part 01 multivendor case study installations
TRANSCRIPT
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Copyright © SEL 2008
Multi-vendor Experiences withIEC 61850 Installation, Testing,
Configuration, Diagnostics, and
Upgrades
David Dolezilek
Schweitzer Engineering Laboratories, Inc.
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Practical Uses of IEC 61850 Protocols
and Synchrophasors
GOOSE in a Centralized Remedial Action
Scheme (CRAS)
GOOSE versus hard-wire protective trip RTU I/O collection via GOOSE
Diagnostics tools for GOOSE “virtual wiring”
Recent Global IEC 61850 installations
Improving RAS with synchrophasors
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Remedial Action Schemes
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Southern California Edison (SCE)
Tested Digital Communications Speed
Strive to mitigate thermal overload andinstability throughout
transmission territory
Detect Decide Trip
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Performance Criteria: Detect, Calculate,
React 50 ms To / From any Location
Test starts when Monitor
detects Contact Input 1
Monitor chooses action to take
Monitor sends monitor alarm
Central Processor receives
monitor alarm
RAS enabled in Central Processor?
Central Processor chooses
action to take
Central Processor sends
decision alarm
Mitigator receives decision alarm
Mitigator chooses action to take
Mitigator closes trip output contact
Monitor detects mitigation trip output
as Monitor Contact Input 2
Scope measures difference
between Contact Input 1 and 2Yes
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Initial Testing Verified Time Budget
Using Three IEDs 740 Km Apart
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Multiple Devices Demonstrated for
WECC RAS Committee
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Within One
Hour, Five
NewDevices
Were
“Digitally”Wired
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Typical: GOOSE Trip Tansit 1.50 msec
Central Processing Time 2.083 msec
Monitor is 60 miles distant. Mitigators are local to CP.
Mitigation GOOSE transit, subscription, output - 3 msec or 11 msec
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Jim Bridger Power Plant
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Simultaneous, Independent Operation
DNP Gateway
IEC Logic
Controller
I/O
Modules
IEC Logic
Controller
IEC Logic
Controller
I/O
Modules
I/O
Modules
DNP Gateway
IEC Logic
Controller
I/O
Modules
IEC Logic
Controller
IEC Logic
Controller
I/O
Modules
I/O
Modules
RAS DRAS C
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Three Levels
of Voting
Crosspoints Voting
InputInput Input
Input Voting
Output Voting
Output
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RAS Uses Crosspoint Switch
Crosspoint Switch
f
t
CBOpens
Tripping
Outputs
Trigger
Inputs
X
Trip G2
N5
N4
XN3
XN2
N1
Trip G1
Output RemediationContingency
Trip G3
X
Trip G4
X
Bypass
C1
X
Bypass
C2
X
X
X XX
X
Preloaded and Ready to Go
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Designed to Handle Multiple, Closely
Timed Events
N-Events
IN1
N=1S1
IN6
N=20S1
IN6
N=6S2
First Event
Example1 Example2
Time (s)
System State
t=5st=0s
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PacifiCorp / Idaho Power Remedial Action
Scheme Eliminates Congestion
Stability improvements increase capacity 50%, avoid blackouts
Fastest contro l
system in the
wor ld
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Training / Testing / Playback Simulator
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Test Simulator Plugged Into RAS C
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Protection-Class Features
Deterministic, high-speed, peer-to-peerprotocol used between RAS controllers
No backplanes to fail
No auxiliary power supplies
MS Windows® NOT used in RAS controller
All controllers embedded Identical logic in all six controllers
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Florida’s International
Drive 1999 Project:Distribution Automation
at Transmission Speeds
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Switching With a Recloser…
Manual Switching = 1 hour
Switching w/Recloser = 10 seconds
Recloser + Control Without Communications
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…vs. Distribution at Transmission SpeedSEL & S&C for International Drive
SEL-351S + Communications
Smart Switching = 0.1 second
M l i d IEC 618 0
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Multivendor IEC 61850
CFE Parque Eolico La Venta
E i ti G t t Wi d F
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Existing Generators at Wind Farm
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Biggest Wind Farm Project in Mexico
CFE expects to generate close to 3 GW
by 2014 in “La Ventosa”
S b t ti E i N G t
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Substation Expansion - New Generators
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SEL - MX060018 Project Satisfies
Newest SICLE Design With IEC-61850
SICLE is Spanish Acronym for
“Integrated System For Substation Local
Control” CFE Specifies SICLE for integration of high
voltage substations, SISCOPROMM for low
voltage
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CFE Decided to Build Small but
Meaningful Substation
CFE wanted to prove 61850 was real
Include as many vendors as possible
Add other redundant IEDs in parallel Demonstrate true functionality on the
network
Prove multi-vendor interoperability
P R li bl
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“This is, without any doubt, a great
advancement for the integrat ion of co ntro l
and protect ion sy stems, and for integrat ion
of the IEC 61850 International standard.”
