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AEP’s gridSMART®
Grid Management Interoperability Unlocks Additional Utility Benefits
Presentation to
DISTRIBUTECH Conference & Exhibition
January 26, 2012
Paul Thomas – American Electric Power
Randy Cough – GE Digital Energy
• 5.3 Million customers• 11 States• 39,000 MW Generation
• 38,953 miles Transmission• 212,781 miles Distribution
• 6006 Distribution Circuits• 3240 D Transformer Windings
AEP System OverviewAEP System Overview
AEP Distribution System Operational Strategy
Transforming from single source distribution circuits to an interconnected grid with
multiple sources, real time visualization, resiliency, automation, and control.
Optimizing Distribution with SMART CircuitsOptimizing Distribution with SMART CircuitsOptimizing Distribution with SMART CircuitsOptimizing Distribution with SMART Circuits
1. Two way communication amongst devices with central control center visibility and automated outage recovery
a. Industry experience has yielded a 30% reliability improvement
b. Permits remote equipment switching without truck roll
2. Equipment sensors that provide real time condition/status
a. Avoid equipment overloads
b. Proactively identify potential failures
c. Enhances power quality monitoring
d. Supports diagnostic & monitoring of equipment to support asset
renewal programs
3. Integrated back office systems to provide remote and automated data collection, analysis, visualization and action
4. Asset Management analytical tools:
a. Preventive Equipment “Asset Health Index”
b. Supports asset investment planning to optimize power transformer
and other equipment replacements
c. Enables condition-based maintenance programs
5. Preventive Automated Fault Anticipation & Location
6. Two way power flow support – easy integration of distributed renewable generation
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AEP Ohio gridSMART Deployment System Overview
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AEP Ohio gridSMART Demonstration - CES
AEP Ohio gridSMART Deployment Update
• Volt VAR Optimization – 11 GE CVVC circuits constructed and operating – 6 AdaptiVolt VVO circuits constructed and operating– 5 stations, 140 devices (caps, regs, voltage sensors)
• Circuit Reconfiguration (aka CR, DA or DA CR)– 16 stations, 600 devices (caps, regs, reclosers, breakers)– 70 out of 70 circuits point to point tested– 69 out of 70 circuits system acceptance tested – 69 out of 70 circuits commissioned and in service
• Community Energy Storage– AEP Ohio had 15 of 80 CES units installed and functioning
late last year– 56 customers have signed up for a unit on their property
PSO gridSMART PSO gridSMART –– System Overview System Overview
AEP PSO gridSMART Deployment Update
• Volt VAR Optimization– 11 Cooper IVVC circuits constructed
– 3 stations, 95 devices (caps, regs, LTC’s, voltage sensors)
– 11 circuits point to point tested by Q2 2012
– 11 circuits system acceptance tested Q2 2012
– 11 circuits commissioned and in service Q2 2012
• Circuit Reconfiguration (aka CR, DA or DA CR)
– 3 stations and 13 circuits
– 52 devices (switches and breakers)
– 11 circuits point to point tested by Q1 2012
– 11 circuits system acceptance tested by Q1 2012
– 11 circuits commissioned and in service by Q1 2012
Utility Volt VAR Optimization (VVO)
Technology and infrastructure upgrades integrated into the
electric distribution system to optimize voltage levels.– Utilizes communications, computerized intelligence, and end of line voltage
monitoring to control voltage regulators and capacitors on the distribution grid
– Typically a 1% reduction in demand and energy consumption for a 1% voltage
reduction
– A 3% voltage reduction should achieve a 3% demand and energy reduction
– Power factors near unity minimize losses and relieve transmission congestion
Benefits• Immediate, highly predictable impacts.• 2-4% reduction in demand and energy requirements.• Lessens need for incremental infrastructure spending. • Helps to lower emissions (S02, NOx, Hg, CO2).• Avoids traditional EE/DR challenges such as cross-subsidization.
