A relay protection core setting management method based on a network GIS system

Abstract

The application relates to the technical field of distribution network relay protection, in particular to a relay protection core fixed value management method based on a distribution network GIS system, which can solve the problem that the process of operation personnel sequentially searching for the relay protection fixed value of corresponding switches in the system is relatively complicated. The method comprises the following steps: obtaining relay protection core fixed values of a distribution network line; obtaining primary values of current fixed values corresponding to each component of the distribution network line, wherein the primary values of the current fixed values of each component are obtained by converting secondary values based on relay protection core current fixed values of the distribution network line; drawing a GIS single-line sketch of the distribution network line, wherein the GIS single-line sketch of the distribution network line is obtained based on a GIS single-line diagram of the distribution network line; and marking the primary values of the current fixed values corresponding to each component of the distribution network line into the GIS single-line sketch of the distribution network line to form a distribution network relay protection fixed value matching diagram.

Description

Technical Field

[0001] This application relates to the field of distribution network relay protection technology, and more specifically, to a method for managing the core settings of relay protection based on a distribution network GIS system. Background Technology

[0002] In recent years, with the continuous improvement of the reliability of power distribution network and the requirements of power supply service system, higher standards have been put forward for the operation and management of distribution network. The correct operation of distribution network relay protection, accurate isolation of faults, and rapid restoration of power supply to non-faulty areas are indispensable parts of the modern power supply service system.

[0003] In the actual operation of some power distribution networks, distribution automation terminals (FTUs), distribution network intelligent terminals, and other distribution network protection and control devices are connected to the distribution network. When operators need to adjust the distribution network operation mode during maintenance, they need to check the core settings of the relay protection in advance. During the check process, the protection settings of the corresponding switches are repeatedly searched from the system and checked.

[0004] However, due to the large number and wide distribution of smart terminals in the distribution network, the process of operators searching for the relay protection settings of the corresponding switches in the system is cumbersome, resulting in low efficiency for operators to verify the core relay protection settings. Summary of the Invention

[0005] To address the cumbersome process of operators sequentially searching for the relay protection settings of corresponding switches in the system, this application provides a method for managing the core relay protection settings based on a distribution network GIS system.

[0006] The embodiments of this application are implemented as follows:

[0007] This application provides a method for managing the core settings of relay protection based on a distribution network GIS system. The method includes:

[0008] The core setting value of the relay protection of the distribution network line is obtained based on the relay protection setting value sheet of the distribution network line. The core setting value of the relay protection of the distribution network line includes the secondary value of the core current setting value of the relay protection of the distribution network line.

[0009] Obtain the primary value of the current setting corresponding to each component of the distribution network line. The primary value of the current setting of each component is obtained by conversion based on the secondary value of the core current setting of the relay protection of the distribution network line.

[0010] Draw a simplified GIS single-line map of the distribution network line, wherein the simplified GIS single-line map of the distribution network line is obtained based on the GIS single-line map of the distribution network line;

[0011] The primary values ​​of the current settings corresponding to each component of the distribution network line are marked on the simplified GIS single-line diagram of the distribution network line to form the distribution network relay protection setting coordination diagram.

[0012] In some embodiments, the method further includes, during the process of obtaining the primary values ​​of the current settings corresponding to each component of the distribution network line:

[0013] Based on the relay protection setting sheet of the distribution network line, obtain the secondary value corresponding to the current transformer ratio and the core setting of the relay protection of the distribution network line. Then, obtain the primary value of the current setting corresponding to each component of the distribution network line through the secondary value corresponding to the current transformer ratio and the core setting of the relay protection of the distribution network line.

[0014] In some embodiments, the method for obtaining the primary values ​​of the current settings corresponding to each component of the distribution network line includes:

[0015] The primary value of the current setting corresponding to each component of the distribution network line = the secondary value of the core current setting of the relay protection of the distribution network line × the transformation ratio of the current transformer of the setting unit.

[0016] In some embodiments, the method further includes, during the process of obtaining the primary values ​​of the current settings corresponding to each component of the distribution network line:

[0017] When the core setting of the relay protection of the distribution network line is obtained as a voltage-time type setting, it is not necessary to convert the secondary value of the current setting corresponding to each component into the corresponding primary value.

[0018] In some embodiments, during the process of obtaining the core settings of the relay protection for a distribution network line, the relay protection setting sheet for the distribution network line includes:

[0019] Primary circuit breaker protection setting sheet, main line voltage-time type setting sheet and branch line current-time type setting sheet.

