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GE Energy Session 4 of a 5 Part Series on the Smart Grid
The Smart Grid … Lunch and LearnSession 4: The Smart Grid – The Transmission View
Smart Grid Learning Series
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Session 1: The Smart Grid and its Benefits
Session 2: The Smart Grid… The Consumer View
Session 3: The Smart Grid… The Distribution View
Session 4: The Smart Grid… The Transmission View
Session 5: The Smart Grid… The View from Rural America
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Session 4: The Smart Grid – The Transmission View
Topics:Smart Grid Overview
• Benefits Overview• Overview of Good Things Enabled by the Smart Grid• Overview of the Calculated Benefits of the Smart Grid
Transmission Today. A “Pretty Smart Grid”
Smart Grid – The Transmission View
Wide Area Measurements & Control
The Changing Role of Generation - Distributed Generation
Distributed Energy Resources/Microgrids
Utility Energy Storage: The Economics
Impact of Policy Discussion
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Soaring energy demandPower outages’ financial impact Green energy takes center stageElectricity prices on the riseAging infrastructure/workforce
Industry challenges
U.S. sees 6.5% spike in ’09electric bills
Source: EIA (Energy information Administration)
6.5%
Electricity prices on the rise
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Electricity … Poised to change the world again
“We can’t solve problems by using the same kind of thinking we used when we created them.”
- Albert Einstein
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The Smart Grid
Growing complexity in modern grids
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Grid Inefficiency
Source: AEP PUC Hearing
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Aging Assets
Age in Years
0%
20%
40%
60%
80%
100%
1 5 9 13172125293337414549535761656973778185899397
Transformer failure rate
The average US transformer age is just under 40 years old
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Electrical infrastructure
What is a Smart Grid?
The integration of two infrastructures… securely
ElectricalInfrastructure
Information Infrastructure
Sources: EPRI® Intelligrid
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Wide-AreaProtection &Automation
Wide-AreaMonitoring & Control
DeliveryOptimization
AssetOptimization
DemandOptimization
RenewablesForecasting
RenewablesSmoothing
Flexibility for emerging capabilities
What it is Why$16MM/yr, 51K tons of CO2 reduction+Res. consumer savings up to 10%Based on 1.6% peak load reduction using critical peak pricing resulting in reduction in fuel costs and deferral of generation capacity
Utility Value/MM Customers*
$7MM/yr,, 45K tons of CO2 reduction+Based on 0.2% loss reduction and 0.5% CVR peak load reduction resulting in reduction in fuel costs and deferral of generation capacity
$11MM/yr, ~4.5 yr ROIBased on system-wide deployment of advanced transformer M&D resulting in transformer life extension and reduction in inspection, maintenance & repair costs
Prognostics for proactive equipment maintenance
Reduced outages and focused maintainers
Asset optimization
Reduce delivery losses in distribution systems
Less energy waste and higher profit margins
Delivery optimization
Manage peak via control of power consumption
Defer upgrades, optimize generation & renewables
Demand optimization
Reliabilityoptimization
Wide Area Protection & Control
Increased network performance & reliability
$7MM/yrBased on the deferral of the capacity upgrade of two 220kV transmission lines for 3 yrs (each line 30 miles long with a cost of upgrade of $1.5MM per mile)
Renewablesoptimization
Use of Forecasting & Smoothing
Compensation for production variability
Key step for meeting RPS targets, especially in areas with weak grids
Roadmap for a Smarter Grid
*Utility savings are approximate annual savings per one million customers+ $85/kW-yr peak generation capacity value
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Smart Grid – The Transmission View
Transmission Grid has held itself Pretty good!
Source: Eric Hirst – Consultant www.Ehitst.com
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2003 Blackout
The 2003 Blackout Thursday, August 14, 2003, at approximately 4:15 pm EDT.
Affected 55 million people in eight U.S. states, 1 province in Canada and
256 power plant went off-line!
> 4:10:38 p.m. Cleveland separates from the Pennsylvania grid.
> 4:10:46 p.m. New York separates from the New England grid.
> 4:10:50 p.m. Ontario separates from the western New York grid.
> 4:12:58 p.m. Northern New Jersey separates its power-grids from New York and the
Philadelphia area,
> 4:13 p.m. End of cascading failure.
> 85% of power plants which went offline after the grid separations occurred, most due to
the action of automatic protective controls.
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The Cleveland separation
DOE/FERC Feb 2006 Report to Congress:
> 2003 Blackout due, in part, to “lack of awareness of deteriorating conditions.
> Technology now exists that could be used to establish a real-time transmission monitoring system…”
> In parallel: NERC identified the need for “Situational Awareness” of the Power Grid.
