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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

Questions?

Paul Thomas – AEP – prthomas@aep.com

Randy Cough – GE – randy.cough@ge.com