal and the main station should be checked in a timely manner, and the operation status should be tracked and observed. Especially after a fault occurs, it should be checked whether the fault point is consistent with the automatic positioning results, and whether the protection and automatic actions are correct; If an abnormal situation occurs, you should find the problem and adjust and optimize it according to the situation.

The technical solution based on the local feeder automation in this embodiment is as follows:

When the feeder fails, the outlet switch with protection is tripped first, the whole line is powered off, the voltage time switch arranged on the line detects the loss of voltage and trips, the outlet switch is reclosed, and each voltage time switch restores power supply step by step until it is closed. When the switch is on until the fault trips again, the voltage-time switch controller FTU locks the switch through the residual voltage, and will not close the switch next time when the power is turned on, thus completing the function of the first reclosing to locate the fault; Re-closing, and gradually restore the non-fault area.

For the two types of lines, radiating line and tie line, the essence of using local feeder automation to realize section location is the same, that is, to realize fault location by starting switch reclosing and voltage-time FTU. The processing principles of the two types of lines are as follows :

(1) In-situ feeder automation scheme for single radiation line

For single radiating lines, the local feeder automation can only recover the larger the non-fault area when the terminal fails. If a fault occurs at the beginning, the rear non-fault area cannot be restored because there is no power supply from the connecting line. Figure 15 shows the schematic diagram of the automatic action of the in-situ feeder of the single-radiation line.

(2) In-situ feeder automation scheme of contact line

As shown in Figure 16, it is a schematic diagram of the action of the hand-in-hand contact line. If it is a transient fault, it will automatically avoid and resume power transmission; if it is a permanent fault, it will trip again; after the fault isolation is completed, the normal section power supply will be restored.

Local type feeder automation, using voltage type switch, electromagnetic type mechanism, super capacitor power supply; switch two remote; voltage type switch has the characteristics of "delayed closing of incoming calls, release without pressure", reliable action; outgoing switch twice Coincidence completes fault location and isolation. For the first reclosing, the switches on both sides of the fault point are blocked to isolate the fault; for the second reclosing, the power supply in the non-faulty area on the power supply side is restored; when the first section of the line is not faulty, the outgoing switch can always be reclosed successfully.

Claims (8)

1. A method for putting into operation in situ feeder automation functions of distribution lines, characterized in that, the method is carried out according to carrying out terminal automation function tests, formulating automation and protection configuration schemes according to line characteristics, and performing software update and Parameter setting, observing the operation situation, adopting the technical scheme mainly based on in-situ feeder automation, realizing the mode operation of the automatic line, and improving the operation efficiency of the in-situ feeder automation function of the distribution line. 2. a kind of distribution line local type feeder automation function modelized commissioning method according to claim 1, is characterized in that, described carrying out terminal automation function test, is to carry out unified test to the automation function of all manufacturers, with Determine the automation software version of each manufacturer that can be run on site; the functional verification includes: terminal voltage loss trip logic, incoming call delay closing, fault blocking logic, contact switch lock and power transmission logic, terminal debugging mode logic; during the test process , there should be no less than 4 intelligent terminals to carry out joint debugging, the content of debugging includes contact mode test and single radiation mode test. 3. The method for putting into operation in situ feeder automation function of a distribution line according to claim 1, wherein the formulating an automation and protection configuration scheme comprises a single radiating line and a tie line; In the process, the following principles are followed: 1) Give full play to the automation function of the local feeder, and minimize the scope of power outages; 2) Combine automation and protection to minimize the number of trips to improve the user's experience with electricity; 3) The scheme must fit Circuit characteristics, try not to move the switch position. 4. a kind of power distribution line local type feeder automation function patterned operation method according to claim 1, is characterized in that, described to carry out software update and parameter setting to terminal, setting method is as follows: first pass according to the test According to the software version of the corresponding model, update the software of the corresponding type of terminal, including checking the point table with the master station; then set the protection setting value and automation parameter information according to the protection automation configuration plan; if conditions permit, it should be based on this basis. Set the relevant fault sequence, and then test the terminal unit. After the test is successful, the terminal can be put into automatic operation, and the automation function is officially activated. 5. The method for putting into operation mode of local feeder automation function of distribution lines according to claim 1, wherein the observation of the operation situation, after the automation function is put into operation, the terminal and the main station should be checked in a timely manner In particular, after a fault occurs, it should be checked whether the fault point is consistent with the automatic positioning results, and whether the protection and automatic actions are correct; if an abnormal situation occurs, the problem should be found and adjusted according to the situation optimization. 6 . The method for putting into operation a distribution line in situ feeder automation function according to claim 1 , wherein the technical scheme mainly based on the in situ feeder automation is as follows: 7 . When a fault occurs, the outlet switch with protection is tripped first, the whole line is powered off, the voltage time switch arranged on the line detects the loss of voltage and trips, the outlet switch is reclosed, and each voltage time switch restores power supply step by step until it is closed. When the fault trips again, the voltage-time switch controller FTU locks the switch through the residual voltage, and will not close the switch next time when the power is turned on, thus completing the function of the first reclosing to locate the fault; Close the switch again and gradually restore the non-faulty area. 7 . The method for putting into operation in situ feeder automation function of a distribution line according to claim 2 , wherein the connection mode comprises a start switch CB, a tie switch LL, and the remaining All are segment switches D01 and D02. The debugging should simulate faults in at least three areas, between the start switch CB and the segment switch D01, between the segment switch D01 and the segment switch D02, between the segment switch D02 and the tie switch LL failure of the three areas in between. 8 . The method for putting into operation in situ feeder automation functions of distribution lines according to claim 2 , wherein the single radiation mode comprises a starting switch CB, a tie switch LL, and the remaining 8 . All are segment switches D01 and D02, and debugging should simulate faults in at least four areas, between the start switch CB and segment switch D01, the area surrounded by segment switches D01, D02, and D03, and segment switch D02 Faults in the rear side area and the rear side area of the segment switch D03.

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