Substation Automation System and IEC.pdf

Substation Automation System and IEC standers.

1. Substation Automation System
And
IEC 61850
Rajesh k. Patel
Reliserv Solution

2. • How substation works
• Intro to Digital Substation
• Evolution of Substation Automation System
• New architecture according to IEC61850
• different protocols in IEC61850
• Benefits of IEC61850
• Bay Level
• Station Level
• Comparison between conventional and SAS substation
CONTENTS

3. How substation works
•How signal generated and transmit through system

4. What system need from switch gear?
•current signal from CTs
•voltage signal from VTs
•status from parts of switch gear
What switch gear need from system?
•command signal to operate parts of switch gear
•all alarms
Local control cabinet (LCC)
LocalControlCabinet(LCC)referstoanenclosureorcontrolpanel
locatedwithinthesubstationthatprovideslocalcontroland
monitoringcapabilitiesforvariouselectricalequipmentandsystems.
LCCsareusedtoallowoperatorsormaintenancepersonnelto
interactwithandcontrolsubstationdeviceswithouttheneedfor
remoteaccessfromacentralcontrolroom.

5. Signal distributed to all panels in parallel
1-Control panel
2-Protection panel
3-Measurement panel
At this stage system need to simplify this complicated circuit and display system status
1-annunciator panel
2-marshalling panel
3-event record panel
Rajesh k. Patel
Reliserv Solution

6. Marshalling
panel
AMarshallingPanelisacriticalcomponentusedinelectricalsubstationsand
powerplantsforcentralizingandmanagingthecontrolwiringbetween
variousfieldinstrumentsandcontrolsystems.Itactsasaninterfacebetween
thefielddevices(suchassensors,relays,circuitbreakers,andother
monitoringandcontrolequipment)andthecentralcontrolorprotection
system(suchasaSCADAorPLCsystem).
AnAnnunciatorPanelisacriticalcomponentinsubstationcontrolsystems
andelectricalplants,usedforalarmindicationandstatusmonitoringof
equipment.Itisdesignedtovisuallyalertoperatorstoabnormalconditions,
faults,oroperationalissuesinreal-time,helpingensurequickdetectionand
responsetopotentialproblems.
Annunciator
panel
event record
panel
AnEventRecordPanel(alsoreferredtoasanEventRecorderPanel)isan
essentialcomponentinsubstationsandelectricalsystemsusedtodisplay,
store,andmanageeventrecordsgeneratedbyprotectionrelays,circuit
breakers,orothermonitoringdevices.Itservesasacentralizedinterfacethat
allowsoperatorstoquicklyaccesseventlogs,viewhistoricalevents,and
analyzethesequenceanddetailsofsystemoperationsorfaults.
Panels

7. Finally the signal convert to tele. Communication and leave system to NCC
NCC:
standsforNetworkControlCenterorNetworkCoordinationCenter.Itisa
centralizedfacilityorcontrolroomthatplaysacriticalroleinthemonitoring,
control,andcoordinationofactivitieswithinanetworkofsubstationsorpower
distributionsystems.TheNCCisintegraltoensuringtheefficient,reliable,and
safeoperationoftheelectricalgrid,particularlyinlargeorcomplexpower
networks.

9. RTU Panel

10. RTU
AnRTUPanel(RemoteTerminalUnitPanel)isanintegralcomponentinelectricalsubstations,powerplants,
andotherindustrialautomationsystems.Itprovidesaphysicalinterfaceforconnectingfielddevices
(sensors,breakers,transformers,relays,etc.)totheRemoteTerminalUnit(RTU),whichisresponsiblefor
gatheringdataandtransmittingittoacentralcontrolormonitoringsystem(e.g.,SCADA).TheRTUitself
collects,processes,andsendsreal-timedata,alarms,andcontrolsignals,allowingoperatorstoremotely
monitorandcontroltheequipment.
Meaning and function
•Interface Between Field Devices and RTU
•Data Acquisition
•Signal Conditioning and Processing
•Control and Command Functions
•Communication Interface
•Alarm Monitoring
•Local Control and Monitoring