-170-160-150-140-130-120-110-100
-90-80-70-60-50-40-30-20-10
0
15:05:00 15:32:00 15:44:00 15:51:00 16:05:00 16:06:01 16:09:05 16:10:38Time (EDT)
Rel
ativ
e Ph
ase
Ang
le Cleveland West MI
Normal Angle ~ -25º
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Wide Area Measurements & Control
Wide Area Measurements, Architecture
PMU PMU PMU. . .
PDC
PMU PMU PMU. . . PMU PMU PMU. . .
Regional Operation
NERC / DHS
Very High-speedDecisions
10-100 ms time frame20-60 Phasors/
Sec
High-speedDecisions
100 ms – 1S time frame1-15 Phasors/sec
PDC PDC
Human Monitoring / EMS > 1 sec1 Phasor/Sec
Wide Area Measurements, Monitoring Phasor Data Concentrators – Local/Regional Monitoring
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System implementation, Visualization
PhaseAngle+30+20+10+00
-10-20-30
+30+20+10+00
-10-20-30
System Contour View
System Frequency View
. . . . .
Data CollectionReplication, Re-Transmission
Proficy
High Speed Applications
Data Rate:12 - 60
Measurements per Second
ICCP InterfaceEMS
OPC / SQL
Sub-PDC
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Synchrophasors - Advanced Analysis & Control Applications
• Situational Awareness
• Under Voltage Load Shed
• MW/MVAR Oscillation viewing/detection
• Oscillation Pattern Analysis & Alarm
• Oscillation Damping
• Dynamic Line Rating
• Angle Check
•Load Duration Plots
• Measure, Detect, Take appropriate control actions
• Proactively eliminate possible Blackouts!
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Special Protection Schemes(SPS)
NERC - North American Electric Reliability Council Defines SPS:
Automatic protection system (also known as a remedial action scheme) designed to detect abnormal or predetermined system conditions
Take corrective actions other than and/or in addition to the isolation of faulted components to maintain system reliability.
Actions may include changes in demand, generation (MW and Mvar),
System configuration to maintain system stability, acceptable voltage, or power flows.
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Contingency Identification
CB1
-
Control Area 1
Generation
1
LINE1
XMER
BK-1XMER BK-2
XMER BK-3
LINE2
500 KV LINE
500 KV LINE
500 KV BUS1
500 KV BUS2
500 KV BUS1
345 KV BUS1
500
KV
BU
S1
345 KV BUS2
230 KV BUS
230 KV BUS
500
KV
LIN
E
500 KV LINE
345 KV LINES
230 KV BUS
XMERBK-4
CB2
CB3
CB4
EHV
LIN
ES
500 KV BUS2
BUS2
CB3
Control Area 2
Control Area 3
Generation
1
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Network Architecture
Control Area 1Control Area 3
Control Area 2
44 44
Wide Area Network WAN (Intranet / Internet)
Link to Office LAN / WAN
Office PC using Internet Explorer
Office PC LAN
Corporate Intranet Web Server
δ1 δ2δ3
δ4
Control Area 2
δ1 δ2δ3
δ4
δ1 δ2δ3
δ4
Different “Tiers” of connection
Control Area 3
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Distributed Generation
Distributed Generation
DG Types DG Growth Globally
↑23.3%
↑30.4%↑1.1%↑16.1%
↑22.4%
Source: Frost & Sullivan 2003
Challenges Involved in DG Grid Interconnection- Distribution system protection strategies for bi-directional power flows- Reactive power/ voltage control- "Islanding" issue- Low/no inertia for fast power balancing
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Isolated Grid Challenges
• Frequency performance under large generation/load swings– Lack of inertia increases system sensitivity
• Integration of non-conventional energy resources– Desire driven by fuel costs and logistics– Intermittency of renewables– Low overload, short circuit ratings– Power rate limits
• Distribution protection and controls inadequate for distributed gen– Bi-directional power flows– Unit level voltage and VAR support– Fault current contribution– Island operation
• Supervisory controls needed to realize full operating potential– System-level energy optimization (electrical, thermal, loads)– Unit commitment and dispatch– Aggregation and system performance
Freq
uenc
y (H
z)27
Generation Controls
Conventional & Non-conventional Generation Control• Conventional generator: directly connected to the grid • Non-conventional generation: connect through Power Electronics (PE)
Major Control Functions• Volt/VAR Regulation• Power/Freq Regulation• Isochronous/Droop Regulation
• Inertial Response• Black-start Capability
Advanced PE Controls• Low/Zero Voltage Ride Through
- Ride through severe disturbances- Support grid recovery
• High voltage ride through• Virtual inertia
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Distributed Generation Transfer Trip Control
Example:
1. Fault occurs on the distribution line.
2. DGT Control sends a wireless trip signal from the substation to the DG site.
3. The trip signal from the substation is received by a DGT Control at the DG site.
4. The breaker at the DG site trips open and disconnects the DG from the Utility grid.
5. The DGT Control at the DG site transmits breaker status info back to the Utility Substation
GE’s DG Trip Control offers fast & wireless transfer of trip signals and enables the Distributed Generator to disconnect itself from the grid.