[0020] In some embodiments, during the process of obtaining the core settings of the relay protection for a distribution network line, the core settings of the relay protection for the distribution network line include:

[0021] Secondary side instantaneous overcurrent protection current value, secondary side instantaneous overcurrent protection current time, secondary side overcurrent protection current value, secondary side overcurrent protection current time, current transformer ratio and reclosing time.

[0022] The beneficial effects of this application are as follows: by obtaining the setting sheets corresponding to all normally operating electrical components of the distribution network lines to be verified, the core setting values ​​of the relay protection of the distribution network lines are organized and converted. At the same time, by drawing a simplified GIS single-line map of the distribution network lines, the converted core setting values ​​of the relay protection are simultaneously marked on the location of the corresponding numbered electrical components on the simplified GIS single-line map, thereby forming a distribution network protection setting coordination diagram based on the distribution network lines to be verified. This achieves the goal of centralized and unified management of distribution network relay protection settings, which facilitates operators to quickly, accurately, and efficiently verify protection settings in the event of a fault. Furthermore, it makes it easier for operators to combine the SOE messages of the distribution automation system to guide on-site fault inspections. Attached Figure Description

[0023] To more clearly illustrate the technical solutions in the embodiments of this application or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0024] Figure 1 This is a flowchart illustrating a relay protection core setting management method based on a distribution network GIS system according to an embodiment of this application;

[0025] Figure 2 This is a flowchart illustrating another embodiment of the relay protection core setting management method based on the distribution network GIS system. Detailed Implementation

[0026] To make the objectives, implementation methods and advantages of this application clearer, the exemplary implementation methods of this application will be clearly and completely described below with reference to the accompanying drawings of the exemplary embodiments of this application. Obviously, the described exemplary embodiments are only some embodiments of this application, and not all embodiments.

[0027] It should be noted that the brief descriptions of terms in this application are only for the convenience of understanding the embodiments described below, and are not intended to limit the embodiments of this application. Unless otherwise stated, these terms should be understood in their ordinary and common meaning.

[0028] The terms "first," "second," "third," etc., used in the specification, claims, and accompanying drawings of this application are used to distinguish similar or related objects or entities, and do not necessarily imply a specific order or sequence, unless otherwise specified. It should be understood that such terms are interchangeable where appropriate.

[0029] The terms “include” and “have”, and any variations thereof, are intended to cover but not exclusively include, for example, a product or device that includes a range of components is not necessarily limited to all of the components that are clearly listed, but may include other components that are not clearly listed or that are inherent to such product or device.

[0030] like Figure 1 As shown. Figure 1 A flowchart of a relay protection core setting management method based on a distribution network GIS system according to an embodiment of this application.

[0031] The power distribution network is formed by a combination of multiple lines. Each line is connected to power distribution automation terminals (FTUs) and power distribution intelligent terminals, which are used to maintain the normal operation of the power distribution network. At the same time, each power distribution line is also equipped with multiple switches for adjusting the line operation mode. Each switch is set with different relay protection settings. When maintenance work adjusts the power distribution network operation mode, the switches on the line may trip due to overload. Therefore, the operators need to check the relay protection settings of the power distribution line switches according to the adjusted relay protection settings sheet for each switch.

[0032] The process of manually searching for the protection settings of corresponding switches in the system by operators is time-consuming. In order to improve the efficiency of operators in checking the relay protection settings of distribution network switches, this application provides a method for managing the core relay protection settings based on the distribution network GIS system.

[0033] In some embodiments, the relay protection core setting management method based on a distribution network GIS system provided in this application includes:

[0034] The core relay protection settings of the distribution network line are obtained based on the relay protection setting sheet of the distribution network line. The core relay protection settings of the distribution network line include the secondary value of the core current setting of the distribution network line. The relay protection setting sheet of the distribution network line is a setting sheet corresponding to all electrical components operating normally in the distribution line, which is exported by the "Integrated Power Grid Operation Management System" according to any complete distribution line.

[0035] Obtain the primary value of the current setting corresponding to each component of the distribution network line. The primary value of the current setting of each component is obtained by converting the secondary value of the core current setting of the relay protection of the distribution network line.

[0036] Draw a simplified GIS single-line map of the distribution network line. The simplified GIS single-line map of the distribution network line is obtained based on the GIS single-line map of the distribution network line.

[0037] The primary values ​​of the current settings corresponding to each component of the distribution network line are marked on the simplified GIS single-line diagram of the distribution network line to form the distribution network relay protection setting coordination diagram.

[0038] like Figure 2 As shown, Figure 2 This is a flowchart illustrating another embodiment of the relay protection core setting management method based on a distribution network GIS system.

