energy center state utility forecasting group (sufg) alternative resources and energy capacity...
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ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Alternative Resources and Energy Capacity
Presented by:Douglas J. GothamPurdue University
Presented to:Institute of Public Utilities
56th Annual Regulatory Studies Program
August 12, 2014
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Main Presentation Topics
• Current status of renewable resource development
• Estimating capacity credits for variable resources using probabilistic methods
• Thermal system operating considerations• Optimal and least-cost capacity expansion
paths
2
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
3Source: EERE/WPA 2013
U.S. led global growth in wind power with over 13 GW added in 2012. The 60 GW total installed capacity ranks 2nd to China’s 75 GW.
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
4
Wind Penetration in US States (Capacity)
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Wind Penetration in US States
Source: AWEA 2012 5
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
6
US Wind Capacity Growth Slowed Down substantially in 2013
Source: EERE/WINDexchange
Headwinds against future growth include
• Lack of clarity about federal tax incentives
• Low natural gas prices
• Modest electricity demand growth
• Limited near term demand from state RPSs
• Growing competition from solar in some regions
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
7
United States Wind Resource Map (80 meter)
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
US PV Solar Resource Map
8
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
US PV Installations
9
Source: SEIA
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Global PV Market
10
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
US CSP Installations
11
Source: SEIA, NREL
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
12Source: DSIRE
Renewable Portfolio StandardsMarch 2013
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Intermittency
• All generators have some amount of uncertainty when it comes to availability– Mechanical failure– Environmental factors
• Some renewable resources experience this problem on a far greater scale
13
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Intermittency Problems
• Operational– Low output + high demand– High output + low demand– Rapid change in output
• Scheduling– Unit commitment– Gas purchase
• Planning14
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
121 2 543 6 7 98 1110 18 2019 2322 242113 14 16 1715
Hour of the Day
Lo
ad (
MW
)
Max Load
Min Load
WindProduction
Source: Veselka (Argonne National Laboratory)
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Intermittency in Planning
• Amount– How much power will the intermittent
resource produce when it is needed most?• Type
– How will the intermittent resource impact the appropriate mix of resources?
16
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
• Load and wind generation exhibit a strong negative correlation, with the negative correlation being stronger during the summer months
0
50
100
150
200
250
300
350
0
2,000
4,000
6,000
8,000
10,000
12,000
14,000
16,000
1 3 5 7 9 11 13 15 17 19 21 23
MW
MW
Hour
2004-2006 Hourly Average Load and Wind
Average LoadAverage Wind
Load and Wind Patterns
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Load and Solar Patterns• Solar power is also intermittent, but is
more predictable than wind– “Forecast for tonight – dark” – George
Carlin– Cloud cover can introduce short-term
variations in output• Solar power is positively correlated with
load– Solar intensity tends to be greater in the
summer 18
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Capacity Value of Intermittent Generation
• Rule of thumb method– Simple and easy to understand– There is no standard approach and little to
no scientific basis for value– May not account for geographic variability
of load and resource
19
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Capacity Value of Intermittent Generation
• Historical availability– Use the percentage of full output that is
available when the system peak demand occurs
– Accounts for local factors– Large variations from year to year– Small sample size of historical
observations
20
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
MISO Wind Availability on Peak (% of Nameplate)
Summer Availability Capacity Credit
2005 11.5%
2006 56.0% 20%
2007 2.1% 20%
2008 12.4% 20%
2009 1.5% 20%
2010 21.6% 8%
2011 44.2% 12.9%
2012 9.8% 14.7%
2013 52.6% 13.3%
2014 14.1%21
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Indiana Wind PPA Simulated Availability on Peak
22
Date of Annual Peak Demand
Peak Load (MW)
Wind Generation (MW) *
Wind Output as % of Wind Capacity
8/3/2004 19,201 57 7.4%
8/3/2005 20,065 174 22.6%
7/31/2006 20,791 231 30.0%
* Wind generation is based on simulated output from NREL data for appropriate locations of Indiana utility PPAs at the time of the study (770MW)
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
23
1 1 2 2 3 3 4 4 5 5 6 6 7 7 8 8 9 9 1010111112121313141415151616171718181919202021212222232324240
5,000
10,000
15,000
20,000
25,000
0
50
100
150
200
250
300
350
400
450
500
Load and Load Net of WindAnnual Peak 8/3/04
Load
Load Net of Wind
Day Hour
Lo
ad (
MW
)
Win
d O
utp
ut
(MW
)
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Capacity Value of Intermittent Generation
• Effective Load Carrying Capability– The amount of new load that can be added
with a given amount of new generation while maintaining a constant loss of load probability
– MISO uses this method to determine the capacity credit shown earlier
24
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Loss of Load Probability• aka - loss of load expectation
– given an expected demand for electricity and a given set of supply resources with assumed outage rates, what is the likelihood that the supply will not be able to meet the demand?
