Post on 06-Apr-2018
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Substation Automationand Smart Grid
GEEnergy
John D. McDonald, P.E.
POWERING POTENTIA L
The Smart Grid
GM, T&D Marketing
IEEE PES Past PresidentIEEE Division VII DirectorIEEE Fellow
Current Situation
Current IED Penetration
10%
20%
30%
40%
50%
60%
2/GE /
A little more than half of existingT&D substations are equipped withIEDs
0%
No IEDs IEDs
Source: The World Market for Substation Automation and Integration Programs
in Electric Utilities: 2005-2007; Newton-Evans Research Company, Inc.
Current Situation (continued)
IED Level of Integration
10%
20%
30%
40%
50%
60%
3/GE /
55% of IED substations have no integration(29% of total subs)
45% of IED substations have some integration(24% of total)
0%
IEDs - No integration IEDs with some level of integration and
automation
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Plans for Retrofit Substations
Retroft Substations
10%
20%
30%
40%
50%
60%
4/GE /
97% of retrofit T&D substations will haveIEDs
42% of retrofit T&D substations includeIED integration and automation
0%
No IEDs IEDs - No Integration IEDs with some level of
integration
Plans for New Substations
Plans for New Substations
10%
20%
30%
40%
50%
60%
70%
80%
90%
5/GE /
97% of T&D substations will have IEDs 85% of T&D substations will include IED
integration and automation
0%
No IEDs IEDs - No Integrat ion IEDs with some level of
integration
Why Needed? Why Now?
DEREGULATION & COMPETITIONDeregulation driving actions of
most utilitiesMajor driving forces:
Improved power quality and
service reliability
6/GE /
New energy related servicesand business areas
Lower cost of service Information needed for
improved decision makingSA: A proactive response to these
forces
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Why Needed? Why Now?
DEVELOPMENT OF IEDsRapid development and deployment of
Intelligent Electronic Devices (IEDs)
Protective relays Meters Equipment condition monitors
IEDs have become an integral part of
7/GE /
Substation Automation systemsTechnological developments have made SA
Systems less expensive and more powerful
RTU
Direct-
Wired
I/O
Data
Concentrator
IED IED IED
LAN
Why Needed? Why Now?
ENTERPRISE-WIDE INTEREST ININFORMATION FROM IEDsOperational Data
Amps, volts, watts, VARs, fault location,switchgear status
Non-Operational Data E ui ment condition
8/GE /
Fault event and power quality data
(waveforms)Persons working outside the control room
want access for improved decision making
SA Platform
EMS/DMS
Corporate
Data Warehouse
Why Needed? Why Now?
IMPLEMENTATION AND ACCEPTANCE OFSTANDARDSConfusion over industry communication
standards is diminishingInternational standards have become reality
9/GE /
Standards based implementation projectsunderway at many electric utilities Widespread use ofde facto standards for IED
communications (DNP3, Modbus. Modbus+) Some use ofde jure standards
(UCA2/IEC61850)
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eve ene s
Construction Cost Savings
Electromechanical Devices IEDs
Required functionality bundled in fewercomponents (21, 50/51, 79,, metering,etc)
One IED may replace many E-Mdevices
11/GE /
WM+
AM A VM
VarM+
PF+
+ + +
WH
+
VarH
+
50/51N+
50/51A+
50/51B+
50/51C+
AS+
VS+
52CS
G R
TS+
+
46
WM+
AM
VarM+
PF+
+
WH
+
VarH
+
50/51N+
50/51A+
50/51B+
50/51C+
AS+
52CS
G R
TS+
+
79
WM+
AM
VarM+
PF+
+
WH
+
VarH
+
50/51N+
50/51A+
50/51B+
50/51C+
AS+
52CS
G R
TS+
+
79
AM+
50/51A+
50/51B+
50/51C+
AS+
86+
52CS
G R
TS+
+
50/51G+
++
87TA
+
46
W
87TB
87TC
Transformer T1 Main Bkr M1 Feeder Bkr F1 Feeder Bkr F2
+
TS+
+
TPU
+
+
DPU
+
DPU
F1
+
DPU
F2
+ + +
+ +
Construction Cost Savings
