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•AEP’s gridSMARTsm Strategy & Technologies

IEEE MeetingFebruary 24, 2011

Richard Greer

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The Evolution of the Electric Utility System

Before Smart Grid:

One-way power flow, simple interactions

After Smart Grid:

Two-way power flow, multi-stakeholder interactions

Adapted from EPRI Presentation by Joe Hughes NIST Standards Workshop

April 28, 2008

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AEP’s Distribution “Grid Management” Infrastructure

• Transforming from Single Source Distribution Circuits to an Interconnected Grid with Multiple Sources, Real Time Visualization, Optimization, Automation, and Control.

– Installation of a distribution management system (SCADA) and the development of a distribution energy management system with visualization tools for “multi-source” distribution operations.

– Control of voltage and Var to maximize grid efficiency from the generator to the customer

– Circuit reconfiguration to improve reliability and optimize circuit performance.

– Accommodate and take full advantage of distributed energy sources including renewables, storage, customer generation, and demand response

– Installation of remote sensors and automated control devices to provide “real time” analysis of the dispatch of multiple sources on a feeder

CYBER SECURITY FIREWALLReal Time

Real Time and

HistoricalData

Distribution Management SystemDSCADA

Distribution Operations Center (DOC)

Outage Management System (OMS)

AMI Meters

Distributed Energy

Resources

DistributionAutomation

FaultLocating

EquipmentMonitoring

andDiagnostics

gridManagement Analytics

BACKHAUL COMMUNICATIONS

CYBER SECURITY FIREWALL

Real Time and

HistoricalData

BACKHAUL COMMUNICATIONS

Real Time

Distribution Management SystemDSCADA

Outage Management System (OMS)

gridManagement Analytics

Distribution Operations Center (DOC)

AMI Meters

DistributionAutomation

FaultLocating

EquipmentMonitoring

andDiagnostics

Distributed Energy Resources

Distributed GenerationEnergy Storage

Demand ResponseSolar & Wind

PHEVs

TransformersLine Devices

InsulatorsConductors

Circuit ReconfigurationDevice Status

Remote OperationVolt Var Control (IVVC)

Fault ValuesAnticipationIndication

Power UpPower Down

PINGMeter Events

CYBER SECURITY FIREWALL

Real Time and

HistoricalData

BACKHAUL COMMUNICATIONS

Real Time

Distribution Management SystemDSCADA

Outage Management System (OMS)

AMI MetersCustomer Distribution

AutomationFault

Locating

EquipmentMonitoring

andDiagnostics

Distribution Operations Center (DOC)

gridManagement Analytics

Distribution Market Clearing (future)

Operation EngineersPlanning Engineers

Transmission Co-Located Engineers

Demand Response Analytics Reliability Engineers

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AEP gridSMART Deployment Status

AEP Texas – In Progress

• Approximately 1 million AMI meters • In-home display devices• Tariffs & programs to be offered by REPs

Indiana Michigan Power (AEP) – In Service

• 10,000 AMI pilot program (GE meters)• Distribution automation• Programmable communicating thermostats• Enhanced time-of-use tariffs• Customer web portal for monitoring & management

AEP Ohio – In Progress

• 110,000 AMI deployment in NE Columbus area• Full suite of distribution automation technologies• Advanced technology deployment (Energy storage, PHEVs)• Enhanced time-of-use tariffs• Home area networks & grid-friendly appliances

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Automated Circuit Reconfiguration

• Utilizes communication and intelligent technology to minimize # of customers impacted by an outage • can improve circuit reliability by 30 – 50%• Can improve energy efficiency by notifying operations when a capacitor bank is

abnormal• Improves safety and efficiency for field employees by using SCADA for remote

switching

• This technology has been evolving over several years and standards are being developed. • Actual deployment still is limited in most utilities. • AEP has deployed this technology on less than 2% of circuits.• The potential for improving reliability and increasing energy efficiency of

distribution circuits is high if more automation is deployed.

