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1

Protection and Control Communications with IEC 61850

1 – Introduction Eric A. Udren

WSU Hands-On Relay SchoolMarch 2013March 2013

Discussion leader

Eric A. Udren 43 year distinguished career in design & application of protective relaying, control, and communications systems.

Executive Advisor with Quanta Technology, LLC of Raleigh, NC in 2008.

Developing substation protection and control upgrading strategies for major North American utilities, relay application research and design, and new data communications applications.

Developed software for the world’s first computer-based relaying system.

S i d l i d t l ft d l t f th i d t ’ fi t d l t f LAN b d Supervised relaying and control software development for the industry’s first development of a LAN-based integrated protection and control system.

Designed the first interface of a microprocessor protective relay to an optical current sensor.

Developed the technical strategy for some of the most progressive utility LAN-based substation protection and control upgrading programs using IEC 61850 and other data communications, including technical design for utility enterprise integration of substation information.

IEEE Fellow.

Chairman of two IEEE Power System Relaying Committee (PSRC) Standards Working Groups

Chair of PSRC Relaying Communications Subcommittee.

Received the PSRC Distinguished Service Award in 2001 and again in 2006.

Member of IEC TC 57 Working Group 10 responsible for IEC 61850.

Technical Advisor to the US National Committee of IEC for TC 95, Measuring Relays.

Page 2© 2013 Quanta Technology LLC Page 2

ec ca d so o e US a o a Co ee o C o C 95, easu g e ays

Member of NERC System Protection and Control Subcommittee (SPCS, formerly SPCTF).

Member of NERC Protection System Maintenance Standard Drafting Team. (PRC-005-2)

Has written and presented over 80 technical papers and chapters of books on relaying topics, and has taught courses on protection, control, communications, and integration. 2011 GA Tech PRC Walter A. Elmore Best Paper Award; IEEE Prize Paper Award.

Holds 8 patents on relaying and power-system communications.

Eric is based in Pittsburgh, PA and can be reached at [email protected] or (412) 596-6959.

2

Impact of substation data communications

SUBSTA.LAN

Substation or facility local area network (LAN)

- Lack of standard protocols and

Goal 1: Collect relay data, give control for SCADA & facility operators (speed, accuracy, completeness, interoperability).

Goal 2: Access operational and non-operational data from relays or meters for many business purposes

intervendor communications was a user issue for years.


relays or meters for many business purposes.

Goal 3: Replace wired P&C schemes with LANs.

Goal 4: Replace switchyard/power equipment wiring for instrument transformer, status, control signals with LANs.

Relay data for SCADA/EMS

RTUs connect to the same ac and apparatus signals as the relays – lots of extra wiring & electronics.

Microprocessor (µP) relays are designed for measurements status control via LAN datameasurements, status, control via LAN data communications.

Goal 1: Concentrator on LAN collects relay values and reports to SCADA & local interface computer.

Serial LAN (RS-485, multiple RS-232) still widely used.

Ethernet LAN – recommended for Smart Grid


Ethernet LAN recommended for Smart Grid applications.

Standard protocols – DNP3/IEC 60870-5 and Modbus –serial links or Ethernet LAN.

Smart Grid standards – DNP3 and IEC 61850.

3

Relay data for SCADA/EMS

Capabilities of new µP relays:

Fast response & fresh accurate data.

DNP3 and Modbus on RS-485 serial or Ethernet ports.p

IEC 61850 MMS server-client functions.

IEC 61850 GOOSE high-speed publish/subscribe of status, metered analogs, synchrophasors.

IEEE C37.118 synchrophasor streaming.

Trial in 2012 – 61850-90-5 high security WAN


Trial in 2012 61850 90 5 high security WAN synchrophasors and wide-area GOOSE.

S b t ti

Control centers- EMS &SCADA

Planning &models

Management

Goal 2 - Enterprise information – reliability & economic benefits

SubstationLAN

CORPORATE WAN with

firewalls & push servers

Integrate relay data communications to the enterprise

Dashboard

Asset M t

Maintenance


serversSubstation

LAN

Databases & back office applications for organizational

users

Management

Protection & Control

Engineering & models

4

Relay data for non-operational users

Goal 2: Use the same communications facilities to get non-operational data to the enterprise:

Fault location, outages, failures, and system maintenancemaintenance.

Fault and disturbance recordings, event logs.

Relay and IED self monitoring and failure reporting for condition based maintenance in NERC PRC-005-2.

Performance statistics - protection & communications system management.


system management.

Power apparatus monitoring by relays and IEDs.

Measurements for trending system operations –planning, engineering, and protection.

Substation revenue metering.

Protection & control over Ethernet LAN

Goal 3: Replace control wiring with messages on data networks.

Substations & systems with IEC 61850 GOOSE messaging on optical EthernetGOOSE messaging on optical Ethernet LANs in service.

Carry status & control points, including tripping and lockout.

High-speed analog values capability.

M & l l i l i


Messages & relay logic replace wires, control switches, lockout switches.

Dramatic wiring reduction in the station.

Can be faster than wiring.

5

Sampled Values service on process bus

Goal 4: Replace switchyard/facility wires with a few optical fibers.

Eliminate conventional cables and surge/EMI pickup


Eliminate conventional cables and surge/EMI pickup.

Move some measurement and control closer to the power apparatus.

Move the relays away from the apparatus.

Why focus on Ethernet communications?

Important – Ethernet networks bi ti f i dcarry any combination of mixed

traffic types, protocols, services…

• Network tools to manage & prioritize mixed traffic.

• Modern Ethernet switches end old concerns about non-deterministic network traffic with collisions.

