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Modernization of Electrical Substation Automation Systems Using IEC61850
1.
International Research Journal
of Engineering and Technology (IRJET) e-ISSN: 2395-0056 Volume: 10 Issue: 01 | Jan 2023 www.irjet.net p-ISSN: 2395-0072 © 2023, IRJET | Impact Factor value: 7.529 | ISO 9001:2008 Certified Journal | Page 859 Modernization of Electrical Substation Automation Systems Using IEC61850 Jigisha Ahirrao1, Lalit Patil2, Shlok Kamath3, Atharva Joshi4 ---------------------------------------------------------------------***--------------------------------------------------------------------- Abstract - There is a need for a high-performance, flexible substation automation system (SAS) that is easy to incorporate. The increasing use of Intelligent Electronic Devices (IEDs) in substation protection, coordination, control, monitoring, metering, and testing offers interoperability and enhanced communications capabilities. The IEC Technical Committee 57 worked to create IEC 61850, an open standard for substation modelling and communications. The international adoption of the standard has grown in popularity. This article explores the use of IEC 61850 in conventional substation automation. It introduces the experience of a real SAS modernizationscenario. Thisinstance emphasizes how useful the IEC 61850 is for operating and monitoring substations. Key Words: IEC 61850, Substation Automation System, IEDs, GOOSE message, intelligent control, protective relay 1. INTRODUCTION To better meet the demands of expanding Intelligent Electronic Devices (IEDs) installation, effective communication, comprehensive protection, and future growth, power system substations are undergoing renovation. In order to operate and control power system components, modern substation automation(SA)makes use of data from IEDs, control andautomationcapabilitieswithin the substation, and control orders from remote users. Ethernet technology brings a standard physical connection that makes universal communication protocolspossibleand lays a solid foundation for substation automation systems (SAS). The integration of IEDs, Ethernet LAN, communications protocols, and communications methods, make the whole substation a functional system with the combination of correct physical/virtual connections, common communication protocols, shared storage, and sequential/combinational logic for coordinated monitoring, protection, and control. The data models defined in IEC 61850 can be mapped to several protocols. The most important international standard for substationautomation systems is IEC 61850 and its related standards. The installation of IEDs in substations, when combined with IEC 61850, enables interoperability, flexibility, and increased efficiency and creates a wide range of potential solutions for substation operation, protection, monitoring, control, and automation. 1.1 Goals of SAS Project An Open System: Ability to configure an IEC61850 system using manufacturer tools already in existence without requiring on-site manufacturer support. To carry out automated activities, communication, protection, control, monitoring, and measurement data from IEDs can be combined. Higher Efficiency: Ethernet-based, quick communications systems. A successful data management system. Lower cost: Using less copper cables, commissioning becoming simpler, and the likelihood of failures decreasing. Auxiliary relays and other apparatus in the control and protection panels are reduced. Flexibility: The ability to test any LED individually without worrying about interfering with the substation's routine operations. Modernized substations enable free function allocation, allowing any vendor to carry out a particular task using its own design. 2. NETWORK ARCHITECTURE IEC 61850 standard often adopts the DNP3 LANIW AN protocol forsupervision system communications. Inorderto use this protocol, a gateway is required togatherandprocess IEC 61850 data from the IEDs, convert it to LANIW AN, and deliver it to the local HMI and the distant control centre. The process bus is defined and essential to data collection and exchange in the IEC 61850-based architecture. The substation system architectureisseparatedintostationlevel, bay level, and process level, as seen in Fig. 1. In Fig. 2, the plant's network connection diagram is displayed. Signalscan be transferred between the bay level lED and station control (station bus), the bay level lED and system equipment, and devices and transducers via the station bus and process bus (process bus). The twin redundant stations and process bus
2.