Station A

B

B

B

R R

R R

R R

Station B

300 300

300

900

300

900

300

300

300

900

300

300

Temporary Fault – Momentary Interruption

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Operational Summary

• Traditional Circuit• Temporary Fault – no sustained outage• 600 Customers saw a short interruption

(blink)• MAIFI = 1 for these 600 customers

Station A

B

B

B

R R

R R

R R

Station B

300 300

300

900

300

900

300

300

300

900

300

300

Permanent Fault 600 Customers Outaged

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Operational Summary

• Traditional Circuit• Permanent Fault• 1 Instantaneous and 2 time delay trips• 600 Customers Outaged• Circuit SAIFI = 600 / 900 = 0.67• System SAIFI = 600 / 2,700 = 0.22

Station A

B

B

B

R R

R R

R R

Station B

300 300

300

900

300

900

300

300

300

900

300

300

Permanent Fault With DA = 300 Customers Outaged

R

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Operational Summary

• Circuits With DA• Permanent Fault• 1 Instantaneous and 2 time delay trips• DA Reconfigured Circuits• 600 Customers saw short interruptions (blinks)• 300 Customers Outaged • Circuit SAIFI = 300 / 900 = 0.33• System SAIFI = 300 / 2,700 = 0.11• MAIFI for 300 Customers = 1

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• GE Hydran M2: An intelligent, on-line transformer monitoring system that provides:– Per phase real time load,– Per phase winding temperatures,– Transformer top oil temperature,– The level of combustible gases

and moisture in dielectric oil,– Oil bubbling temperature, – Aging rate and early detection of

incipient faults in station transformers.

• 73 units installed• Visible via SCADA and PI Historian

Transformer Diagnostics & Monitoring

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Utility Voltage / Var Control:1. Projected benefits of 2% demand and energy reduction are highly predictable because customer

consumption is reduced with no action required on their part.2. The technology optimizes power factor and voltage levels based on selected parameters

a. Power factors close to unity minimize losses and relieve transmission congestionb. Projected response is a 0.7% demand / energy reduction for each 1% volt reductionc. Projected result is 2 - 4% demand and energy reduction

3. Utilizes communications and computerized intelligence to control voltage regulators and capacitors on the distribution system

4. Algorithm uses end of line monitoring feedback to ensure minimum required voltage maintained

AEP Ohio Demonstration Projects:1. Equipment deployment and demonstration of Volt Var Control technologies

a. GE IVVC – 5 Stations (4 -34KV & 7 - 13KV Circuits)b. AdaptiVolt – 1 Station (6 – 13KV Circuits)

2. Independent analysis by Battelle of theoretical and measured results – Expect savings of MW, MWH, MVAR, and MVARH

a. Analysis of financial benefits of MW, MWH, MVAR, and MVARH savingsb. Projections of system wide benefits

Utility VVC can achieve predictable EE/DR and emission reduction goals

AEP’s Volt Var Control Technologies

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KVA Reduction = 325 KVA (8.4%) if pf = 1.0 (4185-3860)

Estimated Benefits with GE IVVC on Karl Road 12 kV Feeder

Demand Reduction = 88 KVA (2.1%) if voltage reduced 3%

Energy Reduction = 52 KW * 8760 =

455 MWH if voltage Reduced 3%

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Voltage Range Goals • ANSI Standard C 84.1 – 1995 “Electrical Power

Systems and Equipment – Voltage Ratings” • [similar to CAN3-C235-83 (R2000)]

–Nominal 120 VAC – Range A (Normal Operation)

•Service Voltage 114 v – 126 v– Voltage at which utility delivers power to home

•Utilization Voltage 110v – 126 v– Voltage at which equipment uses power– Optimum voltage for most motors rated at 115 v– Incandescent Lamps rated at 120 v

–Nominal 120 VAC – Range B (Out of Normal Operation)

•Service Voltage 110 v – 127 v

•Utilization Voltage 106v – 127 v120

124

128

116

112

108

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“A” S

erv

ice

“A” U

tilizatio

n

“B” U

tilizatio

n

Volts at Residential Meter:

Historical VoltageRange

IVVC Range

“B” S

erv

ice

(Adapitvolt estimates)

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East Broad Station – Volt Var Control

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East Broad – 1406 Geographic Layout

Substation

EOL 56

EOL 55

EOL 57

CAP 1

CAP 2

CAP 3

CAP 4

REG 1

REG 2

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East Broad – 1406 Voltage Profile

Substation

EOL 55CAP 1 CAP 3 CAP 4REG 1 REG 2CAP 2

116.0

118.0

120.0

122.0

124.0

126.0

Normal Operation With VVC

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East Broad – 1408 Geographic Layout

EOL 64

EOL 63

Substation

CAP 1

CAP 2

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East Broad – 1408 Voltage Profile