Mission critical electric tilit /ind strial applications in ser ice


• Mission critical electric utility/industrial applications in service.

• Extra network capacity gets cheaper rapidly.

• Development of IT is crowding out other approaches.

6

Big standard, evolving for 18 years and still going...

10 original parts – now in Edition 2, plus >23 new parts!

Multiple services not a monolith:

IEC 61850 ‐ Communication networks and systems for power utility automation

Multiple services – not a monolith: Server-client design for Ethernet networks.

Application layers for utility/industrial system application.

High speed protection, control, and sampled data streaming services.

System-wide data and control services and methods.

Single international standard for power system communications.

N t j t t l i l d f ti d li t d d


Not just a protocol – includes function modeling standards.

Recognized by DOE & NIST as a Smart Grid communications backbone – NIST Smart Grid Interoperability Panel (SGIP) Category of Standards (CoS) listing.

What is IEC 61850?

A single international Ethernet based standard data communications

protocol & model structure with services and features aimed at protection

and control requirements:

Relay/IED measurement & control exchanges with substation hosts –

RTUs, concentrators, HMIs – client-server objects.

High-speed status, control, analog value transfer over LAN to eliminate

control wiring – GOOSE messaging.

Switchyard/switchgear data acquisition and apparatus control – sampled

values (called process bus).

Services for time synchronization (SNTP - obsolete), file transfer (FTP).

Reporting and configuration services


Reporting and configuration services.

Standardized automatic configuration of substation IEDs (SCL).

New wide-area communications services.

Vision of a complete solution to replace existing diverse protocols and

communications systems.

7

IEC 61850 is not just a protocol on a wire…

• A modeling approach, a system architecture, and a protocol.

• Multiple services.

Models forP&C functions &

Ti

Switchyard sampled value

streaming

IEC 61850Architecture

High-speed GOOSE control

messaging

TCP/IP

Ethernet LAN/WAN

Standardizedconfiguration process

points


Timesynch

with SNTPCOMTRADEFault records

TCP/IP, UDP/IP, Layer 2

multicast

US approach UCA™ 21994

Evolution of IEC 61850

DNP3 becomes IEEE 1815 & stays strong

European

The international goal – agree on a single standard

US approach UCA 2

1996

One standard

IEC 61850

2000-2012

May 2000Asheville, NC


European experienceIEC 60870-5IEC 60870-6

IEC 61850UCA 2 & IEC

61850 “merge”

IEC 60870-5 – vendors shifting support away…

8

IEC 61850 wiring reduction

Integrated P&C system using fiberoptic network cables

Ethernet

Conventionalpoint to point wiring

Standardobjects


objects,models,

& pointdescriptions Be careful – the wiring

goes away, but not the complexity...

Part 1: Introduction and Overview Part 7-4: Compatible Logical Node Classes and Data Classes

Part 7-3: Common Data Classes

Part 7-2: Abstract Communication Services

System Aspects

Part 2: Glossary

Part 3: General RequirementsPart 4: System & Project Management

Data and Services Model

IEC 61850 Edition 1 Documents

Configuration

Mapping to Ethernet

Interface (ACSI)Part 7-1: Principles and Models

Part 4: System & Project Management

Part 5: Comms. Requirements for Functions and Device Models

Part 8-1: Mapping to MMS and ISO 8802-3 (Ethernet)

Part 9-1: Sampled Values over Serial Unidirectional Point-to-Point link

Part 6: Configuration Description Language for Communication in Electrical Substations


Part 10: Conformance Testing

Technical Report / Specification

using ISO 8802-3 (defunct)

Part 9-2: Sampled Values over ISO 8802-3Test

Electrical Substations

International Standard (IS) 9-2 LE: UCA Implementation Agreement for merging units in switchyards (LE = Lite Edition)

9

IEC 61850 as multivendor standard Aims for integration of multiple vendors’

devices.

Each product has its own list of implemented

services and features.

Conformance – a product is tested to validate

that its included services conform to standard

specs.

Vendor gets KEMA, TÜV SÜD, etc. certificate.

Interoperability – two or more products actually

exchange information (no certification yet).


exchange information (no certification yet).

Be aware of compliant creativity, generic

modeling shortcuts. Will products actually

interoperate?

Performance – a system of products performs

the application properly (no certification yet).

OSI 7-Layer Communications Stack

Layer Name Function

7 Application Meaning of the data (utility user specifics)

6 Presentation Building blocks of data and encryption for security

5 Session Opening and closing specific communications paths

4 Transport Error checking

3 Network Determining the data paths within the network

2 Li k i i d d i i h k


2 Data Link Data transmission, source and destination, checksum

1 Physical Signal levels, connections, wires, fiber, wireless

10

MMS

IEC 61850 Applications

A li ti P fil

IEC 61850 profile or stack - client-server exchanges

ISO CO Session

ISO CO Presentation

TCP

IP

RFC1006 - ISO TP0

Application Profile

Transport Profile


Ethernet

Fiber, Twisted Pair Cu

p

Client - serverSampled

Application (Objects,Services)

IEC 61850 Communications stack mappings

Client - server communications

GOOSESampledValues

High-speed messaging on LAN – skip WAN

layers and processing

MMS

Mapping


Ethernet Link Layer (with Priority, VLAN)

Ethernet 100 MB/s Fiber

aye s a d p ocess gdelays

TCP

IPGOOSE &Sampled Values:Layer 2 multicast

11

IEC 61850 Station Bus protocol services

SCADA

Station bus mappings (8‐1)

For SCADA, protection, control, and information for the enterprise

Obj t MMS d TCP/IP l

Station Bus

SubstationHost

•Objects on MMS and TCP/IP layers

•GOOSE (on Data Link layer 2)

•Time synch (SNTP) [Later IEEE 1588/C37.232]


Relay 3IED2Relay 1

MU - VTMU - CTProcess Bus

IEC 61850 server-client object services

The bulk of the standard (Parts 7-1, -2, -3, -4; new 7-5, new applications) describes object modeling methods.