[0039] The following describes the process by which operators use the relay protection core setting management method based on the distribution network GIS system provided in this application to verify the switch protection settings of all 10kV feeders to be verified in the distribution network.

[0040] Obtain all core relay protection settings for the 10kV feeders to be verified in the distribution network. The core relay protection settings for the distribution network are obtained based on the relay protection setting sheet for the distribution network. The core relay protection settings for the distribution network include the secondary value of the core current setting of the distribution network. The relay protection setting sheet for the distribution network is obtained by the "Integrated Power Grid Operation Management System" from the setting sheet corresponding to all normally operating electrical components of the 10kV feeders to be verified in the distribution network.

[0041] Obtain the primary value of the current setting corresponding to each electrical component of the 10kV feeder to be verified. The primary value of the current setting corresponding to each electrical component of the 10kV feeder is obtained by conversion based on the secondary value of the core current setting of the relay protection of the 10kV feeder to be verified.

[0042] The electrical components installed on the 10kV feeder distribution network include substation circuit breakers, main line circuit breakers, and branch line circuit breakers.

[0043] A simplified GIS single-line map of the 10kV feeder to be verified is drawn. The simplified GIS single-line map of the 10kV feeder to be verified is obtained based on the GIS single-line map of the distribution network line. The GIS single-line map of the distribution network line is obtained by the operators logging into the integrated GIS platform operating system and downloading it.

[0044] Mark the primary values ​​of the current settings corresponding to each electrical component of the 10kV feeder to be verified on the GIS single-line simplified diagram of the 10kV feeder to be verified, and form the distribution network relay protection setting coordination diagram.

[0045] By obtaining the setting sheets corresponding to all normally operating electrical components of the distribution network lines to be checked, the core relay protection settings of the distribution network lines are organized and converted. At the same time, by drawing a simplified GIS single-line map of the distribution network lines, the converted core relay protection settings are simultaneously marked on the location of the corresponding numbered electrical components on the simplified GIS single-line map. This forms a distribution network protection setting coordination diagram based on the distribution network lines to be checked, achieving the goal of centralized and unified management of distribution network relay protection settings. This facilitates operators to quickly, accurately, and efficiently check protection settings in the event of a fault, and further facilitates operators to combine SOE messages from the distribution automation system to better guide on-site fault inspections.

[0046] In some embodiments, this application also provides a method for managing the core settings of relay protection based on a distribution network GIS system, comprising:

[0047] Obtain the core settings of the relay protection for the distribution network lines. The core settings of the relay protection for the distribution network lines are obtained based on the relay protection setting sheet of the distribution network lines.

[0048] The core settings of relay protection include the secondary values ​​corresponding to the current transformer ratio of the setpoint and the core settings of the relay protection of the distribution network line. The primary values ​​of the current settings corresponding to each component of the distribution network line are obtained by using the secondary values ​​corresponding to the current transformer ratio of the setpoint and the core settings of the relay protection of the distribution network line.

[0049] Draw a simplified GIS single-line map of the distribution network line. The simplified GIS single-line map of the distribution network line is obtained based on the GIS single-line map of the distribution network line.

[0050] The primary values ​​of the current settings corresponding to each component of the distribution network line are marked on the simplified GIS single-line diagram of the distribution network line to form the distribution network relay protection setting coordination diagram.

[0051] By using the transformation ratio of the current transformer and the secondary value corresponding to the core setting of the relay protection of the distribution network line, the primary value of the current setting corresponding to each component of the distribution network line is obtained. The primary value of the current setting corresponding to each component of the distribution network line is then converted into the core setting of the relay protection and simultaneously marked on the location of the corresponding numbered electrical component on the GIS single-line simplified map. This forms a distribution network protection setting coordination diagram based on the distribution network line to be checked, reducing the probability of operators needing to perform conversions during the management of the distribution network line. This facilitates operators to quickly, accurately, and efficiently check the protection settings in the event of a fault. Furthermore, it makes it easier for operators to combine the SOE messages of the distribution automation system to guide on-site fault inspections.

[0052] In some embodiments, the method provided in this application includes the following steps in obtaining the primary values ​​of the current settings corresponding to each component of the distribution network line:

[0053] The primary value of the current setting corresponding to each component of the distribution network line = the secondary value of the core current setting of the relay protection of the distribution network line × the transformation ratio of the current transformer of the setting unit.

[0054] By converting the secondary values ​​of the current transformer ratio and the core current setting of the distribution network line relay protection into the primary values ​​of the core current setting, operators can easily and intuitively verify the protection settings of each component of the distribution network. This greatly reduces the tediousness of the verification process, reduces the error when verifying the lines to be verified, and improves the efficiency of operators in verifying the distribution network lines.

