Antti Hakala-Ranta
Power and productivity for a
better world™
Singapore, Sept 22-23.9.2008
Enhanced protection
functionality with
IEC 61850 and GOOSE
Introduction
Background for IEC 61850
Goals and key thoughts of IEC 61850
Modeling of information and services
New type of communication services
Horizontal communication - GOOSE
Sampled measured values - SMV
Engineering support
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System integration
Application examples
Future outlook
Background – why IEC 61850
Global markets
DA users (Utility, industries) becoming more and more international ->
global standards needed
Flexible communication structures
Communication systems must be capable of fulfilling world-wide
requirements
Rapid changes in communication state-of-the-art technology, but long
life cycles of communication standards
Increasing economical and operational demands on utility
companies
Modern substation systems produce lots of data
Data need to be converted into information
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Communication networks provide access from anywhere
Communication in substations has to support:
Guaranteed and fast real time system responses
High resistance against harsh environmental conditions
History
Standards/de facto standards for substation automation
communication
IEC60870-5-103
Master slave serial protocol, SA semantics defined!, no controls (only with
spec. extension), no horizontal communication, too restricted to give easy
interoperability
Used in Europe and some far east countries
UCA2.0
Predecessor of IEC61850 by US vendors & utilities (an EPRI project)
Modeling & semantic ideas, horizontal communication
Never really accepted by customers, due to a lot of promises given but…
Officially and publicly to be replaced by IEC61850
Modbus
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Well known but: no information semantics (signal engineering), no events,
no time-synch
Used world-wide, especially in US
Master slave serial, also variant running over TCP
DNP3.0…
…and many other proprietary ones
How and what?
An IEC project group of about 60 members from different countries
worked in three IEC working groups from 1995
Objectives:
A single protocol for complete substation considering modeling of
different data required for substation
Definition of basic services required to transfer data so that the entire
mapping to communication protocol can be made future proof
Promotion of high interoperability between systems from different
vendors
A common method/format for storing complete configuration data
Define complete testing required for the equipments which confirms to
the standard
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1st parts of IEC 61850 standard were published 2004
Now, 2008, widely accepted and in use, both by utilities and industries
Background – What is IEC 61850?
IEC 61850 is a global standard
for
“Communication Networks and
Systems in Substations”
„How to make different devices
AND tools from different vendors
work together (=interoperability)“
YES, WE
DO!
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DO YOU
UNDERSTAND
ME?
Application area of IEC 61850
Electrical substations, also in industrial plants
to NCC / DCS
HMI
Station
gateway
Station
computer
Station Level
Engineering
station
Station or interbaybus (LAN)
Bay Level
Control
Protection
Protection
& Control
Control
Protection
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Process bus (LAN)
Process Level
Process Interface
Process Interface
Process Interface
Goals and key thoughts of IEC 61850
It specifies an expandable data model and services for
substation automation
It does not specify protection or control functionality, but it
specifies how they will expose their information
It supports free allocation of functions to devices
It is open for different system philosophies
It defines a description language for substation automation
systems
This facilitates efficient device integration
It supports comprehensive consistent system definition and
engineering
This makes not only the devices, but also their tools & systems
interoperable
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It uses Ethernet and TCP/IP for communication
Provides the broad range of features of mainstream
communication
High performance
It is open for future new communication concepts
Structure of the IEC 61850 standard
Introduction and overview
Impact on
engineering
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Part 8
Station bus
Glossary
Part 2
General requirements
Part 3
System and Project management
Part 4
Communication requirements
Part 5
Communication model (Data model and Services)
Part 7
Substation Configuration Language (SCL)
Part 6
Conformance testing
Part 10
Part 8-1 : Mapping for
MMS-TCP/IP-Ethernet
Part 9-1 : Mapping to pointto-point connections
Part 8-x : for Future Use
part 9-2 : Mapping for bus
connections
Impacts not only on communication !
Direct impact
implementation
Impact on
tenders and
product mgmt.
Part 1
Part 9
Process bus
Concept 1: Split of application and communication
Future Proof Design Aspects - Independence of actual technology
Slow
Application
Domain
Substation
Long-term definition
Safe-guarding investments
Application
• Objects
•Services
Abstract Interface
Adaptation
per selected stack
Mapping
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Fast
Communication
Technology
7
6
5
4
3
2
1
ISO/OSI
seven layer stack
Stack Interface
MMS*
TCP/IP
Ethernet
Stack selection
following state-of-art
Communication technology
Approach of
IEC61850
The data model is mapped unambiguously to an existing stack
*) Manufacturing Message Specification
Concept 2: Take care of the engineering
Additionally to the communication – make the tools interoperable
Making it possible to efficiently manage the configuration data in a
system even if the products are from different vendors
Substation Configuration Language (SCL) allows describing in a
standardised way
IEDs, their configuration and their functional and communication capabilities
Concrete communication structure of a SA system
Allocation of devices to the substation primary equipment.
