Multi-vendor Experiences with IEC 61850 Installation, Testing

Multi-vendor Experiences with
IEC 61850 Installation, Testing,
Configuration, Diagnostics, and
Upgrades
David Dolezilek
Schweitzer Engineering Laboratories, Inc.
Copyright © SEL 2008
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
Remedial Action Schemes
OOSESouthern California Edison (SCE)
Tested Digital Communications Speed
13.3
13
Strive to mitigate thermal overload and
instability throughout
transmission territory
RAS Round-Trip
Detect
Decide
Trip
Performance Criteria: Detect, Calculate,
React  50 ms To / From any Location
Test starts when Monitor
detects Contact Input 1
Central Processor sends
decision alarm
Monitor chooses action to take
Mitigator receives decision alarm
Monitor sends monitor alarm
Mitigator chooses action to take
Central Processor receives
monitor alarm
Mitigator closes trip output contact
Central Processor chooses
action to take
Monitor detects mitigation trip output
as Monitor Contact Input 2
RAS enabled in Central Processor?
Scope measures difference
between Contact Input 1 and 2
Yes
Initial Testing Verified Time Budget
Using Three IEDs 740 Km Apart
Next: Arming via SEL an Dell Computers
Multiple Devices Demonstrated for
WECC RAS Committee
Within One
Hour, Five
New
Devices
Were
“Digitally”
Wired
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
Jim Bridger Power Plant
Simultaneous, Independent Operation
RAS C
RAS D
DNP Gateway
DNP Gateway
IEC Logic
Controller
IEC Logic
Controller
IEC Logic
Controller
IEC Logic
Controller
IEC Logic
Controller
IEC Logic
Controller
I/O
Modules
I/O
Modules
I/O
Modules
I/O
Modules
I/O
Modules
I/O
Modules
Input
Input
Input
Input Voting
Crosspoints Voting
Output Voting
Output
Three Levels
of Voting
Jim Bridger Substation
RAS Uses Crosspoint Switch
f
Trigger
Inputs
Crosspoint Switch
Preloaded and Ready to Go
CB
Opens
Output Remediation
Contingency
Trip G1
N1
N2
X
N3
X
Trip G2
Trip G3
X
X
Trip G4
Bypass
C1
Bypass
C2
X
X
X
N4
N5
t
X
X
X
X
X
Tripping
Outputs
Designed to Handle Multiple, Closely
Timed Events
First Event
Example1
Example 2
Time (s)
t=0s
N-Events
System State
t=5s
IN1 IN6
N=1 N=20
S1
S1
IN6
N=6
S2
PacifiCorp / Idaho Power Remedial Action
Scheme Eliminates Congestion
Fastest control
system in the
world
Stability improvements increase capacity 50%, avoid blackouts
Training / Testing / Playback Simulator
Test Simulator Plugged Into RAS C
Protection-Class Features