David Lancha, Project Manager, IBERINCO
Proven. Reliable.
Complete.
World’s First Multisupplier
IEC 61850 System in Service
Since 2006
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Wind Farm Under Construction
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50BF
50BF
51PHS
87T
51PHS
51NHS
51NLS
87B
RD
50BF
79
21PP
87L
La Venta II Substation
Protection Requirements
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Design #1 Used IEC 61850 Part 5, SEL Methods
in IEDs, IEC 61850 in SCADA Gateway
SEL-451-4
SEL-451
SEL-451-4
SEL-451
SEL-387E
SEL-451-4
SEL-451
SEL-311L
SEL-421
SEL-487B
SEL-3351
SEL-3351
SEL-3332
SEL-3332
230KV Line
LVD93100
230KV
Autotransformer
LVD92010
230KV Tie
LVD97010
230KV Bus
Diff
LVDDB9
Redundant
HMI
Redundant
SCADA
Gateway
Information Processor Serves DNP/Conitel as
SCADA Gateway and OPC to HMIs
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CFE Requested IEC 61850 in all IEDs
SEL-421 – Distance
SEL-311L – Current Differential
SEL-451 – Distribution
SEL-387E – Transformers
SEL-487B – Buses
SEL-451-4 – Bay Control
SEL-3351 Rugged Computer
SEL ACSELERATOR Architect –
Substation Configuration Language
(SCL) Engineering SoftwareSEL-710 – Motors
SEL-2411 – Automation
Controller SEL-751A – Feeders
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Meet CFE Substation Protection
Requirements Using IEC 61850
Conventional wiring and IEC 61850 GOOSE
Test performance of conventional wiring vs.
GOOSE for protection functions
Determine if all relays will interoperate and
perform as desired
IEDs approved by CFE
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Design #2 Used IEC 61850 Part 8,9 in the IEDsIEC 61850 From SEL for Every Application in Bays
SEL-451-4
SEL-451
SEL-451-4
SEL-451
SEL-387E
SEL-451-4
SEL-451
SEL-311L
SEL-421
SEL-487B
SEL-3351
SEL-3351
SEL-3332
SEL-3332
230KV Line
LVD93100
230KV
Autotransformer
LVD92010
230KV Tie
LVD97010
230KV Bus
Diff
LVDDB9
Redundant
HMI
Redundant
SCADA
Gateway
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Next CFE Chose to Demonstrate Multi-
vendor Interoperability
System integrates devices from multiple
vendors
SEL SiemensGE ZIV
RuggedCom Team ARTECHE
Other vendors invited but did not haveIEC 61850 available or not approved by CFE
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Two Different Engineering Groups
Working in Parallel to Integrate IEDs
HMI LN reporting and bay levelGOOSE IEC 61850 integration
being done by Iberdrola
SCADA Gateway LN reporting and
station level GOOSE IEC 61850
integration being done by SEL
New Products for CFE : Bay Control SCADA
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New Products for CFE : Bay Control, SCADA
Gateway, and IEC 61850
SEL Scope: Panel Design for Parque Eolico
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SEL Scope: Panel Design for Parque Eolico
“Wind Farm” and Intertie Substation
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P l R d f I t ll ti
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Panels Ready for Installation
S t A hit t
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System Architecture
Router + Firewall
Remote HMI
RuggedCom
Fiber-Optic
Ring
DNP
Conitel
SW-4
SW-5
SW-3
SW-1
SW-2
