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Western Wind and Solar Integration Study
Dr. Debra Lew
Energy Seminar
Stanford University
Nov 3, 2010
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Welcome to Renewatopia
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Three electrical interconnections in the U.S.
1 2
3Western Electricity Coordinating Council
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The West doesn’t have a lot of markets
NPPD is Joining SPP
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Time (hour of day)0 4 8 12 16 20 24
Syst
em L
oad
(MW
)
seconds to minutes
Regulation
tens of minutes to hours
LoadFollowing
day
Scheduling
A Chronological View
Hours to Day ahead: use load forecast to commit units10 minutes to few hours: manually adjust generator set pointsSeconds to minutes: AGC automatically adjusts generator output
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Variability and Uncertainty
Variability: Wind and solar generator outputs vary as the intensity of their energy sources (wind and sun)– Several timescales: minute (regulation), hour (ramping), diurnal,
seasonalUncertainty: Wind and solar generation are similar to “load”
– Not dispatchable – output is predicted by a forecast– Actual power output is different that forecast output
A perfect forecast eliminates uncertainty, but there is still variabilityThe power system is designed to handle variability and uncertainty in
the load. Wind and solar add to this variability and uncertainty.
0
5000
10000
15000
20000
25000
0 6 12 18 24 30 36 42 48Hours
MW
Wind ActualForecasted Wind
0
500
1000
1500
2000
2500
0 6 12 18 24 30 36 42 48Hours
MW
CSP ActualCSP Forecasted
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Can we integrate 35% wind and solarin the West?
Goal - To assess the operating impacts and economics of wind and solar on the WestConnect grid.
• How do local resources compare to remote, higher quality resources via long distance transmission?
• Can balancing area cooperation help manage variability?
• Do we need more reserves?
• Do we need more storage?• How does geographic diversity help?
• What is the value of forecasting?
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Scenario penetration levels
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Name WestConnect Rest of WECC
Wind Solar Wind Solar
10% 10% 1% 10% 1%
20% 20% 3% 10% 1%
20/20% 20% 3% 20% 3%
30% 30% 5% 20% 3%
Penetration levels are by energy (MWh), not capacity (MW). Solar is 70% concentrating solar power with thermal storage and 30% rooftop photovoltaics.
Highrenewables
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Geographic Scenarios(high renewables case)
In-Area - each state meets target from sources within that state.
Mega Project - concentrated projects in best resource areas.
Local Priority - Balance of best resource and In-Area sites.
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What do we model?
• Model the year 2017 three times• Use historical load and weather patterns from 2004,
2005, 2006 (need correlated load/wind/sun data!)• Statistical analysis of variability. Focus on extreme
events.• Power simulations of all of WECC on hourly basis and
down to 1 minute for extreme events.
• Need high resolution (in time and space) wind and solar data
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Wind data
http://www.nrel.gov/wind/integrationdatasets
• 3TIER Group ran weather model to recreate weather for 2004, 2005, 2006
• 10 minute wind power output for 960 GW of wind sites in WECC.
• Power profiles were based on VestasV90 3MW turbine at 100m height.
• Hourly day-ahead power output forecasts.
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How does the system operate in the high renewables case?
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Mid-July
The operator formerly managed to load but now has to manage the net load.
Load
Net Load = Load - Wind - Solar
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How does the system operate in the high renewables case?
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Mid-July Mid-April
Mid-April shows the challenges of operating the grid with 35% wind and solar.
This was the worst week of the 3 years studied.
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Operations during mid-April
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No Wind/Solar High renewables case
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High renewables case saves 40% in fuel and emissions costs
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40%, or $80 per MWh of wind/solar
Note: Assumes $30/ton CO2 tax.
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High renewables case reduces CO2 by 25-45%
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At a $9.50/MBTU gas price, wind/solar displace gas, resulting in modest emissions reductions.
