1. New structure in Deregulated Environment
Gen
Genco
Genco
Genco
Open access in
Transmission
Transmission
Traders
Discom
Discom
Discom
Traders
Open access in
Distribution
Distribution
Customer
Customer
Customer

2. These changes require the following:
1) Monitoring system wide information and
commands via data communication system
2) To send selected local information to control center,
customer, market participants.
3) Monitor critical real time information for taking
security related operation .
4) To support Power Trading and spot market.

3. 4) Reliable and fast communications among IED’s (
Intelligent Electronic Devices viz Relays, Meters, Fault
recorders, RTU’s etc.) for exchanging information and
change in settings as part of wide area protection
system .
5) Dissemination of billing and other related
calculations from Generation to Distribution for
to various agencies including information for DMS &
EMS.
7) To perform effective co-ordination through
communications , Communication Protocols used are
expected to be high speed ,reliable , fault tolerant and
intelligent enabled.

4. 8) The Protocols are to be accomplished for both local
( LAN) and wide area communications (WAN).
9) The protocols should be thin, flexible and have
provisions for accommodating future requirements.
10) Safe , secured and reliable transmission of
information.
11) Protecting information network from Hacking &
misuse.

5. 12. Information about the power system
gives the utility the strength to be more
successful and competitive in a free
market .
13.In this environment information
becomes a strategic requirement when
fast decisions are required.

6. Typical Substation Automation System Architecture
Remote Center
HMI
Event Printer
Hard Copy Printer
Ethernet LAN
Engineering Tool
ISAGRAPH
Fault Analysis
Reyevo / SEL5601 / IPSCOM
ER1000 Station Controller
Ohmega
Argus
Duobias-M
SEL-311C
M-3425
Multifunction Meter
Delta
Typical Substation Automation System Architecture

7. What is Protocol ?
When Intelligent Devices communicate with each other, there needs to be a common set of rules and instructions that each device follows.
A specific set of communication rules is called a protocol.

8. * The diversity of Equipments and Manufacturers lead to a increase of Proprietary Protocols

9. Computer to Computer data communication standards have been developed over past few decades.
Well known model for this purpose is the 7 Layer OSI ( Open System Interconnection) reference model.

10. This model provides encapsulation of the relevant data with in a packet.
This model provide isolation of application program from system and media. But adds significant overhead in processing power and bandwidth utilisation.

11. OSI 7 Layer Model Application 7 Presentation 6 Sessions 5 5 4
Transport
Network 3
Data link 2 1
Physical

12. Functionality of different layers
Application Layer: This provides the interface and services that support user application. Ex. , WWW, SMTP.
Presentation Layer: This layer responsible for data encryption, data compression .Ex JPG, MPEG etc
Sessions Layer: Responsible for setting up the communication link and manages the sessions. It could provide connection oriented and connectionless services.

13. Functionality of different layers
Transportation Layer: Responsible for flow control, Packet size, error free delivery with proper sequence.
Network layer: Route determination takes place in this layer. Translation of IP address to physical address ( NIC) also takes place here.
Data link layer : Responsible for data movement across the actual physical link.
Physical Layer: It defines the physical aspect of how the cabling is hooked.

14. ••••••••••••••••••••••••••••••••••••••••••••••••••••••• 7
7 LAYER
System X
System Y
Application 7
••••••••••••••••••••••••••••••••••••••••••••••••••••••• 7
Presentation 6
••••••••••••••••••••••••••••••••••••••••••••••••••••••• 6
Peer communication Protocols
Session 5
••••••••••••••••••••••••••••••••••••••••••••••••••••••• 5
•••••••••••••••••••••••••••••••••••••••••••••••••••••••
Transport 4 4
Intermediate System A
Intermediate System B
••• 3
••• 3
•••
Network 3 3
••• 2 2
••• 2 2
•••
Data Link 2 2
••• 1 1
••• 1 1
•••
Physical 1 1
Physical Media
Physical Media
Physical Media

15. Due to addition of many layer
overhead and bandwidth goes
higher.
It is not suitable for SCADA application.
Most of the Protocols follows various flavours of this model.

16. Need For Standards
* Protocol is a set of rules that governs how message containing
data and control information are assembled at a source for their
transmission across the network and then dissembled when they
reach their destination.
* The communication protocol allows two devices to communicate
with each other. Each device involved in the communication
must essentially support not only the same protocol but also the
same version of the protocol. Any differences involved in the
implementation of protocol at the either of ends will result in
the communication errors.