Reduction in Physical Complexity Less inter-device wiring Fewer unique devices to inventory Some traditional devices eliminated
altogether
12/GE /
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Construction Cost Savings
Relay/control house size (newconstruction only)
Design & construction labor andmaterials
13/GE /
Integrated Protection Functions
Objective: Incorporate protectionfunctions in the SA SystemBasic protection units (IEDs)
exchange current/voltage data via
hi h s eed LAN
15/GE /
Relay trip signals exchanged over
LAN
Bus
Diff
RelayHardwired Hardwired
AC AC
DC DC
Traditional
(Electromechanical)
Approach
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Integrated Protection Functions
Objective: Incorporate protectionfunctions in the SA System
Basic protection units (IEDs)exchange current/voltage data viahi h s eed LAN
16/GE /
Relay trip signals exchanged over
LAN
Relay
IED
AC
DC DC
Integrated IED
Approach
Relay
IED
Local Area
Network
Current/Voltage meas;
Status/Trip signals
115kVSource
Integrated Protection Breaker Failure
17/GE /
69kV Bus
Source atRemote End
115kV
Source
Integrated Protection Breaker Failure
18/GE /
69kV Bus
Source at
Remote End
Fault
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115kVSource
Integrated Protection Breaker Failure
19/GE /
69kV Bus
Source atRemote End
ProtRelayIED
OC
115kVSource
Integrated Protection Breaker Failure
20/GE /
69kV Bus
Source atRemote End
Prot
RelayIED
OC
115kVSource
Integrated Protection Breaker Failure
21/GE /
69kV Bus
Source atRemote End
ProtRelayIED
OC
BreakerFailure
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115kVSource
Integrated Protection Breaker Failure
22/GE /
69kV Bus
Source atRemote End
ProtRelayIED
OC
Breaker
Failure
BF
Hardwired
Hardwired
115kVSource
Integrated Protection Breaker Failure
23/GE /
69kV Bus
Source atRemote End
Prot
RelayIED
OC
Breaker
Failure
BF
Hardwired
Hardwired
115kVSource
Integrated Protection Breaker Failure
24/GE /
69kV Bus
Source atRemote End
ProtRelayIED
OC
BreakerFailure
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115kVSource
Protl
Integrated Protection Breaker Failure
25/GE /
69kV Bus
ProtRelayIED
OC
RelayIED
ProtRelayIED
Substation LAN
115kVSource
ProtRelayIED
Integrated Protection Breaker Failure
26/GE /
69kV Bus
ProtRelayIED
OC
I
ProtRelayIED
Substation LAN
GOOSE Messages
115kVSource
Prot
RelayIED
Integrated Protection Breaker Failure
27/GE /
69kV Bus
ProtRelayIED
OC
I
ProtRelayIED
Substation LAN
GOOSE Messages
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Automation Functions
Nature of the problemDistribution substations often tapped
off supply line without high sidebreaker or high side protection
Considerable load may be out of
Automatic Load Restoration:Supply Line Sectionalizing
29/GE /
service until field crews arrive onscene
ObjectivesIdentify faulted section of supply lineIsolate faulted sectionRestore supply to substations fed off
unfaulted section of supply line
Supply Line Sectionalizing
30/GE /
SA
System
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Supply Line Sectionalizing
Permanent
Fault Occurs
31/GE /
SA
System
Supply Line Sectionalizing
Line
Protection
Operates
32/GE /
SA
System
Supply Line Sectionalizing
33/GE /
Line Protection
Reports Fault
Location
SA
System
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Supply Line Sectionalizing
34/GE /
SA System Opens
Appropriate MOD
SA
System
Supply Line Sectionalizing
35/GE /
SA System Sends
Reclose Signal
SA
System
Nature of ProblemWhen a transformer failure occurs,
simple bus failover schemetransfers load to healthy
transformer
Automatic Load Restoration:Intelligent Bus Failover