[0055] In some embodiments, this application also provides a method for managing the core settings of relay protection based on a distribution network GIS system, comprising:

[0056] The core settings of the relay protection for the distribution network line are obtained based on the relay protection setting sheet of the distribution network line. The relay protection setting sheet of the distribution network line includes: the primary side circuit breaker protection setting sheet, the main line voltage-time type setting sheet, and the branch line current-time type setting sheet.

[0057] The components installed on the distribution network lines to be verified include substation circuit breakers, main line circuit breakers, and branch line circuit breakers. Each of the substation circuit breakers, main line circuit breakers, and branch line circuit breakers has its own corresponding relay protection core protection settings.

[0058] The relay protection core settings included in the protection setting sheet for the primary side circuit breaker corresponding to the circuit breaker within the substation include:

[0059] Secondary side instantaneous overcurrent protection current value, secondary side instantaneous overcurrent protection current time, secondary side overcurrent protection current value, secondary side overcurrent protection current time, current transformer ratio and reclosing time; wherein, the current transformer ratio is represented by CT1.

[0060] The main line voltage-time type setting sheet corresponding to the main line side circuit breaker includes: X time limit, Y time limit and Z time limit.

[0061] The branch current-time type setting sheet corresponding to the branch circuit breaker also includes: secondary side instantaneous overcurrent protection current value, secondary side instantaneous overcurrent protection current time, secondary side overcurrent protection current value, secondary side overcurrent protection current time, current transformer ratio and reclosing time; among which, the current transformer ratio is represented as CT2.

[0062] The primary value of the instantaneous overcurrent protection = the secondary side instantaneous overcurrent protection value × the current transformer ratio;

[0063] The primary value of the overcurrent protection current = the secondary overcurrent protection current value × the current transformer ratio.

[0064] The core settings of relay protection include the secondary values ​​corresponding to the current transformer ratio of the setpoint and the core settings of the relay protection of the distribution network line. The primary values ​​of the current settings corresponding to each component of the distribution network line are obtained by using the secondary values ​​corresponding to the current transformer ratio of the setpoint and the core settings of the relay protection of the distribution network line.

[0065] Draw a simplified GIS single-line map of the distribution network line. The simplified GIS single-line map of the distribution network line is obtained based on the GIS single-line map of the distribution network line.

[0066] The primary values ​​of the current settings corresponding to each component of the distribution network line are marked on the simplified GIS single-line diagram of the distribution network line to form the distribution network relay protection setting coordination diagram.

[0067] In some embodiments, this application provides a method for managing the core settings of relay protection based on a distribution network GIS system, comprising:

[0068] The core settings of the relay protection for the distribution network line are obtained based on the relay protection setting sheet of the distribution network line. The relay protection setting sheet of the distribution network line includes: the primary side circuit breaker protection setting sheet, the main line voltage-time type setting sheet, and the branch line current-time type setting sheet.

[0069] The components installed on the distribution network lines to be verified include substation circuit breakers, main line circuit breakers, and branch line circuit breakers. Each of the substation circuit breakers, main line circuit breakers, and branch line circuit breakers has its own corresponding relay protection core protection settings.

[0070] When the core setting of the relay protection of the distribution network line is obtained as a voltage-time type setting, it is not necessary to convert the secondary value of the current setting corresponding to each component into the corresponding primary value.

[0071] The relay protection core settings included in the protection setting sheet for the primary side circuit breaker corresponding to the circuit breaker within the substation include:

[0072] Secondary side instantaneous overcurrent protection current value, secondary side instantaneous overcurrent protection current time, secondary side overcurrent protection current value, secondary side overcurrent protection current time, current transformer ratio and reclosing time; wherein, the current transformer ratio is represented by CT1.

[0073] The main line voltage-time type setting sheet corresponding to the main line side circuit breaker includes: X time limit, Y time limit and Z time limit.

[0074] The branch current-time type setting sheet corresponding to the branch circuit breaker also includes: secondary side instantaneous overcurrent protection current value, secondary side instantaneous overcurrent protection current time, secondary side overcurrent protection current value, secondary side overcurrent protection current time, current transformer ratio and reclosing time; among which, the current transformer ratio is represented as CT2.

[0075] The primary value of the instantaneous overcurrent protection = the secondary side instantaneous overcurrent protection value × the current transformer ratio;

[0076] The primary value of the overcurrent protection current = the secondary overcurrent protection current value × the current transformer ratio.