In general, relays and IEDs are servers; higher-level computers and systems are clients.

Data messages include point descriptions or semantics – self-identifying.

Products are self-describing – aimed at making configuration faster and easier than with manual point


configuration faster and easier than with manual point maps used with other protocols (Substation Configuration Language, Part 6).

12

Object models - logical groupings

Data

Logical Device

LN2(MMXU)

LN1(XCBR)

Pos A

Ph 1 Ph 2StV q

Logical Device(1 to n)

Logical Node(1 to n)

Data Class

Data


Physical Device(network address)Physical Device(network address)

(IED1)Physical Device

A single name always used for a particular function.

E h b i f i h

Logical Node (LN)

Each substation function may use one or more other logical nodes to perform its job (e.g., distance protection needs measurements from logical nodes CT and VT).


13

L: system LN (2) M: Metering and measurement (8)

P: protection (28) S: Sensor and monitoring (4)

R: protection related (10) X: switchgear (2)

Logical node groups

C: control (5) T: instrument transformers (2)

G: generic (3) Y: power transformers (4)

I: interfacing and archiving (4) Z: further power system equipment (15)

A: automatic control (4)

Examples of Logical Nodes (LNs):


p g ( )

PDIS: Line distance protection

PDIF: Differential protection CSWI: Switch controller

RBRF: Breaker failure MMXU: Measurement unit

XCBR: Circuit breaker YPTR: Power transformer

Disconnect sw.Q9_L1/XSWI

Grounding SwitchQ8_L1/XSWI

Logical Nodes (LN)Control

Q0/CSWIQ8/CSWIQ9/CSWI

Bay-HMIIHMI


Primary equipmentControl house equipment

Distance ProtectionPDIS

Circuit BreakerQ0_L1/XCBR

Gas density monitoringQ0_L1/SIMS

14

Accessing data

PTOCRREC

+

+IED1/XCBR.Pos

IED1

Tree view

Mode (Mode)Beh (Behavior )Health (Health)Name (Name plate)Loc (Local operation)EEHealth (External equipment)EEName (External equipment name plate)O C t (O ti t )

+

+

+

+

+

+

+

XCBR-


OperCnt (Operation counter)Pos (Switch position)BlkOpen (Block opening)BlkClos (Block closing)ChMotEna (Charger motor enabled)CBOpCap (Circuit breaker operating capability)POWCap (Point On Wave switching capability)

+

+

+

+

+

+

+

Accessing data

Mode (Mode)+

XCBR

PTOCRREC

+

+

-

IED1/XCBR.Pos.stVal

IED1

Mode (Mode)Beh (Behavior )Health (Health)Name (Name plate)Loc (Local operation)EEHealth (External equipment)EEName (External equipment name plate)OperCnt (Operation counter)Pos (Switch position)

+

+

+

+

+

+

+

+

-


( p )ctlValstValpulseConfigoperTimq…more

intermediate-state (0)off (1)on (2)bad-state (3)

15

Helpful explanation of 61850 modeling

By Karlheinz Schwarz


By Karlheinz Schwarz, Netted Automation GmBH

Seehttp://www.nettedautomation.com/qanda/iec61850/information-service.html#Q1

Example:

Substation (S151) – Voltage level (E1) – Bay (Q3) Physical Device (BC) – Logical Device (CTR)

Hierarchical standard object naming

<prefix> <Logical Node> <instance>

Data description (from common data class, CDC)

Attribute – the current value

In MMS notation: S151E1Q3 $ BCCTR $ Q0XCBR1 $ Pos $ ST$ stVal

Interpretation: (Substa-V-bay) . (Physical box, and functional l i hi h h b k i ) (I f B k


element within that has breaker image) . (Image of Breaker Q0) . (Data name Pos is position value) . Functional Constraint ST (a momentary status report only) . [the status value report – transition, open, closed, invalid]

16

LN example – control, breaker, voltage reg.


Note generic LNs – manual config. – versus std. defined LNs supporting auto config.

Time synchronization

IEC 61850 specifies simple network time protocol (SNTP) from the IT world.

Accuracy assured only within a few milliseconds y y(although some claim better recently).

Requirement for time stamping of events and oscillographic records is 1 ms (from NERC, for event analysis)

Requirement for time synchronization of waveform


equ e e t o t e sy c o at o o a e osampling for process bus merging units is 1 to 10 microseconds, tighter for synchrophasors.

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Time synchronization

The practical solution – wired IRIG-B or fiber connections of time synchronization signals directly from GPS clock IED to IEC 61850 servers and clients.

Same as non-61850 practice

Leaves a few wires in an otherwise clean design

IEEE 1588 – a new standard for time synchronization on a LAN with sub-microsecond accuracy – IEC 61850 profile started at IEEE PSRC WG H7.

PC37 238 IEEE 1588 Profile for Protection Applications


PC37.238 IEEE 1588 Profile for Protection Applications

Configuration with 61850-6 SCL tools

Unified configuration of entire facilities via XML file process – even over wide area.

Not exactly plug-and-play.


Functional specifications & design standards

18

Some configuration tools

Siemens DIGSI (oldest)

GE EnerVista (umbrella for many functions; SCL added)

SEL AcSELerator Architect

ABB ITT Integrated Toolset (recent benchmark, but only ABB)

Applied Systems Engineering (ASE) Visual SCL

Triangle Microworks SCL File Editor, Anvil, Forge…

Kalkitech SCL manager

Helinks (from 61850 developers)


Grid Smart 61850easy – handy diagnostics

Tools are biggest challenge – area of active work and user complaints.