• Generally used to meet a minimum standard, such as 1 day in 10 years– or about 0.000274
25
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
All Power Generators Experience Outages Some Outages Such as Maintenance Schedules Are Planned
0
5,000
10,000
15,000
20,000
25,000
30,000
35,000
40,000
45,000
50,000
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
On-Line Capacity (MW)
Planned Outages Forced Outages On-Line Capacity Load
Total System Capacity
Resulting Reserve Margin
PlannedOutages
Source: Veselka
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
All Power Generators Experience Outages
Due to Mechanical Problems Some Outages Are not Known in Advance
0
5,000
10,000
15,000
20,000
25,000
30,000
35,000
40,000
45,000
50,000
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Load andOn-Line Capacity
(MW)
Planned & Maintenance Outages Forced Outages On-Line Capacity Load
Total System Capacity
Source: Veselka
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Intermittent Resources in a LOLP• It is not as simple as adding another
generator• A wind or PV generator will often operate
at a level lower than full capacity– Rather than two states (on/off), there is a
distribution of possible states• fossil-fueled generators may have multiple states
as well (partial outages, de-rates)
– That distribution differs at various times of the day or year 28
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Wind Probability Profiles Should Be Used When Constructing “with Wind” Resultant Load Probability Curves
0
10
20
30
40
50
60
70
80
90
0 25 50 75 100Exceedance Probability (%)
Ge
ne
rati
on
(M
Wh
)
February - 4 AMFebruary - 6 PMAugust - 4 AMAugust - 6 PMAll Hours of Year
Exceedance Probability (%)
Win
d P
rod
uct
ion
(M
W)
Summer Nighttime Wind Is Less Than Daytime Wind
Winter Wind Is Greater Than Summer Wind
Source: Veselka
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Simulation of Intermittent Output
• Rather than calculate the LOLP analytically, it can be estimated using a Monte Carlo simulation– Simulate the state of each generator
(including wind output level) using multiple random draws
– In many cases, the sufficiency of historical data may affect the accuracy of the probability distribution of intermittent resources 30
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Impact of Intermittency on Type of Resources Needed
• One approach is to use a load duration curve and load duration curve net of wind (or solar)
• Apply a break-even cost curve to the load duration curve net of wind
31
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
hr4
hr 17
121 2 543 6 7 98 1110 18 2019 2322 242113 14 16 1715
Sort Order (Highest to Lowest)
Lo
ad (
MW
)
Max Load
Min Load
Time
Lo
ad
Some Information Is Lost Such as Load Changes Over Time
hr17
hr4
Source: Veselka
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
NGCC
GT
Cycling Coal
Base Load Coal
Nuclear
0 100Exceedance Probability (%)
Lo
ad (
MW
)
Max LoadIs NeverExceeded
Time
Lo
ad
Min LoadIs Always Exceeded
Information Such as Unit Ramping and Frequency of Unit Starts/Stops Are Lost
Source: Veselka
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
121 2 543 6 7 98 1110 18 2019 2322 242113 14 16 1715
Hour of the Day
Lo
ad/W
ind
Ou
tpu
t (M
W)
Max Load
Min Load
WindGeneration
Source: Veselka
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
121 2 543 6 7 98 1110 18 2019 2322 242113 14 16 1715
Hour of the Day
Lo
ad (
MW
)
New Max
New Min
Wind Typically Increases Resultant Load Changes
Resultant Load
Source: Veselka
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
NGCC
GT
Cycling Coal
Nuclear
Base Load Coal
LowestO&M Costs
HighestO&M Costs
121 2 543 6 7 98 1110 18 2019 2322 242113 14 16 1715
Hour of the Day
Lo
ad (
MW
) Without Wind
With Wind
Coal May OperateLess Efficiently @ Min Gen
Faster & Often MoreRamping of Thermal Units
Unit Dispatch with Wind Results in Less Thermal Generation & Associated Air Emissions
Source: Veselka
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
NGCC
GT
Cycling Coal
Base Load Coal
121 2 543 6 7 98 1110 18 2019 2322 242113 14 16 1715
Hour of the Day