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These descriptions can be exchanged between engineering tools of
different manufacturers
Common approach to system engineering without the need of time
consuming, error prone human conversion of engineering data
IEC 61850 – Data Model, logical nodes
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+
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,
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!
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$ $
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+ '
Example: Modbus and IEC 61850
Modbus
Position QA1
DA:12, 1x2347, latch reset 0x2454
Trip Ovecurrent.
DA:12, 1x1827, CD bit 1x1828
Frequency
DA: 12, 4x0488
Close CB
DA: 12, select 0x4096, close 0x4098
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IEC 61850
Position QA1
E1Q1KA1.Ctrl/QA1CSWI1.Pos.stVal
Trip Overcurrent.
E1Q1FA1.Prot/PHPTOC1.Op.general
Frequency
E1Q1KA1.Ctrl/MMXU1.Hz.mag.f
Close CB
E1Q1KA1.Ctrl/QA1CSWI1.Pos.ctVal
Voltage Level
Bay
IED
Log. Device
Log. Node
Data/Attribute
Data access and transfer (Services)
read a value / attribute
write configuration attributes
control a device (direct operate / select before operate)
event oriented communication with reporting
local storage of time-stamped events in a log
get directory information
file transfer for e.g.
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parameter and software download
upload from monitoring information like travel curves or history of gas
density values
Transfer of generic object oriented system events
(GOOSE)
Transfer of sampled (analog) values (SV)
IEC 61850 - GOOSE
GOOSE – real time sharing of information between devices in a
substation
NCC
Switch
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Control &
Protection
Control &
Protection
Switch
Control &
Protection
Control &
Protection
Control &
Protection
Control &
Protection
Control &
Protection
Control &
Protection
Control &
Protection
Control &
Protection
Based on ”publisher/subscriber” model where any device can publish data
and other subscribe it if needed
User first decides in configuration what is needed to be published and
those IEDs interested of that data subscribe to it
Mission is real-time data transmission– IED to IED 100ms / 10ms / 3ms
Uses low-level Ethernet layer and priority tagging to get priority in network
and devices
IEC 61850 – GOOSE
IEC 61850 GOOSE, What?
GOOSE = Generic Object Oriented Substation Event
Generic = Any data
Object Oriented = Data from IED 61850 data model
Substation = Whole substation sees the data
Event = Event based sending
GOOSE is used for transmit data to peer devices in substation
Can in principle transmit any kind of process data between IEDs
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Ethernet technology offers fast and reliable way to transmit the
data
Similar kind of functionality ABB have in existing LON platform
and it is already used for a decade successfully
IEC 61850 – GOOSE
GOOSE, Why?
Reduce interpanel wiring with between IEDs
Performance – faster than IO wiring
Supervised connections
Actions can taken in application if peer IED stops communication
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Quality information is sent to peer IEDs with data for validation
More (virtual) I/O for IEDs, without hardware changes
Possibilities:
Expandability
In IED retrofit cases minimised wiring changes
Chance to introduce new functionality
Due to more IO capacity and higher performance
Flexibility
Possibility to add easily functionality afterwards – no rewiring
Arc protection and GOOSE with REF615
3.
Relay A
2.
1.
1.
2.
GOOSE message
Relay B
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3.
Both relay A (incoming feeder)
and relay B (outgoing feeder) are
equipped with three arc sensors
Relay B detects an arc in the
busbar compartment via sensor 1
and sends a related GOOSE
message to relay A
Conventional wiring: <37ms
With GOOSE: <23ms
After receiving the GOOSE
message relay A checks the
current level and issues a trip
command to breaker A
-> GOOSE communication
enables fast and station wide
supervised arc protection
schemes
IEC 61850 - Blocking based busbar protection
Delay setting with inst. O/C prot.
(conventional approach)
Safety marginal, e.g. delay
in operation due to CT
saturation.
20ms
O/C protection start delay
+ output relay’s delay
<40ms
Start delay with receiving
relay + retarding time for
the blocking signal *)
<40ms
ALL TOGETHER
100ms
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*) if relays are of the same family: <10ms + 2 x relay’s ”task time”
IEC 61850 - Blocking based busbar protection
Yep, I am!