Volt VAR Optimization Architecture
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Volt VAR ControllersVolt VAR ControllersVolt VAR ControllersVolt VAR Controllers
Mesh NetworkMesh NetworkMesh NetworkMesh Network
MeshMeshMeshMesh MasterMasterMasterMaster
EOL MonitorsEOL MonitorsEOL MonitorsEOL Monitors
Line Line Line Line
RegulatorsRegulatorsRegulatorsRegulators
Line Line Line Line
CapacitorsCapacitorsCapacitorsCapacitors
DMS DMS DMS DMS ---- GENeGENeGENeGENe
Fiber Fiber Fiber Fiber
or Meshor Meshor Meshor Mesh
Distribution Automation Circuit Reconfiguration
Technology and infrastructure upgrades integrated into the
electric distribution system to optimize customer reliability.
– Utilizes communications, computerized intelligence, and sensors to
control reclosers, switches and breakers on the distribution grid
– Reliability improvements of 30% to 50% can be achieved through
automation
– Additional reliability and operational efficiencies will be gained through
DSCADA (DMS) monitoring and control
– Proactive knowledge of system and operation center action will
improve customer experience
Distribution Automation Circuit Reconfiguration
High Level Operational Benefits to Date
• Planned and emergency circuit switching time and labor reduced by 2hrs X 20+
• Ice Storm: 1188 of 1190 (99.8%)customers restored in 56 seconds, second fault 15
minutes later 388 (33%) customers remained in service. Avoided CMI = 437,249
minutes or SAIDI reduction of .59 minutes for CSP
• Pole Fire: 3695 of 4499 (82%) customers restored in 160 seconds, Avoided CMI =
306,685 minutes or SAIDI reduction of .41 minutes for CSP
• Outage 3: 2582 of 2965 (87%) customers restored in 72 seconds, Avoided CMI =
214,306 minutes or SAIDI reduction of .29 minutes for CSP
• Transmission outage: 1150 of 1150 (100%) were restored in 155 seconds, Avoided CMI
= 95,450 minutes or SAIDI reduction of .13 minutes for CSP
• Outage 5: 825 of 1420 (58%) customers restored in 137 seconds, Avoided CMI =
68,475 minutes or SAIDI reduction of .09 minutes for CSP
Distribution Automation Circuit Reconfiguration
High Level Operational Benefits to Date
• CSP SAIDI total reduction of 1.51 minutes for the 5 outages
• Average restoration time is 116 seconds for the 5 outages
• 9440 of 11224 (84%) customers were restored in an average of 116seconds for the 5 outages (first outage only)
Circuit Reconfiguration Architecture
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CR ControllersCR ControllersCR ControllersCR Controllers
Mesh NetworkMesh NetworkMesh NetworkMesh Network
MeshMeshMeshMesh MasterMasterMasterMaster
ReclosersReclosersReclosersReclosers
or Switchesor Switchesor Switchesor Switches
Line Line Line Line
RegulatorsRegulatorsRegulatorsRegulators
Line Line Line Line
CapacitorsCapacitorsCapacitorsCapacitors
DMS DMS DMS DMS ---- GENeGENeGENeGENe
Fiber Fiber Fiber Fiber
or Meshor Meshor Meshor Mesh
SensorsSensorsSensorsSensors
Breaker ControlBreaker ControlBreaker ControlBreaker Control
CR and VVO Interoperability
CYBER SECURITY FIREWALLReal TimeReal TimeReal TimeReal Time
Real Time and
HistoricalData
Distribution Management System
DSCADA
Distribution Operations Center (DOC)
Outage Management System (OMS)
AMI Meters
DistributedEnergy
Resources
DistributionAutomation
FaultLocating
EquipmentMonitoring
andDiagnostics
gridManagement Analytics
BACKHAUL COMMUNICATIONS
Multiple Control InteroperabilityMultiple Control Interoperability
CESController
DAController
VVController
Regional(Station)
D-SCADARTU
T-SCADARTU
Mesh Network (DNP)
CESUnit
RecloserSwitch
CapacitorRegulator
FeederDevices
HAN (Zigbee / HomePlug)
CustomerDisplay
WaterHeater
HVACThermostat
CustomerDevices
PEV SmartCharger
Backhaul (Fiber and other)
Enterprise Systems
D-SCADA MDM(Meter)
CIS(Customer)
GIS(Asset)
OMS(Outage)
HistoryArchives
T-SCADACESManagement
DWM(Work)
Revenue
Meter
AMI Head-end
Scope- 10-941, OMS/DMS 1.0 - Scope
GIS
• Manages network asset information in a