17. Proprietary Vs Open Protocols
* Protocol, used by the vendor, the utility is restricted to one supplier
for support and purchase of future devices. This presents a serious
problem.
Examples of Proprietary Protocols are SPA, K-Bus, VDEW etc.
* With the arrival of open systems concept , it is desired that devices
from one vendor be able to communicate with those of other
vendors i.e. devices should inter-operate . To achieve interoperability
one has to use industry standard open protocols.
Ex: IEC ,101,104, IEC61850,DNP,Modbus etc

18. Advantages of Open Protocols
* Migration to standard communication protocol is a very important
decision that leads to cost reduction and maximized flexibility
within the utility sector. Broadly benefits for the utilities are:
Availability of open system connectivity
> Vendor independence
> Reliable products at optimized costs
> Easily available knowledge and specification
Benefits drawn for vendors by standardization are:
> Lower costs of installation and maintenance
> A large market and thus opportunity to compete on price
performance instead of technical details only.
> Cost effective project implementation

19. Interoperability Vs Interchangeability
* Interoperability is the ability of two or more IEDs from same
vendor or different vendors to exchange information and uses
that information for correct co-operation.
* Interchangeability is the ability to replace the device the supplied
by one manufacturer with a device without making change to the
other elements in the system.

20. PROTOCOL STRUCTURE EPA OSI 7-Layer 3-Layer Application Presentation
Session
Transport
Network
Data Link
Physical
Application
Data Link
Physical
OSI
EPA

21. OSI Seven Layer architecture
Network Technology mainly based on OSI (Open System
Interconnect) which is a 7 Layer model representing networking
node by dividing tasks into layers that perform specific Functions.
Logical Connection
Application
Presentation
Session
Transport
Network
Data Link
Physical
Application
Application
Presentation
Presentation
Session
Session
Transport
Transport
Network
Network
Data Link
Data Link
Physical
Physical
Physical Connection
OSI Seven Layer architecture

22. } } PROTOCOL STRUCTURE for IP based Open Protocols TCP/IP Ethernet
IEC, DNP, UCA (and even MODBUS) standards are successfully
able to adopt TCP/IP based Ethernet based technology for
substation automation.
IEC (UCA2)
DNP3/TCP
IEC 104
Application
Presentation
Session
Transport
Network
Data Link
Physical }
TCP/UDP
TCP/IP IP }
IEEE 802.1
Ethernet
IEEE 802.3

23. Link Layer Balanced Transmission
Request Message
Slave
Master
(User Data, Confirm Expected)
[P]
(Acknowledgment)
[S]
Response Message
(User Data, Confirm Expected)
[P]
DNP only uses balanced transmission
IEC profiles permit either balanced or unbalanced transmission
(Acknowledgment)
[S]
[P] = Primary Frame
[S] = Secondary Frame 14

24. Link Layer Balanced Transmission
At the link layer, all devices are equal
Collision avoidance by one of the following:
Full duplex point to point connection (RS232 or four wire RS485)
Designated master polls rest of slaves on network (two wire RS485 and disable data link confirms in slaves)
Physical layer (CSMA/CD) 15

25. Link Layer Unbalanced Transmission
Request Message
Slave
Master
(User Data, Confirm Expected)
[P]
(Acknowledgment)
[S]
Response Message
Not supported in DNP
(Request User Data)
[P]
(Respond User Data or NACK)
[S]
[P] = Primary Frame
[S] = Secondary Frame 16

26. Link Layer Unbalanced Transmission
Only Master device can transmit primary frames
Collision avoidance is not necessary since slave device cannot initiate exchange, or retry failed messages
If the slave device responds with NACK: requested data not available the master will try again until it gets data, or a response time-out occurs 17

27. Protocols used in Electrical utilities are as follows:
Modbus / Profibus
DNP ( Distributed Network Protocol )
IEC series
UCA ( Utlity Communication Architecture ) – IEC series

28. - Application layer Protocol ( 7 th Layer of OSI )
MODBUS
Developed in the process-control industries by MODICON , USA during 1976
- Application layer Protocol ( 7 th Layer of OSI )
Extensively used in industrial environment
Used in process bus of substation bay ( Relays )
It operates on master slave type mode
Slave node will not typically transmit data with out a request from the master.