2 - GOOSE Messaging and Networks


Eric A. UdrenWSU Hands-On Relay School

March 2013

19

Fast relaying over Ethernet LAN

From Part 1 -

Goal 3: Replace control wiring with messages on data networks.

Logic in the relays exchanges messages overLogic in the relays exchanges messages over high speed redundant optical LANs to replace wires, control switches, lockout switches.

Dramatic wiring reduction in the station.

Many installations designed with IEC 61850 GOOSE messaging on LANs are in service.

Status points control including tripping and


Status points, control including tripping and lockout, high-speed analog values.

Can be faster than wiring.

Role of IEC 61850 GOOSE messaging

IEC 61850 GOOSE messaging provides:

High-speed peer-to-peer transfer of status/control bits (reporting

contact state over a wire) or analog values including synchrophasors

for protection and control.

GOOSE messaging plus programmable logic in relays and IEDs

replaces panel wiring and controls.

Benefits – wiring and control elimination, panel and floor space

reduction, less equipment overall in P&C system, continuous

monitoring and management of the system design (“wiring”)


monitoring and management of the system design ( wiring ).

Works with other IEC 61850 services, or without them (e.g., with

60870-5 or DNP3 polling for SCADA)

20

61850 GOOSE and GSSE messaging

Generic Object Oriented

Substation Event.

A relay or IED can send a y

sequence of control, status point,

or analog value messages to

replace control and measurement

signals on dedicated wires.

Not just a single message to request remote action…

A process to “continuously” send intended state from


A process to continuously send intended state from

transmitting IED – like a contact that picks up and drops out

at critical moments.

Even if a subscribing (receiving) relay is just powered up, it

can get updated status it needs.

GOOSE Protocol in 61850-8-2

Application layer directly accesses link layer for speed – no TCP/IP

Uses Ethernet frame directly with Priority/VLAN 802.1Q tag

Use priority ≥4 due to criticality or messages.

VLAN use is optional.p

Fields in payload - source ID, status bits, analog values, time stamp, sequence number, time to live, quality bits, test modes.

Typical packets 200 – 300 bytes long.

Ethertype (8100 = Ethernet


21

Publisher-subscriber exchange:

Each relay publishes a continuous stream of packets with values that others might need.

Overview of GOOSE messaging

Any other relay or IED can subscribe to (view contents from) the streams it needs.

Publisher just talks – does not know who subscribers are, or whether they got the messages in the stream.


Overview of GOOSE messaging

Adaptive rate of GOOSE message transmission:

• Time values are examples in standard – manufacturers vary.

• Some let you set base heartbeat rate and acceleration profile.

• Heartbeat reports values during quiescent times:

Communications monitoring by all subscribing relays


– Communications monitoring by all subscribing relays.

– Update of latest status in case of any relay on the LAN that was

just turned on.

• Modern LAN with Ethernet switches handle all the messages even for

a worst-case power system event.

22

GOOSE packet rates

SEL example, set 1 s heartbeat:

Message b

Interval from i

Time k

GE UR V5.70 example:

number previous, ms mark, ms

1 N/A 0

2 4 4

3 8 12

4 16 28

5 32 60

6 64 124


6 64 124

7 128 252

8 256 508

9 512 1 s

Did the GOOSE messages arrive?

Publisher-subscriber exchange:

• Unconfirmed service, backed up by:

Constant repetition or updating– Constant repetition or updating.

– Redundancy in LAN and relaying

architecture.

– Monitoring and alarming by subscriber

IEDs that fail to receive publisher’s

message stream – call maintenance for


repair.

Wires cannot continuously monitor

themselves as GOOSE messages can do!

© 2011 Penwell & Quanta Technology LLC

44

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Analog GOOSE messaging

Concept - send analog values with same millisecond exchanges as for status or control points.

Change events defined by settable measurement Change events defined by settable measurement deadband.


Multiple values in one GOOSE packet.

Analog GOOSE messaging

Products today:

Send analog values at a fixed slower rate – 100 ms or 250 ms – not as useful for relaying as GOOSE t t i tstatus points.

Some will send values at rate driven by status points in message, but analogs are repeated and updated every 100 to 500 ms.

NEW: publish synchrophasor values at a rate of 2 to 4 per second (GE and SEL) - Synchrophasor time


4 per second (GE and SEL) Synchrophasor time tags in packets.

Ask vendor how to get at GOOSE time tag – not the same as synchrophasor time tag.

This GOOSE is too slow for high speed WAMPAC.

24

Speed of GOOSE messaging

GOOSE message control can be faster than a wired connection! Save 1-4 ms. How?

A wired trip signal goes through:

The relay processor output program loop delay.

Output delay of hardware interface to wires.

Input debounce filter delay of receiving relay.

Signal waits milliseconds for the input processing


g p p gprogram logic loop to notice it and react.

GOOSE message bits are sent and read directly between relay processors with microsecond Ethernet delays.

Products vary – ask manufacturer, or test.

Electromechanical lockout switch drawbacks

Adds 1 cycle operating time.

Funnels wiring from bus full of breakers into one panel location.

A lot of wiring.

Wiring reflects and must adapt to changes in substation topology or relaying philosophy.

Rarely operates in normal service j d d ’t t i


– some jam and don’t trip.

Dangerous testing challenge -NERC says test it.

Big cost adder to scheme –deterrent to differential relay use.

25

Distributed lockout with GOOSE

Each relay with relevant breaker control keep track of lockouts in effect, by logic programming.

