AEP’s “gridSMART” Project Ohio Roll Out Strategy PUCO Staff Workshop December 13, 2007.
1 AEPs gridSMART sm Strategy & Technologies IEEE Meeting February 24, 2011 Richard Greer.
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Transcript of 1 AEPs gridSMART sm Strategy & Technologies IEEE Meeting February 24, 2011 Richard Greer.
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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
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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
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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
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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.
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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
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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
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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
104
“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:
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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
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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
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• 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.