Deterministic, high-speed, peer-to-peer
protocol 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
Florida’s International
Drive 1999 Project:
Distribution Automation
at Transmission Speeds
Switching With a Recloser…
Recloser + Control Without Communications
Manual Switching = 1 hour
Switching w/Recloser = 10 seconds
…vs. Distribution at Transmission Speed
SEL & S&C for International Drive
SEL-351S + Communications
Smart Switching = 0.1 second
Multivendor IEC 61850
CFE Parque Eolico La Venta
Existing Generators at Wind Farm
Biggest Wind Farm Project in Mexico
CFE expects to generate close to 3 GW
by 2014 in “La Ventosa”
Substation Expansion - New Generators
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
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
Proven. Reliable.
Complete.
World’s First Multisupplier
IEC 61850 System in Service
Since 2006
“This is, without any doubt, a great
advancement for the integration of control
and protection systems, and for integration
of the IEC 61850 International standard.”
David Lancha, Project Manager, IBERINCO
Wind Farm Under Construction
La Venta II Substation
Protection Requirements
87L
21PP
79
50BF
50BF
50BF
87B
51PHS
RD
87T
51PHS
51NHS
51NLS
Design #1 Used IEC 61850 Part 5, SEL Methods
in IEDs, IEC 61850 in SCADA Gateway
230KV
230KV Line
LVD93100 Autotransformer
LVD92010
230KV Tie
LVD97010
SEL-451-4
SEL-451-4
SEL-451-4
SEL-451
SEL-451
SEL-451
SEL-387E
SEL-421
SEL-311L
230KV Bus
Diff
LVDDB9
Redundant
HMI
SEL-3351
Redundant
SCADA
Gateway
SEL-3332
SEL-3332
SEL-487B
SEL-3351
Information Processor Serves DNP/Conitel as
SCADA Gateway and OPC to HMIs
CFE Requested IEC 61850 in all IEDs
SEL ACSELERATOR Architect –
SEL-2411 – Automation
Substation Configuration Language
Controller
SEL-751A – Feeders
(SCL) Engineering Software
SEL-710 – Motors
SEL-3351 Rugged Computer
SEL-421 – Distance
SEL-451-4 – Bay Control
SEL-311L – Current Differential
SEL-387E – Transformers
SEL-451 – Distribution
SEL-487B – Buses
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
Design #2 Used IEC 61850 Part 8,9 in the IEDs
IEC 61850 From SEL for Every Application in Bays
230KV
230KV Line
LVD93100 Autotransformer
LVD92010
230KV Tie
LVD97010
SEL-451-4
SEL-451-4
SEL-451-4
SEL-451
SEL-451
SEL-451
SEL-387E
SEL-421
SEL-311L
230KV Bus
Diff
LVDDB9
Redundant
HMI
SEL-3351
Redundant
SCADA
Gateway
SEL-3332
SEL-3332
SEL-487B
SEL-3351
Next CFE Chose to Demonstrate Multivendor Interoperability


System integrates devices from multiple
vendors
SEL
Siemens
GE
ZIV
RuggedCom
Team ARTECHE
Other vendors invited but did not have
IEC 61850 available or not approved by CFE
Two Different Engineering Groups
Working in Parallel to Integrate IEDs

HMI LN reporting and bay level
GOOSE 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
Gateway, and IEC 61850
SEL Scope: Panel Design for Parque Eolico
“Wind Farm” and Intertie Substation
Design #3 Used IEC 61850 Part 8,9 in the IEDs
Added IEC 61850 Devices From Other Vendors
230KV
230KV Line
LVD93100 Autotransformer
LVD92010
GE F650 BC
230KV Tie
LVD97010
230KV Bus
Diff
LVDDB9
Redundant
HMI
Redundant
SCADA
Gateway
ZIV BC
SEL-451-4
ZIV HMI
SEL-451
SEL-451
SEL-3332
SEL-451
ZIV CPT
SEL-387E
SEL-421
ZIV HMI
GE T60
GE F60
GE F35
Siemens 7SJ62
Siemens 7SJ61
SEL-311L
GE L90
SEL-487B
Panels Ready for Installation
System Architecture
Remote HMI
DNP
ZIV CPT
Conitel
ZIV HMI
ZIV HMI
Router
+ Firewall
SEL-3332
SCADA Gateway
GPS
SEL-487B 87B
SW-1
SW-5
Fiber-Optic
Ring
RuggedCom
SW-2
SW-4
SW-3
SEL-451-4 BC
GE F650 BC
ZIV 6MCV BC
SEL-451 50BF, 25, 27
SEL-451 50BF, 25, 27
SEL-421 21, 67
SEL-387E
SEL-279H 79
GE T60 87T
SEL-451 50BF, 25, 27
GE F60 50, 51HS
GE L90 87L
GE F35 50, 51TZ
SEL-311L
Siemens 7SJ62 50, 51LS
Siemens 7SJ61 50, 51N
SEL Construction, Factory Acceptance
Test (FAT), Training, Commissioning
IEC 61850 SCL Replaces Wired
Connections With Logical Connections
GOOSE Messages for Protection

CFE wanted to see performance
comparison between wired and GOOSE

CFE chose to test breaker failure
protection scheme using GOOSE

Primary protection trip

Breaker failure relay retrip

Breaker failure relay trip

Breaker failure trip reception by bus
differential relay

Trip to all breakers in bus
Customer Factory Acceptance Test
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
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
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
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
PP&L Modernized
From PLCs to IEDs