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Distributed Energy Resources/Microgrids
Relieving Grid Congestion - DG/DR/DER
•DG/DR/DER Distributed Generation/Distributed Resources/ Distributed Energy Resources - dispersed generations and energy resources at the MV and LV level. Examples include diesel genset, CHP, PV, Fuel-cell, energy storage, and dispatchable loads.
•Microgrid Microgrid is an architecture for aggregating multiple DER assets and managing them as a single entity like a virtual power plant. •A microgrid can connect to the power grid operated by utility companies, or it can exist in isolation. In the grid-connected case, power may flow in either direction between the the grid and the microgrid via the Point of Common Coupling (POCC).
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Micro Grid Value Proposition
•Enable efficient integration of traditional generators with clean power•Minimize energy cost via optimized dispatch of multiple DER•Reduce operating cost by reducing manual operations and their complexities
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Microgrid Control System
• Microgrid Control System• Microgrid Control System automates and optimizes the use of distributed
energy resources (DER) such as conventional generations, renewable-based generations, energy storages, and dispatchable loads.
• Optimization of a microgrid involves coordinating the timing and selection of dispatchable DER with the non-dispatchable ones (such as renewable resources) to minimize energy cost or emission cost.
Diesel
RenewablesOptimization
Reduced
Energy Costs
GHG Emissions
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Optimal Dispatch
•Microgrid controller determines a set of dispatch decisions by applying the cost objective against the constraints, and the dynamic state of microgrid such as the current output power levels of generators, the input/output power levels and the state-of-charge of each energy storage unit, etc.•The decisions are translated into specific DER actions such as on/off control and power reference set-points. The optimization process is performed periodically to follow the evolving dynamics of the microgrid.
Constraints
System Status
Renewable Forecasts
Load Forecasts
Cost Optimization
Control Generators & Storages
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Microgrid Control System
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Bella Coola
Clayton Falls 2.12 MW Hydro
Bella Coola2.1/1.5MW
6.2 MW Diesel
Hagensborg2.6/1.7 MW
25 kV Distribution
Local HMI
Diesel Genset InterfaceHydro Generator Interface
Remote Monitoring
Microgrid Controller
Storage
Fuel Cell125 kW
3.3 MW-hr
Electrolyzer300 kW
Utility Service Vehicle
Flow orConventional
Battery125 kW / 400 kW-hr
Ethernet Switch
modem
Wireless Radio
Ah Sin Heek Diesel / Energy Storage Site
Microgrid Features:• Centralized Supervisory control to
optimize the use of renewables and minimize the use of diesel
• Wireless local area network• Hydrogen based energy storage
system• Capability to connect, monitor and
control the system remotely• Interfaces to all Microgrid elements
Bella Coola Microgrid Control System
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Maui Project – Smart Grid
“Overarching DOE objective is to develop & demonstrate a open architecture distribution automation solution that aggregates DG, energy storage, & demand response technologies in a distribution system to achieve both T&D benefits.”
•DOE interest is on “reduction of distribution feeder peak demand by at least 15%” using a diverse mix of DG, storage, renewable energy, demand response
•Utility interest is to address the challenges of increased variability caused by wind and solar power.