International Research Journal
of Engineering and Technology (IRJET) e-ISSN: 2395-0056 Volume: 10 Issue: 01 | Jan 2023 www.irjet.net p-ISSN: 2395-0072 © 2023, IRJET | Impact Factor value: 7.529 | ISO 9001:2008 Certified Journal | Page 860 are displayed in the communicationsarchitecture.Compared to a single bus, this offers crucialsubstations a higher level of reliability. Ethernet switches set up in a ring configuration are frequently used to implement thestationandprocessbus systems. Only station buses are used in conventional system architecture. Hierarchical rings are preferred for the station bus and process bus in substations based on IEC 61850. The ability to deliver current and voltage samplesfromamerging unit to numerous devices that use them for various applications is the foundation for the applications of the IEC 61850 process bus. IEC 61850's Part 9-2 explains how sampled values can be exchanged in place of a traditional analogue interface. Control and monitoring of IEDs can be done using GOOSE, and their data can be transmitted using TCP/IP. The timestamp resolution to the microsecond is required by the IEC 61850 standard. Accurate timestamps can be produced by IEDs whose clocks are synchronized to the same time standard. Fig -1: Simplified Communications Architecture Based on IEC 61850 Fig -2: Example Network Communications Diagram IEDs attached to Ethernet switches can all be controlled. Optical cable is used to link to the bay controllers, protection relays, circuit breakers, and gateways. For redundancy, multiple lEDs are required to control some IEDs, such as circuit breakers and switches at the lED level. The sampled values produced by a merging unit from conventional or non-conventional converters in the case of GOOSE are a continuous data stream in a stationary case (no change in status). With regard to sampling values, the process bus must be isolated from the station bus. 3. GOOSE MESSAGE APPLICATION A framework for achieving interoperability between IEDs provided by various vendors is provided by IEC 61850. The distribution of tasks among gadgets and control levels is flexible. The standard therefore supports any function allocation. Interoperability should be offered between tasks that will be carried out in a substation but reside in equipment (physical devices) from various vendorsinorder to enable a free allocation of functions to IEDs. Functions may be divided into pieces and executed byvariousIEDs,yet they still communicate with one another (distributed function).The station level, the bay level, and the process level are the three levels where functions can be assigned. A new structure was created to carry out these functions, comprising the extra logical interfaces (IF). The IEC 61850 series is built on the diagram in Fig. 3. The meanings of the interfaces are as follows: IF1: Protection-data transmission between the station and bay levels. IF2: Interchange of security-related data between local and distant protection (beyond the scope of this standard). IF3: sharing of data at bay level IF4: Instantaneous data interchange between the process and bay levels via CT and VT, particularly for samples. IF5: Interchange of control and data between the process and bay levels. IF6: Control-data transmissionbetweenthestationlevel and the bay. IF7: Data transfer from a substation (level) to a distant engineer's office. IF8: Direct data transfer across the bays, particularly for quick operations like interlocking. IF9: Data exchange within station level IF10: Exchange of control informationbetweena substation (devices) and a distant control centre.
3.
International Research Journal
of Engineering and Technology (IRJET) e-ISSN: 2395-0056 Volume: 10 Issue: 01 | Jan 2023 www.irjet.net p-ISSN: 2395-0072 © 2023, IRJET | Impact Factor value: 7.529 | ISO 9001:2008 Certified Journal | Page 861 Fig -3: Interface Model of a Substation Automation System According to IEC61850-1, logical interface 8 is utilised for peer-to-peer direct data exchange between bays, and as illustrated in Fig. 5, GOOSE messagesmayalsobetransferred between the bay and station bus (level). For the purpose of sending messages between various IEDs and utilising the message data in automation and interlock logicschemes, the IEC 61850 standard employs the peer-to-peer IEC 61850 GOOSE protocol. A real-world use of GOOSE in a substation protection plan is shown in Fig. 4. Relay/copper wire hard wiring is replaced with GOOSE messages using the IEC 61850 standard to provide comparable performance and outperform copper connections in timing. In the event of a feeder circuit breaker failure, the SAS may use GOOSE messages to transmit a trip command to the power transformer secondary circuit breaker. Traditional copper wire connections can fail without warning, but the IEC 61850 method is more secure because if a connection fails, the system quickly sends alerts due to the loss of GOOSE system health messages. Fig -4: Circuit Breaker Trip Failure The flowchart for the protection strategy utilizing GOOSE messages is shown in Fig. 5. The feeder current will be detected by Relay 1's lED asbeing higherthantypical insuch a malfunction. The feeder circuit breaker receives a trip order from the LED. Relay 1 lED will transmit a trip instruction to Relay 2 lED, and Relay 2 will trip the bus by opening the circuit breaker in the transformer branch, if it determines that the feeder current is still high after a predetermined amount of time, indicating that the fault has not been cleared. The protective system terminates if the feeder current reaches normal levels after a predetermined amount of time. The backup protectionsystem will takeover if the fault current is still present in the feeder (perhaps as a result of both circuit breakers being out of commission). Circuit breakers inthetransformer branchreactmoreslowly to electromagnetic current relay protection techniquesthan more modern protection methods. The circuit breaker will trip the bus more quickly if GOOSE messages are used. In order to offer redundancy, the relay IEDs are connected to two Ethernet channels. If one of the communication lines fails, this will greatly boost the scheme's reliability. In order to offer redundancy, the relay IEDs are connected to two Ethernet channels. If one of the communication lines fails, this will greatly boost the scheme's reliability. Fig -5: Flowchart of Protection Scheme Using GOOSE
4.