Eliminate
programmable devices

Digital transducers

PLCs
Eliminate other
components

24 Vdc supplies

Interface relays

External fault detectors
Streamline, Reduce
Complexity With
IEC 61850 Design
Reduce Hardware Components With
IEC 61850 Design
Design
Computers
Substation
PLCs & Comm.
Processor
PLC
3
5
22
24
16
4
1
75
NGS
3
1
0
24
0
2
0
30
Bay
PLCs
Relays
Metering
IEDs
Ethernet
Switches
SER
Total
Display Redundant Data Sources via HMI
L2 P disagrees with other IEDs
Faulty L2 P manually removed
Using IEC 61850 Methods for RTU
Replacement and Distributed Automation
RTU Vendor Went AWOL
No New Units, No Product Support

Over 400 pad-mounted switchgear in service

50 to 100 new each year

Three switch configurations controlling
one to six circuit taps or “ways”

Desire to simplify configuration, add
engineering access, and improve logic
Numerous I/O Configurations Must Fit
in Fixed Small Space
DNP3 serial over radio to SCADA Master
changing to DNP3 / TCP in future
RTU Real-Time Values via Internal and
External Communications Connections
RTU Replacement Network Could Also
Connect I/O of Relays and Meters
SCADA
Master
Example system database
192.168.0.20
PAC_MASTER
DNP3 Serial
Ethernet
Switch

32 AC analog inputs

2 DC analog inputs

24 digital inputs

16 digital outputs
GOOSE Messages
PAC_Slave_A
PAC_Slave_B
PAC_Slave_C
192.168.0.15
192.168.0.25
192.168.0.30
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
Stand-Alone Tool Specifically for 61850
Alternate traditional UCA2 method of
proprietary settings makes multivendor systems difficult
Configure IED via International Standard
Substation Configuration Language, SCL

Start with IED capability
description, 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
email to Add Future IED Subscriptions
“Best Practice” Provides Contextual
Names – Generic Names Less Useful
Generic
Specific
Best practice provides specific names whenever possible
Exceptions include generic logic points, unnamed contact I/O
Use Unique Name and Revision Control
Ask 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

Review receive and
transmit configuration

Quickly review network
settings

Analyze GOOSE statistics
and diagnostics

Immediately pinpoint
source of problem
Identification (ID) Reports Provide
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
of Configuration File
Failed GOOSE, Other Alarms Displayed
and Sent via Email, Voice, Text Message
Cigre
Multivendor
System
of 12
Vendor
IEDs
Support 8 Unique GOOSE Publications,
16 Subscriptions, 24 for Complex
Interlocking
SEL-451-4
SEL-421
ZIV
IRV-A
Team
Arteche
Toshiba
GRZ100
Areva
P444
Sisco software
IED on PC
GE D60
Siemens
7SA525
Siemens
6MD669
Siemens
BC1703
GE
F650
Second Generation Modernization
Began in 2006
Complete modernization
of 30 substations ranging
in voltage level from
13.8 kV to 138 kV
Elektro Network
Includes IEC 61850,
Telnet, FTP, and
SEL Protocols
Substations:
Guarujá 2 – first modernized
substation energized June 12
2007 – seven complete
2008 – eight complete
Guarujá 2
Guarujá 3
Sao Paulo State,
Brazil
Fiber Optics Replace Copper
KONYA Industrial Park
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
8 Switching Stations, 99 Feeders
SEL-3401
GPS-Clock
42-Inch LCD
Monitors
Server 1
Operator
Station 1
Operator
Station 2
Server 2
Printers
Switch
3 Tie Lines (6 Future)
Front-End 2
Substation
Computing
Front-End 1
Substation
Computing
SEL-2407
GPS-Receiver
Clock
6 x SEL-311L
Switch
Station 1
Station 2
Station 3
Station 4
Station 5
Station 6
Station 7
54 SEL-751A Relays and 38 SEL-311L Relays
Station 8
Control Center
Manages 165
Distribution
Substations