>Proposed in July, 2007 to the DOE Office of Electricity
>Funded at over $14M over three fiscal years
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Overview
30MW Kaheawa wind plant
2.7MW OceanlinxTM
Wave Power (proposed)
Kahului Power Plant
HC&S Sugar13MW Steam
New Kihei Sub (potential site)
Kuihelani Sub(potential site)
Maalaea Power Plant
Hawaii Natural Energy Institute
US Department of Energy
State of Hawaii
Hawaii Natural Energy Institute
US Department of Energy
State of Hawaii
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TOPICS
Develop a Smart Grid controls and communication architecture capable of coordinating DG, energy storage and loads to:
• Reduce peak load by 15% relative to loading on the distribution circuit.• Mitigate the impacts of short-timescale wind and solar variability on the grid
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MECO Power System
GE is working with MECO to develop dynamic and
production cost models to assess higher wind penetration
scenarios
Unit Type MWK1 Oil Steam plant 5
K2 Oil Steam plant 5
K3 Oil Steam plant 11.5
K4 Oil Steam plant 12.5
X1, X2 EMD Diesel 2.5
M1 – M3 EMD Diesel 2.5
M4 – M7 Cooper Diesel 5.6
M8 – M9 Colt Diesel 5.6
M10 – M13 Diesel Mitsubishi 12.5
M14 – M16 2 x GE LM2500 CT + Steam plant 58
M17 – M19 2 x GE LM2500 CT + Steam plant 58
HC&S Sugar Plant (Steam plant) 13
KWP Wind Plant 30
Unit Type MWK1 Oil Steam plant 5
K2 Oil Steam plant 5
K3 Oil Steam plant 11.5
K4 Oil Steam plant 12.5
X1, X2 EMD Diesel 2.5
M1 – M3 EMD Diesel 2.5
M4 – M7 Cooper Diesel 5.6
M8 – M9 Colt Diesel 5.6
M10 – M13 Diesel Mitsubishi 12.5
M14 – M16 2 x GE LM2500 CT + Steam plant 58
M17 – M19 2 x GE LM2500 CT + Steam plant 58
HC&S Sugar Plant (Steam plant) 13
KWP Wind Plant 30
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Maui Project Schedule
Utility Energy Storage
Storage – Transmission Deferral
• Delay capital upgrades or Demand Charges• 2-3 hrs of storage • Cost targets are ~$500/kW, +$100/kWh• Trailer system could be viable in urban markets.
GoodNight Consulting sub-station photo NGK July 2004 : Na-S Battery System for peak shaving 57MWh, 9.6MW, 6 hrs
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Utility Scale Storage Technology portfolio
•Mature • Lead Acid
• Ni-Cad
• Sodium Sulfur•
• (Pumped Hydro)
•Developing• Vanadium• Poly-Sulf-Bromide
• Na-NiCl
• Zinc-Bromide•• (Compressed Air)
EmergingCerium Zinc
Flow Batteries
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Installed cost of storage
• Flow Battery Systems:• + Excel for >1 hour of
storage • + Good for daily cycle apps• (high cycle life, low maint)• + Very scalable (kWh -
MWh)• + Potential for new
chemistries• - Lower cycle efficiency
than conventional storage (pump and standby losses)
• - Less mature cost model and manufacturing (range of maturity for various technologies & manfc’s)
Estimated Installed Cost for 100kW-MW class systems
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Impact of Policy
Source: Annual Energy Outlook 2009
GHG Legislation Magnifies the Need of SG
The Role of Generation Impacted by Policy
Reference No GHG Concern LW 110
258.7273.4
338.1
0
100
200
300
400
GW
Coal no CCSCoal with CCSOil / Natural GasNuclearRenewables
LW110-Lieberman and Warner (S. 2191) in the 110th Congress
Renewables represent over 30% under LW110
GW
Cumulative Additions to US Generating Capacity, 2008-2030, Three Scenarios
400
100
200
300
0
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Demand Response Policy/Driving Energy Savings
Source: EIA
Demand Management Actual Peak Load Reductions 2002 - 2007
MW
*A Methodology for Estimating Large-Customer Demand Response Market Potential,LAWRENCE BERKELEY NATIONAL LABORATORY
FERC shall report to Congress estimates for a nationwide demand response potential in 5- and 10-year horizons, including state-by state data.
FERC shall develop a National Action Plan identify: technical assistance needed by states, requirements for a national communications program, & development/ identification of analytical tools, model contracts, and other “support materials” for use by customers, utilities, and demand response providers.
Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report."
Demand-Side Management Program Energy Savings, 2002 –2007
(Thousands of MWh)
Energy Independence and Security Act of 2007 (EISA). Demand Response provisions
Demand Response Programs-ISOs/RTOs Lead
Wholesale Markets DR Programs Improve System Reliability
Summer 2006 demand response contributions and summer 2007 program enrollments
Source: FERC 2007 Assessment of Demand Response and Advanced Metering
July , August 2006:
Estimates Indicate wholesale markets lowered system peaks between 1.4 & 4.1 % on peak days
*Open Access Transmission Tariff regulations in Order No. 890
NERC-wide:
2007 DR increased to 21.9GW from 2006 (20.7GW)
FERC* now requires RTOs, ISOs to Incorporate DR programs in their Planning process
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Smart Grid Learning Series … next week
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Session 1: The Smart Grid and its Benefits
Session 2: The Smart Grid… The Consumer View
Session 3: The Smart Grid… The Distribution View
Session 4: The Smart Grid… The Transmission View
Session 5: The Smart Grid… The View from Rural America