11. •Substationautomationistheintegrationofexistingsubstationdevicesandanetworkinfrastructure.By
integratingprimarydeviceswithnetworkedsecondarydevices,thesubstationcanperformautomatic
industrialtaskssuchasdataacquisition,devicecontrol,andeventrecording.
•SASenableutilitiestomanagetheflowofelectricityintransmissionanddistributiongrids.SASsystems
areimportanttoolsfortheutilitiessincetheyprotectandcontrolsubstationsandensuregridstability
Substation automation system

12. How does a traditional substation
become a digital substation?
OR
when can you call a substation “digital”?

13. Digitization is the conversion of analog information in any form (text, photos, voice, etc.) to digital
form so that the information can be processed, stored, and transmitted digitally
What is Digitalization ?

14. Conventional
Traditional substations have always relied on copper cables connecting together primary equipment
like circuit breakers, conventional current and voltage transformers and protection relays.
The Evolution of Substation Automation

15. Measuring electrical parameters in a conventional substation
Conventional instrument transformers like potential
transformers (PTs) and current transformers (CTs) measure
the high voltages and currents passing through primary
equipment. Copper wires connect the analog output from the
transformers to secondary equipment, and the number of
copper wires increases depending on the application.

16. •As most substations today are switching and routing AC power at high/extra high voltage, it is not the
primary flow which is digital. A digital substation refers to its secondary systems, including all the
protection, control, measurement, condition monitoring, recording and supervisory systems associated
with that primary “process”.
•In general terms, in full digital substation the data related to the primary process is digitized
immediately, at the point where it is measured.
Digital Substation

17. The release of the IEC61850 station bus protocol in the 1980’s was a big first step on the way to implementing
a substation-wide all-purpose network
Digital Substation 1.0

18. Digital Substation 2.0
In 2005, the IEC61850 standard was greatly improved by defining a process bus to connect the process
level with the bay level

19. Digital Substation

20. COMPARISON
Conventional Substation
Substation Automation System
(SAS)
Operational Cost Reduction
Up to 60% Less space in the Relay houses
40% Shorter Installation Phase
Up to 80% Cupper Wire Reduction

21. •Process Level
•Process Bus
•Bay Level
•Station Bus
•Station Leve
The Architecture of Digital Substation acc. to IEC 61850

23. •The defining feature of a Digital Substation is the implementation of a process bus.
•The IEC 61850 process bus enables the substitution of point-to-point copper connections between IEDs, other devises
and switchgear by means of a safe, standardized optical communication bus.
•Thanks to the process bus, real-time measurement signals and status information can be broadcast throughout a
substation without complex wiring schemes.
Process level equipment
Process Bus

24. Benefits of Process Bus
•Reduces copper cabling
•Increased safety
•Reduced risk of electrical shock

25. Bay Level
AccordingtoIEC61850standards,isanintermediate
controlplacebetweenswitchgearboards(processlevel)
andthemaincontrolhouseofthesubstation(stationlevel).
Bay Level Function

26. Configuration of BAY Level
Component of BAY Level
•Protection relay
•Bay Control Unit (BCU)
•measuring device

28. Comparison between fiber optic cable and copper wire
Fiber optic cable Copper wire
•transmit data at much higher speed
•not affected by electromagnetic interferences and power
fluctuations
•very less affected by the corrosive chemicals
•Fiber cables are thin and lightweight
•average cost per meter 4 $
•transmit data at less speed than fiber optic cable
•affected by electromagnetic interferences and power
fluctuations
•affected by the corrosive chemicals
•Average cost per meter 0.5 $

29. Benefits of Bay level
▪Reduces copper cabling
▪Less space
▪Less installation and outage time
40% reduction of installation time for new protection and control systems.
•Fewer panels to install
•Fewer cables to be pulled, connected, tested