29. It was originally designed as a simple way to transfer data between controls and sensors via RS-232 interfaces.
Modbus now supports other communication media, including TCP/IP.
Modbus is now an open standard, administered by the Modbus-IDA (

30. Modbus and DNP3 Communication Protocols
Modbus and DNP are both byte-oriented protocols.
Modbus is an application layer protocol,
while DNP contains Application and Data Link Layers, with a pseudo-transport layer.
Both protocols are widely used over a variety of physical layers, including RS-232, RS-422, RS-485, and TCP/IP.
Modbus has a separate specification for use over TCP/IP (Modbus-TCP). With DNP, the protocol is simply encapsulated within TCP/IP.

31. Distributed Network Protocol 3.0

32. Distributed Network Protocol ( DNP) was developed by Harris, USA.
The Distributed Networking Protocol (DNP) was originally developed by Westronic, Inc. (now GE Harris) in 1990.
The “DNP 3.0 Basic 4” protocol specification document set was released into the public domain in 1993, and ownership of the protocol was given to the newly formed DNP Users Group in October 1993.
DNP was specifically developed for use in Electrical Utility SCADA Applications.
It is now the dominant protocol in electrical utility SCADA systems, and is gaining popularity in other industries, including Oil & Gas, Water, and Waste Water.

33. In 1993 the responsibility for defining further DNP specification was given to DNP user Group.
DNP is based on the earlier work of IEC TC 57
It is based on Enhanced Performance architecture ( EPA) model
There are 4 core documents to define DNP 3

34. Emergence of Standard DNP 3.0 Based on earlier work of IEC TC57
Developed by GE Harris
DNP 3.0 is an open protocol that was developed to establish interoperability between RTUs, IEDs (Intelligent Electronic Devices) and master stations. DNP was largely influenced by North and South America, together with the African and Asian regions as IEC 101 was from the European community.

35. DNP 3.0 Structure Three Layered Protocol (EPA) Application (Layer 7)
Data Link (Layer 2)
Physical (Layer 1)
This structure is similar to IEC. However, DNP3 enhances EPA by
adding a fourth layer, a pseudo transport layer that allows for message segmentation.

36. Additional Pseudo Layer
In addition
Pseudo Transport Layer (Layer 4)
Support Advance RTU functions
DNP introduces a pseudo-transport layer(OSI Layer 4) to build application data messages larger than a single data link frame. In case of IEC, each 101 message should be contained in a single data link frame.

37. DNP3 is an open, intelligent, robust, and efficient modern SCADA protocol.
It can request and respond with multiple data types in single messages,
segment messages into multiple frames to ensure excellent error detection and recovery,
include only changed data in response messages,
assign priorities to data items and request data items periodically based on their priority,
respond without request (unsolicited),
support time synchronization and a standard time format,
allow multiple masters and peer-to-peer operations,
and allow user definable objects including file transfer.
In 1994, the IEEE Power Engineering Society’s Data Acquisition, Monitoring and Control Subcommittee formed a Task Force to review the communication protocols being used between Intelligent Electronic Devices (IEDs) and Remote Terminal Units (RTUs) in substations.

38. The IEEE Task Force found a very confusing, constantly changing environment that was increasing the cost and time to completion of substation SCADA systems.
The IEEE Task Force collected information on approximately 140 protocols and compared them to a list of communication protocol requirements.
This comparison resulted in a short list of protocols that met most of the requirements.
This short list was balloted and two serial SCADA protocols tied for being the most acceptable: IEC and DNP3.

39. Structure of IEC 60870-5 Three Layered Protocol(EPA)
Application (Layer 7)
Data Link (Layer 2)
Physical (Layer 1)

40. For Tele Control System that require particularly
Why 3-Layered Structure of EPA
1) Short Reaction Time
2) Reduced Transmission Bandwidth
BW: Measure of capacity of a transmission
system. Measured in Hertz. How fast data
can flow on a given transmission path.
In Digital data transmission, BW is expressed
as data speed in bits per second. Thus, higher
the BW, more data can be transmitted.