24 km redundant
fiber-optic ring

Future distribution
automation
additions
Use Modern Communications for
Diagnostics – FTP, Telnet, email
GEESE Migrate to Africa
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
Harley Street Substation
Control Center
IEC 60870-5-101
SEL-1102
SEL
SEL-2410
SEL-2410
Switch
Fdr 1
Switch
Fdr 29
SEL-1102 Gateway, 2 SEL-2410s, 36 Bays With SEL-451 Relays
Electricity of Vietnam (EVN)




State-owned utility established 1995
Generation, transmission, and distribution
for whole country
4 transmission
companies
79,800 km of
distribution lines
Growing Electricity Demand
Forecasted growth 17% per annum until 2025
600
500
Terawatt-Hours
400
300
200
Production
100
Sales
0
1995
2000
2005
2010
2015
2020
2025
First Phase – Substation Modernization
Began in 1999

First computerized 220 kV substation
commissioned in Ho Chi Minh City

This success resulted in digitizing more
substations through 2003
Early Substation Modernization

Conventional protection and control using
DNP3 serial and hardwired connections

Problems with incompatibilities between
multiple manufacturers’ IEDs
Second Phase – Standardization


To improve IED compatibility, EVN issued
specification for substation automation based
on UCA2
Based on this, first large-scale substation
automation system (SAS) was implemented
220 kV Thu Duc Substation
Upgraded
Protection
System
Architecture
220 kV
66 kV Busbar
Phase 1
Phase 3
Phase 2
220 kV
110 kV
Phase 1
Phase 3
Phase 2
Third Phase – IEC 61850

IEC 61850 Part 10 approved Oct. 2005

EVN standardized for future projects –
new and retrofit

All 500 kV
backbone
substations
upgraded by
2010
New System Requirements

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
Host 1
Engineering
(Bridge to SCADA)
Host 2
HIS Server
Router to WAN
Fiber-Optic
Ethernet
100 Mbps
LAN 1
LAN 2
Main
NIM
Backup
NIM
Main
IED
Backup
IED
GPS Clock
Bay Cubicle
Main
IED
Backup
IED
Main
IED
Backup
IED
Bay
Devices
Option 2
Bay Cubicle
Bay Cubicle
Bay
Devices
Bay
Devices
Option 1
Computerized Control and Monitoring
Redundant system
servers running on
Windows® 2000 or Linux®
Local HMI,
engineering console,
and historian
Old Protection Panels Replaced
Microprocessor-based relays perform
protection, control, and monitoring
Outdoor Cubicles Reduce Cabling
Existing Copper Cabling
Binh Long Substation
Copper
Cabling
Reduced
@STATION System Overview
HMI1
HMI2
ENG
HIS
GW
LAN / WAN
IEC 61850
Meter
Relays / BCUs
Hardware
Connections
Primary Equipment
Legacy Device Gateway
Rugged Computing Platform
SCADA Gateway
Test Results
User Interface Feature
Required by
EVN
Tested
Display Response Time
<1s
<1s
Data Entry Response Time
<1s
<1s
Display Update Rate
<2s
<2s
Update Completion Rate
<1s
<1s
Test Results
User Interface Feature
Alarm/Event
Response Time
Alarm Acknowledge/
Delete Time
Report and Logbook
Response Time
Display Color Printout
Response Time
Required by
EVN
Tested
<1s
<1s
<2s
<2s
< 0.5 min
< 0.5 min
< 0.5 min
< 0.5 min
Test Results
Required by
EVN
Tested
<2s
<1s
–
<2s
–
<1s
Failover Time Between
Main 1 and Main 2
–
0s
GOOSE Exchange Time
< 10 ms
< 8 ms
User Interface Feature
Console Inhibit Time for
Display Hardcopy
Analog Data
Collection Rate
Status Indication
Collection Rate
Benefits of IEC 61850 SAS


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?
Time Waveform
and Phasor Representation
v(t)
A
0

Reference
wt
A
2

Absolute Time Synchronization Has
Fundamentally Changed the World
Satellite
GPS RCVR
GPS RCVR
IRIG-B
PMU 1
A
IRIG-B
Mag/Ang
Mag/Ang
PMU 2
B
Direct State Measurement
SYNCHROPHASORS

GPS provides common time reference

Measure state vector

Measure currents, too

Synchronously!