30. Station Bus
The physical structure of this bus consists of a fiber‐optical arrangement to which the various upper parts of
SAS devices are coupled.
Horizontal communicationVertical communication

31. Station Level
Station level refers to the place from where the substation is controlled and monitored as a whole.
A dedicated master clock for the synchronization of the entire system shall be provided.
Station level contains:
• The central substation controller (Station Controller)
• The means for communicate with remote upstream control level (NCC)
• The local operating facilities (HMI)
Rajesh k. Patel
Reliserv Solution

32. main functions of the station controller
•Communication with bay controllers through the station bus.
•Communication with HMI through the station LAN.
•Communication of all abnormal substation conditions to the NCC.
•Recording of events with an adequate time resolution (e.g., less than 1 ms).
•Providing a time synchronization signal to the bay controllers.
•Compilation printing of alarm and event lists.
Connection with NCC
NCC facilitates monitoring of the whole grid at the same time. It may work on organizing operations between
different sectors of the grid by a pre-set operation plan at certain situations.

33. Human Machine Interface (HMI)
• HMI is like the “face” of the SAS.
• It gives the substation operator access to control means as well as alarms and events displayed on the
monitor screen.
• HMI consists of a set of pieces of hardware plus a package of applications software.
HMI Hardware
•Color monitors : for display screens showing substation power circuits as well as control and monitoring
resources.
•Alphanumeric keyboard : or function keys for interaction with displayed screens, and a mouse.
•Printer : to produce hardcopies on demand and data logger for continuous printing of event texts in
chronological order.

34. Levels of Visualization and Control

35. IEC61850
•IEC 61850 is a flexible, open standard that defines the communication between devices in substation
automation systems. To enable seamless data communications and information exchange between the
overall networks.
•IEC 61850 is the most recent standard for communication networks and systems in substations.
Advantages of IEC61850
Simplified Architecture
Greater Reliability
Future-Proof Design
Vendor-Independence

36. Key Benefits of IEC 61850
•Increases flexibility
•Reduces copper wiring
•Reduces total installation cost
•Eases system engineering and integration process
•Improves application performance and security
•Minimizes costs of technological obsolescence
•Provides easy way of implementing typical applications
•Saves time and money in setup & commissioning

37. GOOSE protocol in IEC 61850 standard
• The IEC61850 standard defines the GOOSE protocol as a publisher/subscriber protocol.
• This protocol is used to exchange data between lEDs over Ethernet.

38. GOOSE protocol in IEC 61850 standard
• The IEC61850 standard defines a special language based on XML to describe the post and its elements called
SCL.
• Different post levels can be described by this language, so different files can be generated including:
•ICD
•SSD
•SCD

39. • The GOOSE protocol is an event-based protocol
• The GOOSE protocol sends data periodically and with a specific time interval. Also, this protocol sends data in
the form of a message when a special event occurs, such as tripping or closing a connector.
• Because this protocol is a Publisher/Subscriber type, it does not receive a confirmation after sending a message,
but because it sends a lot of messages, the chance of data loss is very low
• All messages are sent with a specific attribute, and the Subscriber receives only data that requires the desired
attribute

40. MMS protocol in IEC 61850 standard
• The IEC61850 standard defines the MMS protocol as a SERVER/CLIENT protocol.
• This protocol is used to exchange data between lEDs or the BAY layer with a higher Level than the
substation layer.
• The MMS protocol works based on TCP/IP in the network platform.
• This protocol allows the client to read and write data.