41. Purpose of 60870-5 Protocol High Integrity Efficient Data Transmission
Protection Against Undetected Transmission Errors
Correct data should reach the destination
Without Loss

42. DNP 3.0 and IEC 60870-5-101 Both DNP 3.0 and IEC 60870-5-101
Designed for Transmission of SCADA Data for Electric Power System Control
Wide Market Acceptance
Intended for Use in SCADA Systems Using directly Connected Serial Links

43. DNP 3.0 and IEC 60870-5-101 60870-5-101 and DNP Usage
Collection of Binary Data
Collection of Analog Data
Collection, freezing and Clearing of Counters

44. DNP 3.0 and IEC 60870-5-101 Time Synchronization Time-Stamping Events
File Transfer
Unsolicited Events Reporting

45. IEC Series
It is bit serial communication standards. The standard is optimised for efficient and reliable transfer of process data and commands to and from geographically widespread systems over low-speed (up to 64 kbps) fixed and dial-up connections.

46. IEC –
It deals the functionality for the interoperability of telecontrol equipment of different manufactures for the communication between substations and between substation and control centres .
IEC This standard deals with values of integrated totals which are transmitted at periodic intervals to update the energy interchanges between utilities or between heavy industry and utilities.

47. IEC 60870-5-103 - This deals with informative interface of protection equipment .
IEC This present a combination of the application layer of IEC and the transport functions provided by a TCP/IP.

48. IEC 61850
This standard unifies UCA with European standard. It aims to design a communication system that provides interoperability between the functions to be performed in a substation.

49. IEC :
This specifies hardware and protocol specifications for local systems in which a hand held unit is connected to only one tariff device at a time. This specifies hardware and protocol specifications for local systems in which a hand held unit is connected to only one tariff device at a time.

50. to access (read and write) memory locations, without
·     1) IEC is essentially a protocol providing a means
to access (read and write) memory locations, without
telling anything about how those memory locations
should be filled with information.
·    2) IEC does neither say anything about the
format and the interpretation of the data.

51. 3) IEC 61107, developed for the purposes of local data exchange, does not follow the OSI model of layered protocols and does not have the functions provided by these layers. Therefore, although it is widely used over telephone networks, it is only possible with some compromises.
4)      IEC lacks advanced security functions.
5) Consequently, for each new meter type, even from the same manufacturer, a new device driver is required. Such drivers carry information about where and how to find the information and how to interpret it. The development of device drivers has proven to be a lengthy and costly exercise.

52. Communication - Interfaces & Protocols in Substation
* Serial (RS232/RS485/RS422)
* LAN (Ethernet)
Serial Protocols
* IEC (Protection)
* IEC (Tele Control)
* DNP 3.0 (Protection, Monitoring & Metering)
* Modbus RTU (Metering)
LAN Protocols
* IEC
* DNP 3.0 over TCP/IP
* MODBUS over Ethernet ( For Industries)
* IEC 61850

53. Communication Protocols from Station Level Equipment.
* Serial
* Ethernet
Station Level Protocol
* IEC
* IEC
* DNP 3.0 over TCP/IP
* Modbus over Ethernet / Serial

54. DNP 3.0 * Supports Balanced Transmission Services * Supports
- Time Synchronization
- Time-stamped events
- Freeze/Clear Counters
- Select before operate
- Unsolicited Responses

55. IEC 870-5-101: Basic Telecontrol Tasks
Protocol Standard for the telecontrol of Electrical Power Transmission Systems.
Permanent Directly Connected (Serial) Link between Telecontrol stations.
Supports both Balanced/Unbalanced Transmissions
Frame Type FT1.2 (1 Byte Checksum error check)

56. IEC
This protocol standard is developed to Provide Network access for IEC
Application Layer remains same.
Does not use the Link Layer functions of IEC
Some APCI (Application Protocol Control Information) Added to 101 ASDU To suitable for network transportation

57. Modbus Over Ethernet / Serial
Modbus Over Ethernet protocol if useful in sending Modbus messages on LAN / WAN network.
Additional of 6 Bytes as a MBAP Header to basic Modbus over serial frame.
Slave Address byte of serial Modbus frame is replaced with Unit Identifier.

58. IEC
Companion Standard for Interface of Protection Equipment's
Unbalanced Master Slave Serial Protocol.
Protective Relays Act as Slave Devices.
Station Controller as a Master.
Physical Interface may be RS232,RS485 (or) Fiber Optic.
Status indications,Measurement values, time-tagged events,
control commands and clock synchronization Can be
transferred between Master & Slave Devices .