EOL 63

EOL 64

Substation

CAP 2CAP 1

117.0

119.0

121.0

123.0

125.0

Normal Operation With VVC

117.0

119.0

121.0

123.0

125.0

Normal Operation With VVC

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Battelle Study – Initial Projections on 8 GE CVVC Circuits

Projected Peak Demand Reduction 3%Projected Energy Reduction 3.3%

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Volt VAR Control can reduce customer consumption and energy cost

123 Volts 119 Volts

1,055.6 KW607,600 kwh$43,740 / mo

1,034.48 KW595,448 kwh$42,873 / mo

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Challenges

• “Near Real Time Operation” requires highly reliable communication

• Vendor solutions for VVC are still evolving• Finding balance point for investment in circuit upgrades

vs. control systems• Understanding how technical benefits translate into

financial benefits • Determining appropriate regulatory recovery strategy• Communicating that demand and energy reductions are

mostly due to reduced consumption and the loss reduction piece is small

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AEP’s gridSMART Advanced Technologies

Distributed Renewable Generation

• 70 KW photovoltaic panels installed on roofs of AEP Service Centers in Newark,OH and Athens,OH [70 KW X 2 = 140KW]

• R&D project comparing traditional PV to concentrated PV at AEP’s Dolan Engineering lab (Groveport, OH)

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Plug-in Electric Vehicles and Infrastructure

Corporate Strategy and Readiness

• AEP strongly supports and promotes the adoption of PEV technology

• Developing consumer programs (system-wide) which may include “EV-Friendly” rates and incentives.

• Working with various stakeholders in all AEP states to ensure greatest consumer experience.

PEV Demonstration – Columbus, Ohio (2010-2013)

• Deploying 10 PEVs and 15 charging stations to AEP employees living in the demo area.

• Collecting and analyzing driving/charging behaviors and potential impact to grid. Utilizing “smart charging” to reduce impact.

• Vehicles will include Chevy Volts, Smart EVs, Ford Escape PHEV, 2 Prius converted to PHEV

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AEP’s gridSMART Advanced Technologies

Substation Scale Battery

• 2006: 1 MW, 7.2 MWh; Deferred substation upgrade in Charleston, WV

• 2008: Three installations; 2 MW, 14.4 MWh each;With “islanding” in Bluffton,OH; Balls Gap,WV; East Busco,IN

• 2010: 4MW, 25MWh; To be installed in Presidio, TX

Community Energy Storage

• Small distributed energy storage units connected to the secondary of transformers serving a few houses or commercial loads.

• Pursuing development & deployment:

AEP’s (NaS) Battery Application1 MW, 7.2 MWh installed in Chemical

Station (Charleston, WV - 2006)

• Deferred substation upgrades

Three installations in 2008 (2 MW Each)

• Peak Shaving

• Demonstrate “Islanding”

• Storage of intermittent renewables

• Sub-transmission support

290-360 ºC

AEP selected Sodium Sulfur (NaS) technology• Proven technology in Japan (TEPCO)• 1-10 MW, 4-8 hour storage systems• NaS strengths:

• Commercial record over 1MW (over 100 installations)• Cost• Compactness• Modularity & Ability to be relocated

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AEP NaS Application #1

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Bluffton, OH NaS 2 MW in Service

AEP 2006 Project AEP 2006 Project – Performance Data– Performance Data

• Scheduled trapezoidal Charge & Discharge profiles

• Improved the feeder load factor by 5% (from 75% to 80%)

+ 1.2 MW Charge

- 1.0 MW Discharge

2007

2006

2008Three

Successful Years of

Peak Shaving

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NaS Islanding – S&C IntelliTEAM II

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Community Energy Storage (CES)

CES is a small distributed energy storage unit connected to the secondary of transformers serving a few housesserving a few houses or small commercial loads

Key Parameters Value

Power (active and reactive)

25 kVA

Energy 75 kWh

Voltage - Secondary 240 / 120V

Battery - PHEV Li-Ion

Round Trip AC Energy Efficiency

> 85%

AEP Specifications for CES is “OPEN SOURCE” for Public Use and Feedback.EPRI is hosting free, open webcasts to solicit industry wide input.

www.aeptechcenter.com/ceswww.aeptechcenter.com/ces

25 KVA

• CES: 2MW/2MWh; Fleet of 80 25-kW Units

• Circuit: Morse Rd 5801; 13 kV, 6.3 MVA Peak Load, 1742 customers

• Coverage: Approximately 20% of customers

• Schedule: Aug 2010 Test Prototypes Apr 2011 First 0.5MW

Oct 2011 Remaining 1.5MW

• Status: Jun 2010 – Prototype under construction

No

rth

AEP Ohio GridSMART Demonstration - CESAEP Ohio GridSMART Demonstration - CES

Morse Rd 5801

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CES is a distributed fleet of small energy storage units connected to the secondary of transformers serving a few houses or small commercial loads.