Relays are coordinated by the lockout initiating relay, or b t ti t l k t it f tiby a station computer lockout monitor function.

Each relay has a nonvolatile memory of lockout state (some use mechanically latched output relays).

Uses messaging capabilities already in new relays.

No extra wiring or cost.


Self monitoring feature eliminates testing problem.

As fast as direct tripping.

See 2009 NETAWorld article by Myrda, Donahoe, Udren for design example.

Ability to trip is monitoredEnd-to-end check of GOOSE communications:

Transformer relay publishes a GOOSE message including a bus breaker trip bit.

Normal-state message (do not trip) is generated every second by DSP in transformer relay.

Passed through communications network to bus relay DSP

Bus relay DSP alarms if no-action message disappears.

Wires cannot check themselves this completely!

Line RelayBus Relay

System A


System ASystem A

Xfmr Relay

System A

Monitor IED

System A

Ethernet Switch

System A

52TC

26

Engineering of mission

Redundant station bus for IEC 61850 GOOSE messaging

Engineering of mission critical substation Ethernet network

No single point of failure within each of dual redundant LANs.

Use relay primary and f il ti l Eth t


failover optical Ethernet ports.

Dual switches and paths for GOOSE messages.

Multicast GOOSE messages have no destination address

Designed to stay within a LAN or Virtual LAN.

Do not pass through routers to the WAN or other LANs.

GOOSE and wide area networks

But –routers make secure bridged connection between two LANs separated by a WAN – works like one big LAN.

Useable for transfer tripping, monitoring, control or load mitigation via WAN.

Need cyber security – VPN, firewalls, etc.

Slows down messaging today 20 ms getting faster


Slows down messaging – today 20 ms, getting faster.

See IEC 61850-90-1 for teleprotection over WAN examples.

See 61850-90-5 for new GOOSE streaming over WAN.

52© 2013 Quanta Technology, LLC

27

Settings management

Need a closed-loop business process that initiates and tracks all installation and updating of setting records.

Communicates with the IEDs themselves (over WAN is future method) to check consistency between the data base and the installed settings and firmware.

Need a convenient way of installing settings within the management system in every use case.

Firmware update, maintenance check, operating emergency, relay replacement, etc.

New software data base tools can connect with tested d i t t i t d f t


devices, test equipment, and enforce management processes – OMICRON, EnoServ, IPS, others.

This is a big need for all 61850 services and systems, and all new complex relays and IEDs!

Using 61850 services on the LAN

Use client-server exchanges of standard defined objects for metering, status, control, and IED configuration.

Metering and status via polling or report-by-exception.

No visible impact on installation – benefit is drive to easy No visible impact on installation benefit is drive to easy engineering and maintenance.

DNP3 can perform similar role with familiar manual point configuration lists.

GOOSE messaging and Sampled Values service get rid of conventional control wiring among relays, IEDs, power apparatus –design commitment; visible change.


DNP3 has no high speed data or control ability like GOOSE or Sampled Values

New – 90-5 R-GOOSE and R-SV over WAN.

LAN can carry mixed traffic – e.g. DNP3 metering and status, non-61850 legacy device traffic, plus GOOSE for wiring elimination.

28


3 - Recent Developments in IEC 61850Eric A. Udren

WSU Hands-On Relay SchoolMarch 2013

IEC 61850 is living and growing

IEC 61850 Edition 1 – the seed – 1700 pages

IEC 61850 Edition 2IEC 61850 Edition 2

International application –improved models

Expanded structure

Improved clarity

TISSUES (b ) l d


TISSUES (bugs) cleared

New practical features

New application domains

29

IEC 61850 is branching

New parts of IEC 61850

Expanding outside the substation Between substationsBetween substations

To control centers

Communications and application modeling across the entire power system

Integration with enterprise systems


systems

Interfaces with popular SCADA and control protocols

Wide-area high-speed data & control services with security

What is new in Edition 2 of existing parts?

Clarifications and corrections (TISSUES)

Modeling

Power Quality

Statistical evaluation of information

New models for mechanical equipment and measurements of non-electrical quantities

New features for testing support

Support for exchange of engineering information for configuration across projects and between facilities


configuration across projects and between facilities

Redundancy – possibility to have IEDs with dual connections

30

Testing improvements

• Edition 1 required expedient user construction of testing facilities (mainly with GOOSE).

Edition 2 –

/f f• Mirroring/feeding back control information

• Isolation of functions in service

• Interlocking test methods


IEC 61850 – new parts

New facilities modeling:

IEC 61850-7-410 – Hydroelectric power plants –Communication for monitoring and control

IEC 61850-7-420 – Communication Systems for Distributed Energy Resources (DER)

IEC 61850-7-500 /-7-510 (Technical Reports)

Explains how to use the concepts of IEC 61850 to model applications


IEC 61400-25-x – Communications for monitoring and control of wind power plants

31

More new parts under development

Part 7-5 - defines the usage of information models for substation automation applications - examples on how to apply logical nodes from 7-4 for various applications.

Part 7-10- web based IEC 61850 models

More consistent implementations than those from programmers reading paper documents.

Part 100-1 - Methods for functional testing in IEC 61850 based systems.

Configuration management of IEC 61850 based systems


Configuration management of IEC 61850 based systems

Mappings for gateways

IEC 61850-80-1 – Guideline for exchange information from a common data class (CDC) based data model using IEC 60870-5

Station Controller & Gateway

60870

61850

data model using IEC 60870 5

IEC 61850-80-2/IEEE 1815.1 – Exchanging Information between networks implementing IEC 61850 and IEEE 1815 (DNP3)

DNP Master

DNP Outstation

Bay Controller

61850

Protection

61850


(DNP3) Just starting – IEEE C37.118

synchrophasors to IEC 61850-90-5 synchrophasors – at PSRC

IEC 61580 Client

IEC 61850 Device

IEC 61850 Device

IEC 61850 Device

IEC 61850 Device

Gateway

32

How to address new areas?