25%
5%
15% reduction
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High renewables case reduces CO2 by 25-45%
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At a $9.50/MBTU gas price, wind/solar displace gas, resulting in modest emissions reductions.
At a $3.50/MBTU gas price, coal is displaced, resulting in high emissions reductions.
45%
30% reduction
50%
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High renewables case reduces CO2 by 25-45%
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At a $9.50/MBTU gas price, wind/solar displace gas, resulting in modest emissions reductions.
At a $3.50/MBTU gas price, coal is displaced, resulting in high emissions reductions.
30% reduction
50%45%
That’s like taking 35 million cars off the road!
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You need Balancing Area Cooperation
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You need Balancing Area Cooperation
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You need subhourly scheduling
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Hourly scheduling puts more stress on the fast regulating reserves than the wind and solar variability does.
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You need forecasting
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Forecasting saves up to 14% in annual operating costs. If forecasts were perfect, an additional 1-2% could be saved.
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You need demand response (or more expensive measures)
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Forecast error distribution
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• Using existing rules for contingency reserves, there were occasional reserve shortfalls
• Increase spinning reserves for every hour of the year.• Add storage like pumped hydro storage.• We only have shortfalls for 89 hours of the year (1%), so
these options can be expensive.
• Demand response(paying loads to turn off) was found to be effective and was less expensive.
You need demand response (or more expensive measures)
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You don’t necessarily need more variability reserves
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Wind and solar double the variability reserve requirements (load following).
Because wind and solar cause some generators to be turned down, rather than off, the system actually has more up-reserves than it does in the no wind/solar case.
Additional reserves do not need to be committed to cover the increased variability reserve requirement.
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You don’t need more storage
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• We evaluated storage for price arbitrage only. We did not evaluate storage for ancillary services (reliability, regulation, etc).
• Wind and solar increased use of existing pumped hydro storage (PHS) slightly.
• We decreased pumping costs to increase use of PHS but overall production costs increased.
• We added a 100 MW PHS in Arizona and gave it perfect foresight of when to pump and generate. At high penetrations, value and use of storage increases, but not enough to justify costs.
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You need to better utilize existing transmission
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• Absolutely need some intra-state transmission to bring resources to load.
• Very little operational difference between the 3 geographic scenarios.
• Wind/solar displace other generation, freeing transmission capacity. If this new capacity can be used for wind/solar, then less new transmission is needed.
• Assuming better utilization of existing transmission, we could start integrating up to the medium renewables case before new interstate transmission is commissioned.
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It is operationally feasible for WestConnect to accommodate 30% wind and 5% solar if:
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• Substantially increase balancing area cooperation• Increase use of subhourly scheduling• Increase utilization of transmission.• Enable coordinated commitment and dispatch over wider regions.• Use forecasts in operations.• Increase flexibility of dispatchable generation.
Source: DOE
• Commit additional operating reserves as appropriate.
• Implement/expand demand response programs.
• Require wind to provide down reserves.
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This is but one piece of the puzzle.
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Integration StudyHourly production modelOperational FeasibilityVariable CostCapacity Value
Transmission PlanningN-1 contingencysecurity
Dynamic StudiesFrequency Response
AC AnalysisVoltageLine lossesReactive power
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Thanks!
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• Study Team - GE Energy, 3TIER Group, SUNY/CPR, Exeter Associates, Northern Arizona University, NREL
• Technical Review Committee• WestConnect• U.S. DOE• For full report or Executive Summary:
http://www.nrel.gov/wwsis
Photos and figures credit: Western Wind and Solar Integration Study: http://www.nrel.gov/wind/systemsintegration/pdfs/2010/wwsis_final_report.pdf and Western Wind and Solar Integration Study: Executive Summary: http://www.nrel.gov/wind/systemsintegration/pdfs/2010/wwsis_executive_summary.pdf.
Cover slide photos: PIX 25996, 08604, 10927, and 14898 (from left to right).