GE F650 BC
SEL-451 50BF, 25, 27
SEL-387E
GE T60 87T
GE F60 50, 51HS
GE F35 50, 51TZ
Siemens 7SJ62 50, 51LS
Siemens 7SJ61 50, 51N
SEL-451-4 BC
SEL-451 50BF, 25, 27
ZIV 6MCV BC
SEL-421 21, 67
SEL-279H 79
SEL-451 50BF, 25, 27
GE L90 87L
SEL-311L
SEL-487B 87BGPS
ZIV CPT ZIV HMI ZIV HMI
SEL-3332
SCADA Gateway
SEL Construction Factory Acceptance
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SEL Construction, Factory Acceptance
Test (FAT), Training, Commissioning
IEC 61850 SCL Replaces Wired
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IEC 61850 SCL Replaces Wired
Connections With Logical Connections
GOOSE M f P t ti
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GOOSE Messages for Protection
CFE wanted to see performance
comparison between wired and GOOSE
CFE chose to test breaker failureprotection scheme using GOOSE
Primary protection trip
Breaker failure relay retrip
Breaker failure relay trip
Breaker failure trip reception by busdifferential relay
Trip to all breakers in bus
C t F t A t T t
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Customer Factory Acceptance Test
GOOSE Retrip Operation 12 5ms Faster
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GOOSE Retrip Operation 12.5ms Faster
Than Parallel Hardwire at La Venta
GOOSE Breaker 21 TRIP A
Wired Contact Breaker 21 TRIP A
12.5 ms Difference
Between Inputs
86FI Operation: GOOSE 8 ms Faster
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86FI Operation: GOOSE 8 ms Faster
CFE Project Res lts
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CFE Project Results
Retrip test; GOOSE three-fourths cycle faster Breaker failure scheme; GOOSE half-cycle
faster – wiring scheme still has to go through
physical lockout (86) relay, which adds 6 to 8 ms
Configuration and troubleshooting made simpler
with sequential events recorder (SER) and
event reports
Traffic did not affect performance of SEL
devices
P j t E i i R l d
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Project Engineering Revealed
Necessary Communication Parameters
Time synch method - chose SNTP
Sacraficed accuracy to use Ethernet
Changed back to IRIG later Number of client associations – chose 6
Two redundant HMIs
Remote and local engineering workstations
Two redundant SCADA gateways
I t l k d A t ti P j t
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Interlock and Automation Projects
Dictated GOOSE Requirements
Number of outgoing GOOSE messages -
eight
Number of incoming GOOSE messages - 16 Number of incoming GOOSE bits
Bay control – 128
Relay –16, 128 depending on application
Parque Eolico La Venta II
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Parque Eolico La Venta II
PP&L Modernized
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PP&L Modernized
From PLCs to IEDs
Eliminateprogrammable devices
Digital transducers
PLCs
Eliminate othercomponents
24 Vdc supplies
Interface relays
External fault detectors
Streamline Reduce
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Streamline, Reduce
Complexity With
IEC 61850 Design
Reduce Hardware Components With
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Reduce Hardware Components With
IEC 61850 Design
Design ComputersSubstation
PLCs & Comm.