Technical reports explain “How to use IEC 61850 for...“

Technical reports describe:

The use cases considered

The impact on the communication

The impact on the modeling

The impact on the engineering

Results will be used to update the standards later. ( d t diti )


(amendments or new editions)

Technical reports (not standards)

IEC 61850-90-1: Using IEC 61850 for communication between substations (published)

IEC 61850-90-2: Using IEC 61850 for communication b t b t ti d t l tbetween substations and control center

IEC 61850-90-3: Using IEC 61850 for condition monitoring

IEC 61850-90-4: Network engineering guidelines

IEC 61850-90-5: Using IEC 61850 to transmit h h i f ti di t IEEE C37 118


synchrophasor information according to IEEE C37.118

Really important – how to stream sampled values, synchrophasors, or GOOSE messages over WAN with security using standard IT services

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90-1 on interstation communications

61850 communications, modeling/semantics, & system engineering across stations need Ethernet communications. GOOSE needs LAN, or equivalent…

Ethernet between stations:

Wideband direct interfaces of LANs

Tunnel that filters and directly passes packets over WAN

Gateway that acts as a proxy for packets – e.g. teleprotection device

Ethernet LAN/WAN configuration advice

Station A Station B??

Teleprotection equipmentacting as gateway

?


Function A1

Function A2

Function B1

Function B2

Transparent Tunnel

??Proxy

B1

?

61850-90-2 and 90-3

90-2 - Using IEC 61850 for the communication between substations and control centers – in development

90-3 – Condition monitoring of primary power apparatus –communications & asset management requirements:

Transformers, LTCs

GIS

Lines, UG cables

Sta. batteries


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Part 90-4 - Network Engineering Guidelines

Ethernet network& physical layers were black box – you make it work.

Now – comprehensive guidance on reliable network design.


Part 90-4 - Network Engineering GuidelinesLayer 2 redundant network paths for protection messages

Short-bump or bumpless rerouting for segment failures

62439-3 Parallel Redundancy Protocol (PRP) – 2 LANs

62439-3 High availability Seamless Redundancy (HSR)

Rapid spanning tree protocol (RSTP) from IT and redundancy – simple and fine!

DANH

CPU

DANH

CPU

source

„A“-frame(HSR)

„B“-frame(HSR)

destinations

„C“-frame „D“-frame

DANH

CPU

DANH

CPU switch

RedBox

singly attached nodes

interlink


DANH

CPU

DANH

CPU

DANH

CPU

DANH

CPU

DANH

CPU

DANH

CPU

DANH

CPU

DANH

CPU

DANH

CPU

DANH

CPU

destinations

35

90-5 WAN synchrophasor transport

Sampled Value or GOOSE publish/subscribe across the WAN – useful way beyond just synchrophasors.

Add layer 3 transport – UDP/IP unicast or multicast (unconfirmedefficient stream of data packets – not like slow, confirmed TCP/IP)p , )

Routers can search for subscribers and establish routes dynamically using Internet Group Management Protocol (IGMP) V.3, a standard IT router service.

New - a big deal – end-to-end authentication in the packet!

SHA-2 authentication hash code - computed in real time.

Needs new PMU/relay platforms/processors to compute


Needs new PMU/relay platforms/processors to compute authentication hash code (coming in 2012).

Industry standard Group Domain of Interpretation (GDOI) security key distribution/management.

Packet encryption specification – can be done in routers.

WG17 technical reports - SG integration

• IEC 61850-90-6: Using IEC 61850 for distribution automation.

• IEC 61850-90-7: IEC 61850 object models for photovoltaic, storage

and other DER inverters.

• IEC 61850-90-8: IEC 61850 object models for electrical vehicles.

• IEC 61850-90-9: IEC 61850 object models for battery storage systems.

• IEC 61850-90-10 – DER scheduling.

• IEC 61850-90-11 – Modeling of


IEC 61850 90 11 Modeling of

programmable logic per IEC 61499.

• IEC 61850-90-14 – Modeling of FACTS

power controllers

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IEC 62445-2 Standard for communications between substation and control center.

C C f C

Other standards projects supporting IEC 61850

IEC 62351-6 - Cyber security structure for IEC 61850.

Harmonize data models of IEC 61968 Common Information Model [formerly EPRI CIM] and IEC 61850.


Product development

61850 compliant relays and IEDs are widely available.

It’s been a long expensive road for manufacturers – they are committed to development.

See http://www.ucausersgroup.org/ for list of compatible d t d th i f tiproducts and other information.

In early 2012 – lots of servers (relays), growing choices for clients (substation hosts), emergence of commercial process bus (sampled data) systems based on IEC 61869-9.

Learn status at UCA International Users’ Group http://sharepoint.ucausersgroup.org/default.aspx

Reports and related standards developments at IEEE Power S t R l i C itt (PSRC) ti


System Relaying Committee (PSRC) meetings http://www.pes-psrc.org/

Articles in PACworld magazine http://www.pacw.org/home.html

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IEC 61850 – supported in products

Embeddable stacks for sale to IED manufacturers – Triangle Microworks and SISCO.

Supported by IED manufacturers – SEL, GE, Siemens, ABB, Alstom Grid/Schneider, ZIV, RFL, Ametek Pulsar, others.

R l t t t f t i t d i 61850 d t Relay test set manufacturers introducing 61850 products –OMICRON, Doble, Megger, others.