59. Future ( IEC / UCA )
Standard for communication network and systems in Substation.
Intended to integrate
* Protection System
* Control System
* Substation Field Devices
* Interface to Supervisory Control and Data Acquisition(SCADA) of Control Center
* One of the most important features of IEC is that it covers not only communication, but also qualitative properties of engineering tools, measures for quality management, and configuration management & Conformance testing.

60. Communication Standards Within the Substation
IEC / DNP 3.0
Modbus / IEC 61850

61. What to Expect from Vendor on Protocols in their Devices??
IEC protocol
* Communication Settings supported (Baudrate, Parity,
IED address range config.).
*Function Types supported (both Standard, Private).
*COT Supported.
*ASDU Type supported for each type of Tag or Parameter
or information.
*Information number (Standard, Private) for each parameter
or tag & description for the same.
*Any private ASDU ( ASDU 254,255 )implementation?
If so then details.
* Interoperability Table if any

62. DNP3.0 Protocol
* Details of Communication Interface supported.
* DNP Levels Supported.
* Data Scaling Range if any?
*Data Retrieval Method supported (unsolicited/polled static/exception).
*Object Type & variations supported.
*Data Map (Index number ) of each parameter.

63. Modbus (RTU) Protocol
*Details of Communication Interface supported.
*Relay Address range supported.
*Function Types supported.
*Address range for each parameter.
*Data Type(16 bit(integer),32 bitz(long int), etc)
*Multiplication factors if any.
*Parameters type (Read only/read/write).

64. Typical Architecture of ERSA System
HMI # 2
HMI # 1
Remote Control Center
Ethernet LAN
ER 1000
400 & 220 kV Bay Control Units
Protective Relays
Tariff Meter

65. MV Architecture Remote HMI Local HMI Station Controller Modbus
The above shows the most commonly followed system Archtecture around the globe.
The archtecture is an open one pemits integration with devices of multiple vendors.
The above architecture is a totally decentralised and distributed Archtecture.All the Application programmes , logics and interlocks etc are residin in the emebeded station controller not in the HMI PC.
This increses the system reliability many folds.
In this Architecture the master station HMI acts as Display and archiving device.
The station controller also act as the communication gateway enable connectivity to devicces of multiple open /standard protocol.
Hardwired I/O’s for protection and Equipment Status
Multifunction Meters
Bay Control & Protection Units

66. ER 1000 Station Controller/Communication Gateway
Remote Control Center
Local HMI
ER 1000
DNP 3.0 / IEC 101 / IEC 104 / Modbus serial or Ethernet [ Slave components]
IEC 103 Master
DNP 3.0 Master
Modbus Master
Hardwired Analog/Digital I/O’s
for protection and Equipment Status
IEC Slave Components
DNP 3.0 Slave
Components
Modbus Slave
Components

67. Functionality's & Requirement of station Controller
Communication Gateway
Protocol Converter
Virtual RTU
Data Concentrator
Automation Unit
Wired I/O’s
Open H/W architecture and OS
IEC compliant PLC programming
Highly modular and hence easily expandable
Superior architecture compared to a PC based architecture
Can work in any extreme environmental conditions

68. What is Simple Substation Control And Monitoring System????...
* Present the state and operational Details of the field equipment
in a user friendly manner through a powerful GUI
Control and monitor the field equipment, protection IED’s locally
or remotely
Inbuilt -Energy Management System with communicable Multifunction Meters.
Report Generation (Hourly, Daily, monthly, yearly), Alarms
IED Parameterization, Disturbance Analysis.
Online Sequence of Time Tagged Events (Source / System Time Stamp) printing and Event File Storing.

69. Serial to Fibre Optic Converter
A simple relay based substation control
Local Workstation
Remote HMI
Ethernet/Dialup
IEC 103
SOE Printer
IEC 103
Modbus
ER 05
RS 485/422 to RS Converter
Serial to Fibre Optic Converter
ER 10
ER 10
Multifunction Meters
RTU
Modbus/RS485
ER Relays
ER Relays

70. Typical structure of today’s automated substation

71. Typical structure of tomorrow’s automated substation

72. Data telemetry was introduced for monitoring , Control and Protection.
Electric utilities were among the first entities to embrace data telemetery.
Data telemetry was introduced for monitoring , Control and Protection.
Development in communication, Computer, introduction of Intelligent Electronic Devices (IED) made information collection easier.