Processor
Bay
PLCsRelays
Metering
IEDs
Ethernet
SwitchesSER Total
PLC 3 5 22 24 16 4 1 75
NGS 3 1 0 24 0 2 0 30
Display Redundant Data Sources via HMI
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Display Redundant Data Sources via HMI
L2 P disagrees with other IEDs Faulty L2 P manually removed
Using IEC 61850 Methods for RTU
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g
Replacement and Distributed Automation
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Numerous I/O Configurations Must Fit
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Numerous I/O Configurations Must Fit
in Fixed Small Space
DNP3 serial over radio to SCADA Masterchanging to DNP3 / TCP in future
RTU Real-Time Values via Internal and
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RTU Real-Time Values via Internal and
External Communications Connections
RTU Replacement Network Could Also
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RTU Replacement Network Could Also
Connect I/O of Relays and Meters
Example system database
32 AC analog inputs
2 DC analog inputs
24 digital inputs 16 digital outputs
192.168.0.15 192.168.0.25 192.168.0.30
192.168.0.20SCADAMaster
DNP3 Serial
Ethernet
SwitchGOOSE Messages
PAC_MASTER
PAC_Slave_A PAC_Slave_B PAC_Slave_C
Data Flow Acts the Same as Distributed
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Data Flow Acts the Same as Distributed
RTU I/O Panels But Performs Better
SCADA Master
Field Inputs
GOOSE Inputs
DNP3 Response
DNP3 Command
Contact Output
GOOSE Outputs
Multi-vendor Configuration Requires
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g q
Stand-Alone Tool Specifically for 61850
Alternate traditional UCA2 method of
proprietary settings makes multi-
vendor systems difficult
Configure IED via International Standard
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Configure IED via International Standard
Substation Configuration Language, SCL
Start with IED capabilitydescription, ICD file
Create configured IED
description, CID file Edit only what you
choose
No accidental changes
Minimize verification
testing
Load File in IED, or Send to Colleague Via
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g
email to Add Future IED Subscriptions
“Best Practice” Provides Contextual
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Names – Generic Names Less Useful
Best practice provides specific names whenever possible
Exceptions include generic logic points, unnamed contact I/O
Generic Specific
Use Unique Name and Revision Control
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Use Unique Name and Revision ControlAsk IED Directly to Verify Present Configuration
Solicit identification report from IED
IED name reveals file name and revision ConfigVersion reveals default SCL file that
configuration was developed with
IED GOOSE Reports Are Essential
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IED GOOSE Reports Are Essential
Review receive and
transmit configuration
Quickly review network
settings
Analyze GOOSE statistics
and diagnostics Immediately pinpoint
source of problem
Identification (ID) Reports Provide
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( ) p
Source / Destination of “Virtual Wiring”Mismatched Configuration Explains Failure
ID shows incorrect revision of PAC configuration
Once corrected, GOOSE report shows correct
revision as part of GOOSE reference name
Analyze Contents With Knowledge
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Analyze Contents With Knowledge
of Configuration File
Failed GOOSE, Other Alarms Displayed
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Failed GOOSE, Other Alarms Displayed
and Sent via Email, Voice, Text Message
Cigre
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Multi-
vendor
System
of 12
Vendor
IEDs
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Second Generation Modernization
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Second Generation Modernization
Began in 2006
Complete modernizationof 30 substations ranging
in voltage level from
13.8 kV to 138 kV
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Elektro Network
Includes IEC 61850,
Telnet, FTP, and
SEL Protocols
Substations:
Guarujá 2 – first modernizedsubstation energized June 12
2007 – seven complete
2008 – eight complete Sao Paulo State,
Brazil
Guarujá 2
Guarujá 3
Fiber Optics Replace Copper
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p p pp
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KONYA Industrial Park
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Chooses SEL and IEC 61850
500 large to mid-size electricity-dependent
tenants: plastics, machinery, pharmaceuticals
Park management responsible for infrastructure:
electricity, gas, water, traffic, security
One 100 MW transformer and three 33 kV
tie lines from National Grid
65 MW maximum demand increasing by 15%
every year
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Control Center
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Manages 165
DistributionSubstations
24 km redundant
fiber-optic ring Future distribution
automationadditions
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GEESE Migrate to Africa