I’ll block the
Inst. O/C
block-PHIPTOC
X
IEC 61850-8-1
X
Delay setting with inst. O/C prot.
(REF615 GOOSE approach)
Safety marginal, e.g. delay
in operation due to CT
saturation.
40ms
O/C protection start delay
20ms
Retardation time of inst.
O/C stage blocking
5ms
GOOSE delay (Class 1)
<3ms
ALL TOGETHER
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Who is interested?
PHLPTOC-start
~70ms
With GOOSE better protection coordination -> more selective busbar
protection, faster fault clearing time
Circuit Breaker failure scheme with GOOSE
REF615
X
Relay A
X
REF615
GOOSE message
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Relay B
My Breaker is not
opening!
Activate Breaker
failure scheme
OK, I hear you!
I’ll open my Breaker
Relay B (outgoing feeder)
detects a fault, issues
opening command to the
breaker and starts the
breaker failure
The breaker in outgoing
feeder fails to open and
after a set time delay the
breaker failure protection
in Relay B sends out backup command as a GOOSE
message to Relay A
After receiving the GOOSE
message Relay A issues
opening command to the
incoming feeder breaker
and the fault is cleared.
IEC 61850 - 1-of-N Blocking
Local
HMI
Relay A
User issues
Select breaker
Command
before Operate
from SCS
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X
X
X
Relay C
Breaker
Selected
Relay B
In this scheme a blocking signal
is sent from selected feeder to
other feeders
No other controls allowed within
Select timeout period
Circuit Breaker control selection
is sent by the publisher and in all
subscriber IEDs this signal is
connected to the blocking input
of the control function block
When control sequence is over
subscriber IEDs get new value
change which frees the control
function block
IEC 61850 - Busbar Earthing
Earthing switch
Closed -indication
Relay A
X
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X
X
Relay C
Relay B
In this scheme a blocking signal
is sent to breakers if the earthing
switch is closed
Circuit Breaker position is sent
by the publisher and in all
subscriber IEDs this signal is
connected to the blocking input
of the control function block to
prevent closing of breakers
This schema can be made also
in opposite way where feeders
breaker position can block
closing of earthing switch
IEC 61850 – Disturbance Recording
Relay A
Detected fault
and Trip
X
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X
X
Relay C
Relay B
In this scheme a fault is detected
in one feeder
GOOSE can be used to trig the
Disturbance Recording in other
feeders
Recordings are triggered almost
parallel without delays
IEC 61850 GOOSE – Performance issues
Functionality without guaranteed performance?
GOOSE response time requirements from application to
application according the standard (IEC 61850-5) are:
Type 1 (fast messages)
Type 1A (tripping)
Class P2/3: <3ms (P2/3 = transmission S/S)
Class P1: <10ms (P1 = distribution S/S)
Type 1B (others)
Class P2/3: <20ms
Class P1: <100ms
Following IEC 61850 standard means that relay-to-relay signalling
is faster than with traditionally wiring
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Reduced wiring with faster response times
Challenge is to guarantee these in all circumstances
Sampled measured values – IEC 61850-9-2
IEC 61850-8-1
A method for transmitting
sampled measurements from
transducers
Enables sharing of analogue I/O
signals among IEDs
Benefits are obvious in highvoltage transmission substations
How about medium voltage
switchgears?