Every second

Every cycle
Synchrophasors Provide a “Snapshot”
of the Power System
P= |V1| |V2|sinФ / X
V1∠0
Ф= sin-1(PX / |V1| |V2|)
P→
V2 ∠Ф
Increase Stable
Power Transfer
Relays Are Right for Synchrophasors

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
64 Minutes
Utilities Are Operating Closer to the Edge
Margin
Margin
1.0
Operating
Point
Bifurcation
Point
0.5
0.0
PU Nominal Load
1.0
1.3
1.5
1.7
Long Island: Monitor Angles Between
Transmission Distribution Buses to
Detect & Prevent Voltage Collapse
Vr 
V S 0
ZL = R
+ jX
S=P+
jQ
Smax 
1  sin(θ) Vs
2 cos( θ)2 X
2
Apply Remote Synchronizing
230 kV
Bus
SEL-421
115 kV
Bus
13.8 kV
Bus
SEL-421
Improved View:
Synchroscope
and Freq Plot
make it easier
for operators
“The MRI of Power Systems”
NERC press release on
Florida outage Feb. 26,
2008:
Synchrophasors are “Like
the MRI of bulk power
systems”
SCE Uses C37.118 From
Relays and PMU
SCADA
Master
DNP3
Information
Processor
IEEE C37.118
Harris 5000/6000,
IEC 60870-103,
Modbus, SEL Fast
Message, Telegyr
8979, Conitel 2020,
CoDeSys, OPC, …
Distributed Generation Creates
Islanding Problems
Transmission
Network
SEL-3378
DG
Synchrophasors Detect and Correct
Islanding Problems
Defensive Strategies Working Group
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!
Europe / Asia
4,115 units
Canada
North America
142,085 units
Asia
Pacific
45,793 units
South America
15,903 units
Africa / Middle East
5,085 units
Real-World Example – Line Repair
Error Detection
Synchrophasors Make
CFE’s Grid Smarter
Relay-to-Relay
Synchrophasors for
Generator Shedding
Load Shedding Based on Angle
400 kV
Synchrophasors
400 kV
Trip
Generator
900 MW
National
System
Chicoasen
Sabino
Angostura
Tapachula
City
400 kV
115 kV Network
Southern Region Load
Detect and Control Adaptive Islanding
Transmission
Network
SEL-451
Relay / PMU
SEL-3378 SVP
Distribution
Network
Unintentional
Islanding
SEL-451
Relay / PMU
Over Angle Protection Holds System
Together
Link 1
Area 1
Heavy
Load
Link 2
SEL-421 Synchrophasors
Area
2
SEL-421
Trip
Generation
Area 3
Light
Load
(Chicoasen – Angostura) > 5°  Trip Generation
Today: Most Processing Is at the Master
Master

Finds topology

Purges bad data

Estimates state
Asynchronous
Scan
RTU
RTU
~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
Bus Voltage
Instantaneous
Phase Angles
Line
MVA
Frequency
PMU ID
Trended
Phase Angles
Local Calculation of Line Temperature
Improves Power Transfer Reliability
+
+
Line Temperature = f (Ambient Temp, Current, Line Orientation, Season)
IEEE Synchrophasors Compatible
With IEC 61850 Networks
Possible 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
V2
V1
V3
V4
I231
I12
I34
I232
 I12     V1 
I     V 
 231    Y   2  State Vector
I232     V3 
 I    V 
 34     4 
Traditional RAS Clearing Time Budget
Relay
Relay
Detects
Fault
-1 Cycle
I/O Module
Computer
Relay Trips/
Asserts Contact
Output
0 Cycle
I/O Module
RAS Controller
Issues Gen
Breaker Trip
1 Cycle
Relay
Relay Receives
Trip Command
and Trips Gen
Breaker
2 Cycles
Breaker
Breaker Trip
Time
3 Cycles
Total RAS Clearing Time
6 Cycles
SVP RAS Clearing Time ¾ Cycle Faster
Improving RAS with Synchrophasors

Direct state measurement is now practical
because of the widespread availability of
Synchrophasors

The SVP performs local direct state
measurement 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?

Detect potential unstable operating conditions

Control islanding

Detect system oscillation before criticality

Minimize problems automatically
Synchrophasors Empower the Future