Industry-standard conformance testing program per 61850-10 and UCAIUG program with laboratories.

Substations with significant 61850 in North America since 2005 – going into design standards at large utilities.

Used in critical special protection schemes.


IEC 61850 versus DNP3

DNP3 Pros –

IEEE 1815 standard, long complete (according to its own targets)

Widely sold and used

IEC 61850 Pros –

Single international Smart Grid integration standard suite

All required services

All major vendors support Widely sold and used.

Debugged, stable

Supported by Users’ Group

DNP3 Cons –

No high speed control or data services,

Just for SCADA

High-speed control (GOOSE) and process data (Sampled Values) including wide-area and security

Models the functions for automated integration process (little hand configuration)

Supported by Users’ Group

IEC 61850 Cons –

Integration tools have been work in progress


Just for SCADA

Manual configuration of points and data types takes time.

Mostly North American

Integration tools have been work in progress for a long time

Interoperability work in progress

Big product development effort, depending on scope focus.

Design for usability and maintenance is an area of opportunity

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Troubleshooting Ethernet/61850 systems

Function level monitoring - program the relay logic to report data sent/received – catches most problems!

This is an IT network.

Basic tools for Ethernet networks – e g WireShark Basic tools for Ethernet networks – e.g., WireShark

Protocol-specific tool examples:

Applied Systems Engineering DNP3 Analyzer

SMC 61850 GOOSEMeter (hand tool)

61850Easy configuration/troubleshooting tools

SISCO AXS4MMS Client - analyzer for relays (servers).


SISCO GOOSE Blaster simulator

NetScout network traffic monitoring for GOOSE

Most important – design functional test features into the logic.

61850 progress

Massive standard – growing beyond 2000 pages (users don’t need to read all this).

Continuing development and issue resolution among vendors users and standards developersvendors, users, and standards developers.

Edition 2 and new parts of 61850 are being published.

Supported by today’s major relay vendors.

Paper and article traffic reaching saturation level.

Varying interpretations by vendors require industry conformance test program


conformance test program.

61850 reaches inside the devices – there are problems – get experienced guidance for standard development.

DNP3 remains a widely used client-server protocol that works on Ethernet (hand point map; no GOOSE).

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Steps of typical IEC 61850 project

Each utility has unique organization and needs

1. Data gathering – engage all stakeholders up front!

2. Develop specifications.

3. Develop Request for Information (RFI) with specs.p q ( ) p

4. Conduct RFI & process – get back a practical plan?

5. Business case - justify proceeding?

7. Full specifications.

8. RFP & vendor selection for trial standard system.

9. Detailed design with vendors.

10. Organizational design and preparation.


10. Organizational design and preparation.

11. Development lab, training facilities.12. Field trials.

13. Standards development; procedures and documentation.

14. Interface systems to the utility enterprise.


4 - Sampled Values Service & Process BusEric A. Udren

WSU Hands-On Relay SchoolMarch 2013

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Sampled Values service for process bus

If a LAN can carry critical relaying traffic in the controlh it d t dhouse, can it carry data andcontrol between the switchyardand the control house?

Goal 4: Replace switchyard wires with a few optical fibers.

Eliminate conventional cables and surge/EMI pickup.

Move some measurement and control out to the yard, closer to the power apparatus


power apparatus.

Just a few wires left - we still have to get dc and station service power out to the yard.

Process bus

Voltages, currents, and status sampled near the source and converted directly to Ethernet packet stream.

Multiple sample sets per packet for data transmission efficiency.

Support trend towards intelligent power apparatus - relays, metering, control IEDs installed directly in the power apparatus, even in the factory.

Reduce field wiring cost.

Cut wiring losses and burdens.

Add field signals without new wiring to control house.


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Process Bus concept

µP1 OR

MORE

A/DSub-

systemCTs,VTs

LP FILTER

LP FILTER

LP FILTER

LP FILTER

MUX

SAMPLE AND

HOLD

Ethernet Network Communications

If we cut a microprocessor based relay in two and put a communications bus between the I/O and the processing...

Comm.Controller

A/DSub-

systemMUX

S/H & Filter

S/H & Filter

S/H & Filter

S/H & Filter

O/E

SubstationLAN

Control House Switchyard

VTsRelay Output

Relay Output

Relay Output

Trip andalarmcircuits

Contact Inputs

Statuscontacts

POWER SUPPLY

125 Vdc Station Battery Supply


µP Comm.Controller

µP Comm.Controller

O/E

Relay Output

Combining data from diverse locations around the switchyard

Process Bus LAN

Comm.Controller

A/DSub-

systemMUX

S/H & Filter

S/H & Filter

S/H & Filter

S/H & Filter

Relay Output

Optical fibers

Process bus services in 61850-9-2

•Sampled values protocol (on data link layer 2 for speed and simplicity)

•GOOSE (on data link layer 2 for d d i li i )

SCADA

speed and simplicity)

•Time synch (SNTP)

Relay 3IED2Relay1

Station Bus

SubstationHost


yIED2y

MU - VTMU - CT Process Bus

MU = switchyard Merging Unit

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Line Protection Bus Protection

EthernetController

EthernetController

Merging unit

Merging Unit

Ethernet Controller

IEC 61850-9-2 Process BusBinary Inputs &

Control Outputs

Ethernet Switch

C37 92 OVT

Sample timing synchronization


withCombined

ECT and EVT

MOCT fiber

EOVT fiber

Conventional VTs

Conventional CTs

C37.92 OCT

C37.92 OVT

Process Bus Protocol in 61850-9-2

Application layer directly accesses link layer for speed – same as GOOSE

messaging – no TCP/IP

Uses Ethernet frame directly with priority/VLAN .1Q tag

Use priority ≥4 due to criticality or messages, same as GOOSEp y y g ,

VLAN use is optional

What goes into the packet payload?