36/GE /
mp e a over sc eme mayoverload healthy transformer,especially during peak load
Some schemes have been disabledbecause of this
Substation firm capacity limited byamount of load that can be carried ifa transformer fault occurs
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ObjectivesTransfer as much load as possible
to 2nd substation transformer
Automatic Load Restoration:Intelligent Bus Failover
37/GE /
,to alternate substation
Shed portion of load if necessary
Intelligent Bus Failover:
How It Works
38/GE /
Transformer
Fault
Intelligent Bus Failover:How It Works
39/GE /
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Transformer
Fault
Intelligent Bus Failover:
How It Works
40/GE /
Trf
Protection
Intelligent Bus Failover:How It Works
41/GE /
Intelligent Bus Failover:How It Works
42/GE /
Bus Transfer
Scheme
Operates
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Intelligent Bus Failover:How It Works
43/GE /
Shed Load
If Necessary
To Adjacent
Substation
Intelligent Bus Failover:How It Works
44/GE /
Restore Load
Using Feeder
Automation
To Adjacent
Substation
Enter riseApplicationFunctions
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Disturbance Analysis
Exploit Inherent Capabilities ofIEDs
Sequence of Event reportingDigital Fault Recorder (DFR)Fault Location
52/GE /
Disturbance Data from
relay IED
Computer
Engineers Desktop
Intelligent Alarm Processing
Prioritize alarm informationEliminate duplicate & nuisance alarmsRoute alarm info to appropriate partyExpert alarm processing
provides more informative and useful
53/GE /
alarm messages
Phase A Phase Overcurrent Alarm
Phase B Overcurrent Alarm
Ground Overcurrent alarm
CB change of state
Loss of voltage
Etc..
Feeder Fault A-B-GAlarm
Filter
Power Quality Monitoring
SA System and IEDs able to detectpower quality events and report thefollowing information: Harmonic content of the voltage
waveform
Total harmonic distortion
54/GE /
Power Quality Info from IEDs
Computer
Engineers Desktop
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Real-Time Equipment Rating
Base equipment ratings onactual conditions rather thanconservative assumptions
Squeeze more capacity out ofexisting equipment
Exam le:Transformer Hot S ot
55/GE /
Monitoring Monitor the true winding hot spot
temperature
Derive loadability from the results
5 - 10% additional loading can be
achieved
Continuous On-lineDiagnosis of SSEquipment (HVbreakers, Transformers)
Equipment Condition Monitoring
56/GE /
Support reliability centered
maintenanceFind/fix problems earlierAvoid forced
(unscheduled) outages
Reduce maintenance costs
Equipment Monitoring Devices
Dissolved Gas in Oil Monitors/Samples
Moisture Detectors
Load Tap Changer Monitors
Partial Discharge/Acoustic Monitors
57/GE /
Bushing Monitors
Circuit Breaker Monitors (GIS and OCB)
Battery Monitors
Expert System Analyzers
Protective Relay IEDs (I2t, Breaker timing)
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Role of SAMonitor specialized
sensorsPerform expert system
Equipment Condition Monitoring
58/GE /
Inform engineers ordispatchers of possibleproblems
Supply non-operationaldata
Equipment Condition Monitoring
Triggers, Alerts
SubstationMaintenance
Office
Traditional approach:
59/GE /
Telephone
MaintenanceManagement
System
ConditionMonitoring
Sensor
Modem
Equipment Condition Monitoring
SA approach Use Non-Operational Data
Path:
Workstat ion Workstat ion Workstation
Modem Data
Firewall
Engineering PC
Data
FirewallRouter
OperationalData
60/GE /
Server Server
IED IED IED
Radio tower
DataConcentrator
Local HMI
IED
TCP/IPCorp WAN
Router
Server
DataWarehouse
Non-Operational
Data