Modernization of Electrical Substation Automation Systems Using IEC61850

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
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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

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.

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

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.
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Modernization of Electrical Substation Automation Systems Using IEC61850

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