73. Different manufacturers introduced different rules for communicating and exchanging information among their intelligent devices.
This introduced barriers in communicating with other device manufactured by others.

74. IEC Series
Data Exchange for Meter Reading- Tariff and Load control

75. on the liberalised market. The functions are
  1) covers all metering functions required
on the liberalised market. The functions are
modelled using metering domain specific interface
objects. This allows developing meters meeting
exactly customer needs, using standard building
blocks.
It also allows innovation and competition by
enhancing functionality in a standard way as
required while maintaining interoperability.
2) It ensures unique identification of all metering
equipment world-wide and unambiguous
identification of all data elements.

76. 3) It ensures unambiguous interpretation of all
metering data.
4) It allows controlled and selective access by
various parties to application relevant data.
5) It provides various levels of security mechanisms
to control access to data depending on
authentication and access rights.
 6) opens the way for exchanging data over various
communication media, as the meter data model is
independent of the communication protocol stack.

77. 7) It brings interoperability, and therefore lowers costs,
as it is based on a standard data model and
internationally approved standard protocols.
8) It allows developing a genuine driver, as the meter
describes the functions available and sends all
information necessary to interpret data. This allows
meter manufacturers and data collection system
providers to concentrate on the applications relevant
for their customers rather than on connectivity and
interfaces;
    
9) It comes complete with a conformance testing
scheme to guarantee interoperability.

78. IEC , TASE.2
This deals with mechanism for exchanging time-critical data between control centres. In addition, it provides support for device control, general messaging and control of programs at a remote control centre.

79. ELCOM90 :
This originated from a Scandinavian initiative to standardise information exchange between control centres. ELCOM is an international accepted

80. IEC 61970
This deals with CIM facilities for the integration of EMS applications developed independently by different vendors, between entire EMS systems developed independently, or between an EMS system

81. IEC 62210
This deals with safety, security and reliability of systems in Electrical Utilities. The deregulated market has imposed new threats and safe operation is essential in a deregulated environment.

82. IEC
This provides a standard for interconnection of monitoring and control systems for wind power plants

83. IEC TR
This report deals with Electronic communication in deregulated markets and makes a clear distinction between communications for control of energy systems and communications for the market

84. Possible trend in the near future
Ref: CIGRE report on Substation Automation

85. Possible trend in the far future
Ref: CIGRE report on Substation Automation

88. IEC TC57 Reference Architecture
Control centre
Control Centre S C A D
Metering
Protection
Physical
Device
Remote
Terminal
Unit
Substation
-103
Substation
Automation
-101
EMS
Application
61970
61850
61968
DMS
Subsystem

89. Relevant IEC Standards
Technical Committee 57
Power system control and associated communications
Published
IEC Telecontrol equipment and systems
IEC Distribution Automation using Power Line Carrier
IEC TR Power system Control and associated Communications – Data and Communication security
IEC Communication for monitoring and control of Wind Power plants.
TR Deregulated energy market communications
confirmed EDIFACT as a recommended standard for business transactions
In progress
IEC Communication networks and systems in substations
IEC System Interfaces for Distribution Management
IEC Energy Management Systems Application Program Interfaces
IEC Communication systems for Distributed Energy Resources
IEC Hydro Electric Power Plants – Communication for monitoring and control. .

90. Introduction
UCA

91. Brief Description about UCA 2.0
Electric Power Research Institute (EPRI) launched a concept in 1990 known as the Utility Communication Architecture or UCA. The goal behind UCA was to identify a suite of existing communication protocols that could be easily mixed and matched, provide the foundation for the functionality required to solve the utility enterprise communication issues, and be extensible for the future. After some initial revisions, the results of the project have been known as UCA UCA 2.0 is described in a technical report TR 1550 of the IEEE [2].
UCA2- SUBSTATION COMMUNICATION MODEL

92. Concept of 61850

93. Brief description about IEC 61850
The basis and the way of standardizing communications in IEC are entirely new. IEC was developed from IEC x and UCA 2.0.
Comprehensive EPRI project UCA 2.0
International Agreed Goals
IEC ,
-103, -104
IEC 61850
 The goal of this standard IEC “Communication networks and systems in substations” is to provide interoperability between the IED’s from different suppliers or, more precisely, between functions to be performed in a substation but residing in equipment (physical devices) from different suppliers. Interchangeability is outside the scope of this standard, but the objective of interchangeability will be supported following this standard.
 Interoperability has the following levels for devices from different suppliers:
(1) The devices shall be connectable to a common bus with a common protocol (syntax)
(2) The devices shall understand the information provided by other devices (semantics)
(3) The devices shall perform together a common or joint function if applicable (distributed functions) Since there are no constraints regarding system structure and data exchange, some static and dynamic requirements shall be fulfilled to provide interoperability.