41. • IEC61850 is an object-oriented standard.
• Each Physical Device contains one or several Logical Devices and each Logical Device contains one or several
Logical Node and each Logical Node contains one or more Data Objects and each Data Object contains several
Data Attribute is.
• The name of each object is standardly named in IEC61850 standard.
• The IEC61850 standard provides access to objects.
MMS protocol in IEC 61850 standard

42. • The IEC61850 standard provides the possibility of collecting arbitrary data in the form of a Dataset.
• Dataset is a necessary part for a Reporting block
• Reporting is used to notify the client of changes in the values of the elements in the Dataset.
• The client does not need to request to read the Dataset data to be notified of changes.
MMS protocol in IEC 61850 standard

43. Objectives of lEC 61850
Interoperability: It is the ability of IEC 61850 where exchange of data takes place between one IED (of one
manufacturer) to other lEDs (of different manufacturers) in a compatible manner.
Free configuration: This standard shall support different philosophies and allow free allocation of functions
Long term stability: It must be able to follow the progress in communication technology as well as evolving
system requirements.
Data Storing: A common method/format for storing complete data
Testing: It defines complete testing required for the equipment which conforms to the standard.
Single standard: It gives a single protocol for complete substation considering modelling of different data
required for substation

44. Different Parts of IEC 61850
•System Aspects
•Configuration
•Abstract Communication Service
•Mapping to Communication Networks
•Testing
IEC 61850 : communication networks and systems for power utility automation

45. System Aspects of IEC 61850
Introduction and overview
It gives introduction and overview of IEC 61850 standard.
Glossary
It contains glossary of technology and definitions used in context of
substation automation system in different parts of the standard.
General requirements
It gives general requirements of the communication network.
•importance is given to quality requirement of communication network.
•communication network must remain immune to the change in
environmental conditions.
System and project
management
It pertains system and project management w. r. t
•engineering process and its supporting tools
•life cycle of lEDs
•overall system and quality assurance.
Communication requirements for
functions and device models
•It defines the performance requirement of different functions being
implemented using communication.
•It includes all known functions.
•Based on this, architecture of communication network and the
applications that can be implemented for a given network are to be
decided.

46. Configuration of IEC 61850
Configuration Language for Electrical Sub-station lEDs
It specifies a file format for describing communication related to IED configurations.
This includes:
•Parameters of IED.
•Communication system configuration.
•Switchyard structures.
The main purpose of this format is to exchange IED capability descriptions and substation automation system
descriptions between IED Engineering Tool and System Engineering Tool of different manufacturers in a
compatible way
•The defined language is called Substation Configuration Description Language (SCL)
•It is based on Extensible Markup Language (XML) version 1.0.

47. •It applies to the ACSI (Abstract Communication Service Interface) communication in sub-stations and feeder
applications.
•The ACSI provides interface between a client and a remote server.
Common Data Classes
•It specifies common data classes related to substation applications.
•It applies to descriptions of device models and functions of sub-station and feeder equipment.
Compatible Logical Node Classes
•It specifies the compatible logical node names and data names for communication between lEDs.
Mapping to MMS and ISO/IEC 8802-3
•It specifies a method of exchanging time-critical and non-time-critical data through LAN by mapping ACSI to
MMS (Manufacturing Message Specification) and ISO/IEC 8802-3
Abstract Communication Services of IEC 61850

48. Sampled values over serial unidirectional multi-drop point to point link
•It specifies the mappings for the communication between bay and process level.
•It also specifies a mapping on a serial unidirectional multi-drop point to point link in accordance
with IEC 60044-8.
Sampled values over ISO/IEC 8802-3
•It defines the Specific Communication Service Mapping (SCSM) for transmission of sampled values according
to the abstract specification in IEC 61850-7-2
Precision time protocol profile for power utility automation
•It defines timers requirements to achieve highest synchronization classes.
•Communication between substation to substation
•Communication between substation and control center
•Communication for condition monitoring
•Using IEC 61850 to transmit synchro phasor information according to IEEE C37.118
Abstract Communication Services of IEC 61850

49. Testing of IEC 61850
•It specifies the procedure for conformance testing of products implemented with this communication protocol.
Approach to Standardization
•To meet the basic requirement of IEC 61850 i.e.
•interoperability and free configuration, the IEC 61850 is built over a standard Open System Interconnection
(OSI) 7 layer model.
Rajesh k. Patel
Reliserv Solution