STATION

Community Energy Storage (CES)

CESCESCES CES

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CES LayoutCES Layout

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CES – Virtual Station Scale StorageCES – Virtual Station Scale Storage

Local Benefits:1) Backup power

2) Flicker Mitigation

3) Renewable Integration

Substation

Power Lines Communication and Control Links

CES

CES is Operated as a Fleet offering a Multi-MW, Multi-hour Storage

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Communication & Control Layout for

CES

CES Control Hub

Substation

Power Lines Communication and Control Links

Operations Center

CES CESCESCES

CES is Operated as a Fleet offering a Multi-MW, Multi-hour Storage

Grid Benefits:4) Load Leveling at substation

5) Power Factor Correction

6) Ancillary services

Local Benefits:1) Backup power

2) Flicker Mitigation

3) Renewable Integration

CES – Virtual Station Scale StorageCES – Virtual Station Scale Storage

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CES Control EnvironmentCES Control Environment

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)

RevenueMeter

AMI Head-end

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Circuit Load Leveling ExampleCircuit Load Leveling Example

Circuit Demand

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Set Points:• Start Time (same for all days)• Minimum Demand below which no energy should be discharged

2:00 pm Day2

2:00 pm Day1

2:00 pm Day3

No Discharge on Low

demands

Minimum Demand at

for discharge

Time Triggered Load FollowingTime Triggered Load Following

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Set Trigger Level

Inadequate energy on high-peak days makes

peak shaving ineffective

Load Leveling Challenge – perfect timingLoad Leveling Challenge – perfect timing

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Morning Noon EveningMidnight

Trigger Level for Discharge

Trigger Level for Charge

Circuit Feeder's charge and discharge needs are assessed periodically and divided among

CES Units on the circuit feeder

Feeder Load

CES

# 1

CES

# 2

CES

# 3

Feeder level demand profile showing CES Unit charge and discharge

Load Leveling – Spread Across the CES FleetLoad Leveling – Spread Across the CES Fleet

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Each customer connected to the CES Unit gets a fair share of

available stored energy at the time an outage occurs.

CES goes into backup (island) mode

1. Establish the island, calculate available energy per

locally connected customer; x kWh

2. Instruct each locally connected meter to initiate energy

limiting; allow x kWh

3. If a customer reaches energy allocation, x kWh, the

meter opens its disconnect switch

CES Energy Allocation during backupCES Energy Allocation during backup

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CES returns from backup (island) mode when the circuit

returns to normal (system is stable for 5 minutes)

1. CES synchronizes and reconnects to circuit, closed

transition

2. CES cancels energy allocation instruction to each locally

connected meter

3. Each open meter closes the disconnect switch {unless

there was another active command to open}

CES Energy Allocation - ReturnCES Energy Allocation - Return

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CES Customer Interface ChallengesCES Customer Interface Challenges

•Another box in the yard, installation

•Equipment access for maintenance

•Transformer has 4 customers, 2 are interested

•Reliability is not really a problem

•My neighbor will use all the energy

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Transforming to a Smart Grid Engineer

• Distribution Engineers will need new skills to plan for stations and circuits utilizing DA, IVVC, DG, and other new technologies.

• Planning and protection studies will be more complex • Distribution Engineers will also have access to new

data to help analyze system performance and validate the results of studies. – An interesting example is the ability to collect data on the

performance of Distributed Generation (DG) and validate the DG’s impact on the system during abnormal conditions.

– This type of analysis should lead to higher confidence levels for Distribution Engineers charged with assuring proper operation of their circuits while accommodating and taking advantage of DG in a Smart Grid world

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Summary

• Customers will see higher reliability and more opportunity to control their energy usage and cost.

• Utility employees will have new systems to learn, new responsibilities, and much more information about system operation than they have ever had.

• The public at large should see environmental benefits as a Smart Grid helps reduce emissions from generating plants by helping control demand and energy usage while still assuring the customers’ needs for energy are met.

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Richard Greer – AEP – ragreer@aep.com

540-985-2617

Questions?