International Research Journal
of Engineering and Technology (IRJET) e-ISSN: 2395-0056 Volume: 10 Issue: 01 | Jan 2023 www.irjet.net p-ISSN: 2395-0072 © 2023, IRJET | Impact Factor value: 7.529 | ISO 9001:2008 Certified Journal | Page 862 3. CONCLUSIONS To better meet the needs of upcoming power systems, power system substations are being updated with an increase in the installation of intelligent electronic devices (lED), effective communication, and comprehensive protection. In SAS, IEC 61850 is now a widely recognized standard. In this study, the SAS modernization experienceof a power plant integrated with the IEC 61850 family of protocols is presented. IEDs are easily integrated into this SAS modernization project to send control data between relays, automation controllers, HMIs, and other equipment. The architecture of networks and communications is introduced in detail. In this system, the protection and control schemes are communicated between the feeder, bay control, and transformer relays using peer-to-peer IEC 61850 GOOSE messages. A circuitbreakerfailureprevention scheme application case is provided. With the help of equipment from differentmanufacturersandtheadoptionof IEC 61850, the plant owner was able to improve system operation efficiency and implement comprehensive protection, control, and monitoring. REFERENCES [1] T. S. Sidhu and Y. Yin, "Modelling and Simulation for Performance Evaluation of IEC61850-Based Substation Communication Systems," Power Delivery, IEEE Transactions on, vol. 22, pp. 1482-1489,2007.M.Young, The Technical Writer’s Handbook. Mill Valley, CA: University Science, 1989. [2] P. P. Parikh, T. S. Sidhu, and A. Shami, "A Comprehensive Investigation of Wireless LAN for IEC 61850-Based Smart Distribution Substation Applications," Industrial Informatics, IEEE Transactions on, vol. 9, pp. 1466- 1476,2013. K. Elissa, “Title of paper if known,” unpublished. [3] Y. Liu, H. Gao, W. Gao, N. Li, and M. Xiang, "A design scheme of line current differential protection based on IEC61850," in Power Engineering and Automation Conference (PEAM), 2011 IEEE, 2011, pp. 520-523. [4] Y. Liu, H. Wei, L. Wang, and T. Zhao, "Ethernet communication based on the IEC61850-linemonitoring of electrical equipment lED," in Condition Monitoring and Diag. [5] D. C. Mazur, J. A. Kay, and J. H. Kreiter, "Benefits of IEC 61850 standard for power monitoringandmanagement systems in forest productsindustries," inPulpandPaper Industry Technical Conference (PPIC), Conference Record of 2013 Annual IEEE, 2013, pp. 69-75. [6] L. Yang, P. A. Crossley, A. Wen, R. Chatfield, and 1. Wright, "Design and Performance Testing of a Multivendor IEC61850-9-2 Process Bus Based Protection Scheme," Smart Grid, IEEE Transactions on, vol. 5, pp. 1159-1164,2014. [7] G. Manassero, E. L. Pellini, E. C. Senger, and R. M. Nakagomi, "IEC61850-Based Systems-Functional Testing and Interoperability Issues," Industrial Informatics, IEEE Transactions on, vol. 9, pp. 1436- 1444,2013.
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