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g
Stations Include IEC 61850 MMS and GOOSE
City Power Pennyville – 19 bays , 2 bus
sections, 3 transformers
City Power Khanyisa – similar to above with
36 bays
City of Cape Town – 2 complete substations
Nelson Mandela Bay Municipality Three new substations in 2008
Each based on IEC 61850
City Power Johannesburg
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y g
Harley Street Substation
Control Center IEC 60870-5-101
Fdr 29Fdr 1
SEL
SEL-1102
SEL-2410SEL-2410
Switch Switch
Electricity of Vietnam (EVN)
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y ( )
State-owned utility established 1995
Generation, transmission, and distributionfor whole country
4 transmission
companies 79,800 km of
distribution lines
Growing Electricity Demand
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g y
Forecasted growth 17% per annum until 2025
0
100
200
300
400
500
600
1995 2000 2005 2010 2015 2020 2025
Production
Sales
T
e r a w a t t - H o u r s
First Phase – Substation Modernization
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Began in 1999
First computerized 220 kV substation
commissioned in Ho Chi Minh City
This success resulted in digitizing moresubstations through 2003
Early Substation Modernization
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Conventional protection and control using
DNP3 serial and hardwired connections
Problems with incompatibilities between
multiple manufacturers’ IEDs
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220 kV Thu Duc Substation
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Third Phase – IEC 61850
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IEC 61850 Part 10 approved Oct. 2005
EVN standardized for future projects –
new and retrofit
All 500 kVbackbone
substations
upgraded by
2010
New System Requirements
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Dual redundant fiber-optic LAN with no
single point of failure
IEC 61850 for all substation communication
IEC 60870-5-101 for SCADA
Standard System Hardware Architecture
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Host 1 Host 2Engineering
(Bridge to SCADA)HIS Server Router to WAN
Backup
IED
Backup
IED
Main
IED
Main
IED
Bay
Devices
Bay
Devices
Main
NIM
Backup
NIM
Bay CubicleBay Cubicle
Bay Cubicle
Option 2
Option 1
LAN 1
LAN 2
GPS Clock
Backup
IED
Main
IED
Bay
Devices
Fiber-Optic
Ethernet
100 Mbps
Computerized Control and Monitoring
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Local HMI,
engineering console,
and historian
Redundant system
servers running on
Windows® 2000 or Linux®
Old Protection Panels Replaced
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Microprocessor-based relays perform
protection, control, and monitoring
Outdoor Cubicles Reduce Cabling
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Existing Copper Cabling
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Binh Long Substation
Copper
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Cabling
Reduced
@STATION System Overview
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HMI1 HMI2ENG
HISGW
LAN / WAN
Primary Equipment
Meter
Hardware
Connections
Relays / BCUs
IEC 61850
Legacy Device GatewayR d C i Pl f
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Rugged Computing Platform
SCADA Gateway
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Test Results
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User Interface FeatureRequired by
EVNTested
Display Response Time < 1 s < 1 s
Data Entry Response Time < 1 s < 1 s
Display Update Rate < 2 s < 2 s
Update Completion Rate < 1 s < 1 s
Test Results
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User Interface FeatureRequired by
EVNTested
Alarm/Event
Response Time< 1 s < 1 s
Alarm Acknowledge/
Delete Time < 2 s < 2 s
Report and Logbook
Response Time< 0.5 min < 0.5 min
Display Color Printout
Response Time < 0.5 min < 0.5 min
Test Results
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User Interface FeatureRequired by
EVNTested
Console Inhibit Time for
Display Hardcopy< 2 s < 1 s
Analog Data
Collection Rate – < 2 s
Status Indication
Collection Rate – < 1 s
Failover Time Between
Main 1 and Main 2 – 0 s
GOOSE Exchange Time < 10 ms < 8 ms
Benefits of IEC 61850 SAS
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Faster system integration with IED
interoperability Reduction of copper cabling and
hardwiring
GOOSE for peer-to-peer data exchange Outdoor cubicles adjacent to feeder or bay
System malfunctions reduced by nearly
50%
What is a Synchrophasor?
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Time Waveform
d Ph R t ti
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v(t)
0
A
t2
A
Reference
and Phasor Representation
Absolute Time Synchronization Has
F d t ll Ch d th W ld
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Fundamentally Changed the World
GPS RCVR
PMU 1
A B
Satellite
GPS RCVR
PMU 2
IRIG-B IRIG-B
Mag/Ang Mag/Ang
Direct State Measurement
SYNCHROPHASORS
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SYNCHROPHASORS
GPS provides common time reference
Measure state vector
Measure currents, too Synchronously!