[0077] The core settings of relay protection include the secondary values ​​corresponding to the current transformer ratio of the setpoint and the core settings of the relay protection of the distribution network line. The primary values ​​of the current settings corresponding to each component of the distribution network line are obtained by using the secondary values ​​corresponding to the current transformer ratio of the setpoint and the core settings of the relay protection of the distribution network line.

[0078] Draw a simplified GIS single-line map of the distribution network line. The simplified GIS single-line map of the distribution network line is obtained based on the GIS single-line map of the distribution network line.

[0079] The primary values ​​of the current settings corresponding to each component of the distribution network line are marked on the simplified GIS single-line diagram of the distribution network line to form the distribution network relay protection setting coordination diagram.

[0080] The beneficial effects of this embodiment are that by obtaining the setting sheets corresponding to all electrical components of the normally operating lines in the distribution network to be checked, the core setting values ​​of the relay protection of the distribution network lines are organized and converted. At the same time, by drawing the GIS single-line diagram of the distribution network lines into a simplified GIS single-line diagram, the converted core setting values ​​of the relay protection are simultaneously marked on the location of the corresponding numbered electrical components on the simplified GIS single-line diagram, thereby forming a distribution network protection setting coordination diagram based on the distribution network lines to be checked. This achieves the purpose of centralized and unified management of the distribution network relay protection setting values, which facilitates operators to quickly, accurately, and efficiently check the protection setting values ​​in the event of a fault. Furthermore, it makes it easier for operators to combine the SOE messages of the distribution automation system to guide on-site fault inspections.

[0081] For ease of explanation, the above description has been provided in conjunction with specific embodiments. However, the discussion in some embodiments above is not intended to be exhaustive or to limit the embodiments to the specific forms disclosed above. Various modifications and variations can be obtained based on the above teachings. The selection and description of the above embodiments are for the purpose of better explaining the principles and practical applications, thereby enabling those skilled in the art to better utilize the embodiments and various different variations of the embodiments suitable for specific application considerations.

Claims

1. A method for managing the core settings of relay protection based on a distribution network GIS system, characterized in that, The method includes: The core setting value of the relay protection of the distribution network line is obtained based on the relay protection setting value sheet of the distribution network line. The core setting value of the relay protection of the distribution network line includes the secondary value of the core current setting value of the relay protection of the distribution network line. Obtain the primary value of the current setting corresponding to each component of the distribution network line. The primary value of the current setting of each component is obtained by conversion based on the secondary value of the core current setting of the relay protection of the distribution network line. Draw a simplified GIS single-line map of the distribution network line, wherein the simplified GIS single-line map of the distribution network line is obtained based on the GIS single-line map of the distribution network line; The primary values ​​of the current settings corresponding to each component of the distribution network line are marked on the simplified GIS single-line diagram of the distribution network line to form the distribution network relay protection setting coordination diagram. In the process of obtaining the primary values ​​of the current settings corresponding to each component of the distribution network line, the method further includes: Based on the relay protection setting sheet of the distribution network line, obtain the secondary value corresponding to the current transformer ratio and the core setting of the relay protection of the distribution network line. Then, obtain the primary value of the current setting corresponding to each component of the distribution network line through the secondary value corresponding to the current transformer ratio and the core setting of the relay protection of the distribution network line.

2. The relay protection core setting management method based on the distribution network GIS system as described in claim 1, characterized in that, In the process of obtaining the primary values ​​of the current setpoints corresponding to each component of the distribution network line, the method includes: The primary value of the current setting corresponding to each component of the distribution network line = the secondary value of the core current setting of the relay protection of the distribution network line × the transformation ratio of the current transformer of the setting unit.

3. The relay protection core setting management method based on the distribution network GIS system as described in claim 1, characterized in that, In the process of obtaining the primary values ​​of the current settings corresponding to each component of the distribution network line, the method further includes: When the core setting of the relay protection of the distribution network line is obtained as a voltage-time type setting, it is not necessary to convert the secondary value of the current setting corresponding to each component into the corresponding primary value.

4. The relay protection core setting management method based on the distribution network GIS system as described in claim 1, characterized in that, In the process of obtaining the core settings of the relay protection for the distribution network line, the relay protection setting sheet for the distribution network line includes: Primary circuit breaker protection setting sheet, main line voltage-time type setting sheet and branch line current-time type setting sheet.

5. The relay protection core setting management method based on the distribution network GIS system as described in claim 1, characterized in that, In the process of obtaining the core settings of the relay protection for the distribution network line, the core settings of the relay protection for the distribution network line include: Secondary side instantaneous overcurrent protection current value, secondary side instantaneous overcurrent protection current time, secondary side overcurrent protection current value, secondary side overcurrent protection current time, current transformer ratio and reclosing time.

Images