geographical context• Provides current and future view of
networkOMS
• “Predicts” and manages outages based on customer calls, smart meters and
SCADA
• Manages work flow for dispatching operations
• Interfaces to many utility systems
DMS
• Manages real-time network operations
• Provides advanced analytics• Proposes planned and emergency
switching
Integrated Distribution Operations Platform
Interoperable DMS-OMS-GIS
• Integrated work flow
• Coordinated network model
• Service-based data
interface
• Common OMS-DMS UI
• Standardized interfaces to
other utility systems
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Integrated Distribution Operations Platform
This platform leverages a common network model and integrated applications to further
streamline business process and provide accurate, timely information to all personnel
Load Flow
DMS - GENe
Common Dispatcher Interface
Trouble CallManagement
CrewManagement
Outage
Management
Switch
Management
OMS - PowerOn
SwitchManagement
StateEstimation
FDIR
IVVCDistributedResourceControl
Common
Network ModelPlan, Design, ConstructPlan, Design, Construct
AsAs--built, Inspect, built, Inspect,
AnalysisAnalysis
GIS – Electric Office
Engineering,Engineering,
Historical, PlanningHistorical, Planning
AnalysisAnalysis
Visualize
Use Cases:
• Network Updates
• Network Validation
• Manage Changes
• Manage Advanced Apps
• OMS / DMS real time
model sync
• Circuit re-configuration
• Planned Switching
• Installing CR or VVO in an area is a “simple” deployment ☺
• Deploying CR and VVO (and others) in the same area created unrecognized challenges:
� VVO designed and constructed first before CR in sub optimal footprint
� Initial VVO applications required stable topology
� Today interoperability between CR/VVO means VVO is turned off prior to
allowing CR to change topology
� Next step CR/VVO interoperability will allow for VVO to remain on even
when CR changes topology – VVO system dependent
• Testing, configuring and commissioning devices and automation schemes is much more time consuming and complicated than stand alone devices
• When communications or controls fail, automation must allow the field equipment to return to local control
Interoperability Lessons Learned
• Interoperability means that two vendors CR automation schemes should be able to talk and reconfigure circuits with shared tie points:
� We have not demonstrated this yet
� Has this been demonstrated by anyone yet?
• Operating CR, VVO and DSCADA (DMS) helps to identify, trouble shoot and proactively correct:
� Miscoordination between overcurrent devices
� Multiple tapping regulators
� Faulty capacitor banks or switches
� Failing regulator contacts, shorting coils, motors, etc.
� Misc. failing equipment and tree contacts
� Communication issues
� And last but not least; identify equipment ghosts that have been there all
along and work with vendors to improve their equipment firmware,
software and processes.
Interoperability Lessons Learned
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This material is based upon work supported by the Department of Energy under Award Number DE-OE0000193."
Disclaimer: "This report was prepared as an account of work sponsored by an agency of the United States Government. Neither the United States Government nor any agency thereof, nor any of their employees, makes any warranty, express
or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus, product, or process disclosed, or represents that its use would not infringe privately owned rights. Reference
herein to any specific commercial product, process, or service by trade name, trademark, manufacturer, or otherwise does
not necessarily constitute or imply its endorsement, recommendation, or favoring by the United States Government or any agency thereof. The views and opinions of authors expressed herein do not necessarily state or reflect those of the United
States Government or any agency thereof.
DOE Project EnhancementsDOE Project Enhancements