Ethertype (8100 = Ethernet


43

IEC 61850-9-2 frame – generic and flexible

Octets 8 7 6 5 4 3 2 1 Notes

Preamble

Start of frame 0 1 2

23 4 5

Destination address

6 7 8 9

10 11

Header MAC

Source address

Refer to “AddressFields” section.

12 13

TPID

14 15

Priority tagged

TCI

Refer to ”Priority Tagging/VirtualLAN

section.

16 17

Ethertype

18 Length Start 19

APPID

20 Ethertype PDU

Octets 8 7 6 5 4 3 2 1

1

2 TPID

0x8100 (802.1Q Ethertype)

3 User priority CFI VID

4 TCI

VID

Service Default VID Default priority


2021

Length (m + 8)

22 23

Reserved 1

24 25

Reserved 2

26 .

m + 26

APDU (of length m)

Ethertype PDU

Refer to “Ethertypeand Other Header

Information” section.

. .1517

(Pad bytes if necessary)

.

.

. .1521

Frame check sequence

Service Default VID Default priority

Sampled Values 0 4

9-2 LE Implementation Guideline


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IEC 61850-9-2 LE Data Set

Fixed sampling rates of 80 or 256 samples per power cycle at 50 or 60 Hz.

Fixed data frame format

Fixed configuration format


9-2 LE fiber 1 pps synchronizing clock input specs


45

Unified substation-wide LAN using 9-2 LE


Chopping up the ring for redundancy

Design concept of big ring station/process bus does not separate the zones

of protection – zones share merging units and communications.

Relay engineers are used to separating zones of protection for reliability &

failure mode handling.g

Another way to apply MUs –

dedicated merging unit

function for each zone,

each location, and

System A or System B

– full redundancy and

isolation.


isolation.

This takes a lot more

equipment but

separates zones.

46

Another direction – 61850-9-2, but not 9-2 LE

GE Multilin HardFiber® process bus system.

Uses conformant 61850-9-2 sampled values frame.

Uses 61850-8-1 GOOSE for sampling synchronization and control .

61850-8-1 GOOSE is not how 9-2 LE synchronizes sampling – not compatible with other vendors’ MUs.

Technically thoughtful (an opinion) architecture solution that addresses application concerns:

Isolation of protection zones.

Isolation of redundant systems.

Works ith toda ’s GE UR rela s


Works with today’s GE UR relays.

Each relay drives its own data sampling, as it does conventionally.

Tracks system frequency and avoids distance relay polarizing problems.

Design includes solutions to installation efficiency and testing issues.

GE HardFiber® process bus system

Weatherproof Brick® mounts on apparatus; has four mini merging units inside – GE calls them cores.

Connect to relays in control house via premade fiber assemblies and weatherproof connectors. eat e p oo co ecto s


Images courtesy GE Multilin

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GE HardFiber components

GE prefab multiple fiber plus power cable from Brick to SCE relays in SCE facility.

Variety of standard lengths up to 500 meters.C il th bl h

GE prefab copper cable for field connections –CTs, PTs, contacts, trip circuits.

Coil the excess cable where convenient.

Brick end and indoor end shown.




Indoors:

Cross connect panel.

Fibers to/from relays.

Power from panel to remote Brick via HardFiber cable.

Flexible easy patching of Brick


patching of Brick cores to multiple GE UR relays.


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Process card replaces UR analog/binary input card.

A special purpose Ethernet switch connecting multiple brick core fiber signals to the protection processor.

NOTE: No network connection is possible to existing UR Ethernet port used for:

IEC 61850 GOOSE messages to control center.

Relay settings, events, or configuration.

Isolated by protection application processors.

Can’t hack from Brick into substation network.


Critical CIP compliance help.Image courtesy GE Multilin

GE HardFiber system configuration

Sampling is triggered by downward GOOSE messages, not 1 pps timing fibers across switchyard.

Electronic data sources are not shared across zones or between redundant systems.


Image courtesy GE Multilin

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HardFiber interoperability with other vendors?

ABB, Siemens, Alstom Grid, SEL used 9-2 LE.

9-2 LE is an implementation id li t t f 61850 t d dguideline, not part of 61850 standard.

Brick cannot work in a 9-2 LE system & vice versa.

What about multiple vendors and interoperability of 61850?


2012 - a way out of the impasse

Merging unit standards project in IEC TC 38 (Instrument Transformers) – IEC 61869-9 Merging Unit Standard.

IEC 61869-9 cites 61850-9-2 and chooses specific options – one sampling rate only (4 kHz), standard frames, etc. – even more specific than 9-2 LE.

Eliminates 1 pps fiber time synchronization - IEEE 1588 precision timing protocol (PTP) on the existing Ethernet connection to synchronize samples.

Every vendor can adapt its products to work with this standard without big hardware changes.

GE and the others said they will adapt to published standard


GE and the others said they will adapt to published standard.

Products interoperate, with flexible architectures.

Implementation agreement in drafting.

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Ngrid UK 400 kV process bus demo

Ratcliffe indoorsubstation


Switchyard maintenance solution!


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Cost effective partial solution

Extend the station bus into the switchyard for binary status and control I/O.

Put a remote binary I/O relay (SEL 451, GE UR C90+, etc.) in the switchyard for all status and control via GOOSE.

Wire only the CTs and CVTs back to the control house.

Eliminate 70-80% of switchyard wiring.

We can do it right now.


Solution for NU 61850 EHV P&C design standard.

Questions?


[email protected] or (412) 596-6959.