IED
Sampled
Values
Remote
BIOs
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IED
IEC 61850-9-2
Process bus
CTs/VTs
The approach: Mapping to communication stacks
Model according to state-of-the-art SA technology
SA specific data model
evolves slowly
Data Model (Objects,Services)
Communication technology
changes quickly
Splitting of SA specific
data model from
communication technology
Client Server
Communication
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ISO/OSI – Stack
Hierarchical set of
Rules how information is coded for
transmission
According to state-of-the art
communication technology
* Generic Object Oriented
Substation Event
Sampled
Values
Mapping
Abstract
Communication
Services
Interface (ACSI)
Stack
Interface
GOOSE*
MMS
Real time
Communication
TCP
IP
Ethernet Link Layer
Ethernet Physical Layer with Priority tagging
Stack selection according to the state-of-the-art
Communication technology
IEC61850-6, Engineering with help of SCL
IEC 61850-6 defines an XML based language to describe in a
defined way
Capabilities of the devices (IEDs)
How devices are connected to the primary apparatuses
How devices exchange information
This means and results
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Different device and system tools can exhance information
Efficient, automated device integration
Facilitates centrally done system engineering of systems consisting
devices from different vendors
Support top-down engineering
“Data entry only once” – engineering information is preserved and can
be utilized in other product and tools
Demo…
Future, updates, related work
After original publishing
Power Quality - Amendment 2 for IEC 61850-7-4
IEC 61850, Amendment 1: miscellaneous corrections
Models for Hydro Power Plants, IEC 61850-7-410
Models and mappings for Wind Turbines, IEC 61400-25-x
Upcoming
Ed.2 to be published during 2009
Updates, clarifications
Models for Distributed Energy Resources (DER), IEC 61850-420
Communication between substations, IEC 61850-90-1
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Related work
Communication between substation and control center, IEC 62445-2 (NP)
Information security for TC57 protocols: IEC 62351-5 (published)
IEC 62271-3, old 62010) High Voltage Switchgear and controlgear - digital
interfaces based on IEC 61850, apply 61850 for HV assemblies (published)
IEC 62439, high availability automation networks
UCA User’s Group International – for maintenance of the standard
“feedback” to IEC
“The whole scope”
IE C
618
5
0
Distributed generation
(DER)
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IEC 62351 (*
*) security within TC57, ~5 parts
IEC
50
8
1
6
(Hydro) Power Plants
Future with IEC 61850
IEC 61850 facilitates a new way of building systems
Location transparency – i.e. functions can be freely allocated within the
system, due to the efficient communication
Step 1: Simplifying signal wiring
Usage of GOOSE to replace interbay wiring
Usage of remote I/Os
To share common IO in a substation
To extend IO capabilities of an IED
Step 2: Simplifying measurement wiring and enhancing functionality
Sharing busbar voltages for all devices on a substation with Ethernet ->
more functionality for all bay level devices with same HW
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Step 3: Reallocating functionality -> centralizing
Easier maintenance, upgrades, less complicated hardware
Reliability, availability must in focus
…see next page…
Traditional
Separate interbay signal, time synchronization, external signal
wired …
DCS/NCC
Local
SCS
GPS time source
External signals
Station bus (e.g. Modbus TCP)
Clock synch
IRIG-B
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External signals
Interlocking, shared voltage signals…
Monitoring, control, settings
IEC 61850, as today
Simplification of interpanel and external signals, by IEC 61850
GOOSE for sharing interpanel and external signals
SNTP time synchronization on station bus
Local
HMI
Electrical control system
- SCS & GW
DCS/NCC
GPS time source
Station bus IEC 61850
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External signals
Monitoring, control, settings
Interlocking, shared external signals
Time synchronization
IEC 61850 - possibilities
Simpler, more cost-efficient IEDs
External and secondary IO as remote IO
All signals (including measurements) shared for all components –> less wiring
Centralized handling of control, disturbance handling, fault records etc -> easier to
maintain and extend
Complicated applications like fault location, distance protection can be implemented
using the power of centralized computer
Local
HMI
DCS/NCC
Station Computer
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Redundant looped 100Mbit/s Ethernet, IEC 61850-8-1/9-2
External signals
IEC 61850 – extremely centralized
Simplistic IEDs per bay
I/O interface and basic protection (OC, EF)
-> lower complexity: cost-efficient, maintenance, standardization, availability…
All other functionality centralized: distance, differential protection, handling
of control, disturbance handling, fault records etc
-> easy to maintain and extend the system
-> online upgrades without affecting the operation, added-value services…
DCS/NCC
Local
HMI
Station Computer
WAN
WAN
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Redundant looped 100Mbit/s Ethernet, IEC 61850-8-1/9-2
External signals
Service provider for:
- Maintenance
- Fault analysis
- Technical support
Summary - Advantages of IEC 61850
Better connectivity and interoperability
between devices and systems from different
vendors
Cost savings on substation automation
systems
Efficient device integration and system level
engineering
Simpler wiring
Support for new type of applications
Standardized high performance
communication between bays
High performance process bus to connect
intelligent sensors reducing system costs
Future-proof applications
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Application configuration withstands changes
on communication systems
Standardized, controlled way to define
extensions to the system
Newton Evans Survey 2008, future usage of IEC 61850
International
31% already use it
58% to use IEC 61850 by
2010
Only 9% no plans
27% “maybe”
International
North America
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Less then 5% use it
Only 8% have plans to use
it 2010
52% have no plans yet
39% maybe
North America
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