Every second
Every cycle
Synchrophasors Provide a “Snapshot”
f th P S t
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of the Power System
P= |V1| |V2|sinФ / X Ф= sin-1(PX / |V1| |V2|)
V1∠0 V2∠ФP→
Increase Stable
Power Transfer
Relays Are Right for Synchrophasors
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Phasor measurement and control unit
(PMCU) ≥ PMU
Minimal incremental cost
Reduced current and voltage connections High-accuracy measurements
High reliability and availability
Future control applications
Relays are everywhere
What Operators Did Not See Aug. 14th
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64 Minutes
Utilities Are Operating Closer to the Edge
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MarginMargin
1.0 1.3 1.5 1.7PU Nominal Load
1.0
0.5
0.0
Operating
Point
Bifurcation
Point
Long Island: Monitor Angles BetweenTransmission Distribution Buses to
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Transmission Distribution Buses to
Detect & Prevent Voltage Collapse
X)θcos(2
V)θsin(1S
2
2
smax
Z L = R + j X V S 0
V r
S = P + j Q
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Impro ved View:
Synchroscopeand Freq Plot
make it easier
for operators
“The MRI of Power Systems”
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NERC press release onFlorida outage Feb. 26,
2008:
Synchrophasors are “Likethe MRI of bulk power
systems”
SCE Uses C37.118 FromRelays and PMU
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y
SCADA
Master
DNP3
IEEE C37.118
InformationProcessor
Harris 5000/6000,
IEC 60870-103,
Modbus, SEL Fast
Message, Telegyr8979, Conitel 2020,
CoDeSys, OPC, …
Distributed Generation CreatesIslanding Problems
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Islanding Problems
TransmissionNetwork
DG
SEL-3378
Synchrophasors Detect and Correct
Islanding Problems
Defensive Strategies Working Group
New York State Reliability Council
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New York State Reliability Council
NYSRC asked SEL to propose solutions
Mitigate impact of major disturbances on the
New York electric system
Blackout mitigation and prevention
Separate into “islands” using transmission
system fault protection relays
SEL Synchrophasor Total
Potential Worldwide!
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Canada
Potential Worldwide!
North America
142,085 units
South America
15,903 units
Europe / Asia
4,115 units
Africa / Middle East
5,085 units
Asia
Pacific
45,793 units
Real-World Example – Line Repair
Error Detection
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Error Detection
Synchrophasors Make
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Relay-to-RelaySynchrophasors for
Generator Shedding
y p
CFE’s Grid Smarter
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Detect and Control Adaptive Islanding
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TransmissionNetwork
SEL-451
Relay / PMU
SEL-3378 SVP
Unintentional
Islanding
Distribution
Network
SEL-451
Relay / PMU
Over Angle Protection Holds System
Together
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Together
Area 1
Heavy
Load
Area2
Link 1
Link 2
Area 3
Light
LoadTrip
Generation
SEL-421 SEL-421Synchrophasors
(Chicoasen – Angostura) > 5° Trip Generation
Today: Most Processing Is at the Master
Fi d t l
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Finds topology
Purges bad data
Estimates stateMaster
RTU RTU
Asynchronous
Scan
~5 seconds per scan
. . . can have partial
information from
two or more
physical systems –
due to faults, switching,
swinging, tap changes.
One Utility’s View of Several Data
Streams
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StreamsBus Voltage
Line
MVA
Frequency
Instantaneous
Phase Angles
Trended
Phase Angles
PMU ID
Local Calculation of Line Temperature
Improves Power Transfer Reliability
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Improves Power Transfer Reliability
+ +
Line Temperature = f (Ambient Temp, Current, Line Orientation, Season)
IEEE Synchrophasors Compatible
With IEC 61850 Networks
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With IEC 61850 NetworksPossible Future GOOSE or 9-2 Extension
IEEE C37.118,
Telnet, tunneled
serial
Verify CT wiring,phase rotation,
settings
Determining the State of a Power System
VV
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4
3
2
1
34
232
231
12
V
VV
V
I
II
I
Y
I12 I34
I231
I232
V1 V4V3V2
State Vector
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SVP RAS Clearing Time ¾ Cycle Faster
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Improving RAS with Synchrophasors
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Direct state measurement is now practicalbecause of the widespread availability of
Synchrophasors
The SVP performs local direct statemeasurement and control
Wide area RAS schemes are improved
because synchrophasors reduce the amount
of information communicated to the master
station
What Does a Future “Worst-Case
Scenario” Look Like?
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Scenario Look Like?
Detect potential unstable operating conditions Control islanding
Detect system oscillation before criticality
Minimize problems automatically
Synchrophasors Empower the Future
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