94. IEC 61850 What does IEC 61850 achieve
Defines structure for protection and control
System configuration
Communication between bay devices
Standardised
language for
describing
substation
Fault records in Comtrade format
IEC 61850
Standard communication
with TCP - IP
Time synchronisation with SNTP
Based on Ethernet
standard

95. Advantages in IEC 61850? IEC 61850 is a global standard for
“Communication Networks and Systems in Substations”
It specifies an expandable data model and services
It does not block future development of functions
It specifies no protection or control functions
It supports free allocation of functions to devices
It is open for different system philosophies
It provides the Substation Configuration description Language (SCL)
It supports comprehensive consistent system definition and engineering
It uses Ethernet and TCP/IP for communication
Provides the broad range of features of mainstream communication
It is open for future new communication concepts

96. GOOSE ??

97. GOOSE Receiver Device Y GOOSE Receiver Device Z
IEC – GOOSE Principle
A device sends information by Multicasting. Only devices which are subscribers receive this message. In the example, Receiver Z receives the message. Receiver Y is not a subscriber.
GOOSE Receiver Device Y
GOOSE Sender Device X
Ethernet
GOOSE message
GOOSE Receiver Device Z

98. Difference of IEC 61850 and UCA 2.0 : fast messaging “GOOSE”
Overtaking path for IEC GOOSE
Normal message
Fast GOOSE
Buffer for Normal Message
Ethernet Switch

99. IEC Key benefits
IEC is a definite step towards unified substation communication, compared to the former IEC , DNP3 and most proprietary protocols:
speed of exchanges: 100 Mbps instead of few 10kbps, enabling more data to be exchanged or a better operation or maintenance of the system,
peer-to-peer links, replacing conventional wires with no extra hardware but and also permitting the design of innovative automation schemes,
client-server relations offering flexible solutions easy to upgrade compared to master slave communications,
object oriented pre-defined names, creating a single vocabulary between users, suppliers and supplier’s devices therefore facilitating the system integration and commissioning,
XML interfaces referencing the above objects for straightforward exchanges between engineering tools in order to optimise the data consistency and minimise project lead times.
communication conformance tests that help reducing the variety of interpretation found in many legacy protocols and leading to long integration tests and tuning.

100. IEC 61850 Based SAS Projects PGCIL Maharanibagh GIS:
400 KV Switchyard with 5 bays (Two Main)
220 KV Switchyard with 7 bays (Two Main)
Separate SA systems for 400 and 200 kV Levels.
FAT completed in Dec. 2005
PGCIL Bhatapara:
400 KV Switchyard with 6 Diameters (1½ Breaker)
220 KV Switchyard with 12 bays (Two Main +Transfer)
Common SA system for 400 and 220 kV Levels
PGCIL Raigarh:
400 KV Switchyard with 8 Diameters (1½ Breaker)
220 KV Switchyard with 9 Bays (Two Main +Transfer)
FAT completed in Jan. 2006

101. PGCIL Maharanibagh 400 kV S/S
REL 670
REC 670
REL 670 Main I
7SA522 Main II
BBP Bay Units
Main I, Main II
RET 670 Main I
RET 670 Main II
REB 500 Main I
REB 500 Main II
Busbar
Line x 2
Autotransformer x 2
Auxiliaries
IEC Redundant Ring network
IEC
Gateway
DR WS
Redundant HMI
GPS Receiver
Ethernet Switch
Laser Printer
DMP
Bus Coupl. x 1

102. PGCIL Maharanibagh 220 kV S/S
REC 670
REL 670 Main I
7SA522 Main II
BBP Bay Unit
REB 500
Busbar
Line x 4
Autotransformer x 2
Bus Coupler x 1
IEC Redundant Ring network
IEC
Gateway
DR WS
Redundant HMI
Ethernet Switch
Laser Printer
DMP