Lo
ad (
MW
)
Min Load
NuclearForcedOut ofService
Some Units May Be Stopped & RestartedRevise Unit Commitments
When Base Load Units Are Forced Out-of-Service, It Can Potentially Cause Problems with Technical Minimums at Some Units
Source: Veselka
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
An
nu
aliz
ed C
ost
($/
MW
-yr)
0 100
GT NGCC Coal
Capacity Factor (%)
GT 0-7%NGCC7-40%
Coal40-85%
Nuclear
Nuclear85-100%
Levelized Capital + Fixed O&M
A Simple Screening Curve Reveals Technology Niches
Source: Veselka
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Lev
eliz
ed C
ost
($)
Capacity Factor (%)
0 100
GT NGCC Coal Nuclear
1000 Exceedance Probability (%)
No
rmal
ized
Lo
ad (
%)
Nuclear
Coal
NGCC
GT
100
Combining Screening Curves with the Load Duration Curve Approximates the “Ideal” Capacity Mix Source: Veselka
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Lev
eliz
ed C
ost
($)
Capacity Factor (%)
0 100
GT NGCC Coal Nuclear
1000
No
rmal
ized
Lo
ad (
%)
Nuclear
Coal
NGCC
GT
Exceedance Probability (%)
Without Wind
With Wind
100
Expansion Mix Is Affected by Introducing a Variable Supply Resource Source: Veselka
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
SUFG Study
• SUFG looked at the impact of various levels of wind penetration on resource needs for Indiana
41
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Data Sources• Indiana statewide hourly load for 2004-
2006• NREL wind speed estimates for 2004-
2006, using locations from which Indiana utilities are currently purchasing wind power– No Indiana utilities were purchasing wind
power during that period, but it does maintain the chronological relationship between wind and load 42
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Costs for New GenerationType Annualized Fixed Cost
(2010 $/MW/Yr)Variable Cost(2010 $/MWh)
PC 542,277 25.34
CC 170,100 37.66
CT 110,353 62.26
Wind 403,430 0.00
43
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Effect of Natural Gas Prices
• Projected natural gas prices were low enough that coal units are not cost competitive at any capacity factor
• Natural gas combined cycle are used to meet both baseload and intermediate needs
44
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Load Duration Curve +
Break-even Cost Curve w/ Low NG
Prices
45
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Additional Resource Requirements (MW)
46
0 MW Wind 1,000 MW Wind 3,000 MW Wind 6,000 MW Wind
CC 875 500 0 0
CT 5,769 5,873 6,016 5,586
Total 6,644 6,373 6,016 5,586
The first 1,000 MW of wind has a capacity value of 271 MW (27.1%), the next 2,000 MW has a capacity value of 357 MW (17.9%), and the last 3,000 MW has a capacity value of 430 MW (14.3%).
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
New Capacity Requirements
47
0 1000 2000 3000 4000 5000 6000
-1,000
0
1,000
2,000
3,000
4,000
5,000
6,000
7,000
8,000
CT CC PC Total
Wind Capacity (MW)
Cap
acit
y (M
W)
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
As Wind Penetration Increases….
• Baseload/cycling resource requirements decrease
• Peaking resource requirements increase (until existing cycling resources start being used as peakers)
• Total resource requirements decrease at a declining rate
48
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Solar Impacts
• Unlike wind, solar output is generally positively correlated with demand– both are higher during the day– bright sunshine can increase demand
• Solar usually decreases the need for peaking resources and has less impact on baseload/cycling needs
49
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
The Duck Curve
50Source: California ISO DR-EE Roadmap
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Energy Storage and Demand Response
• Both storage and DR tend to shift demand from peak periods to off-peak periods
• Decreases need for peaking/cycling resources
• Increases need for baseload resources• Total resource requirements decrease
51
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
Energy Efficiency
• Energy efficiency impacts tend to vary depending on the particular end use affected– lighting programs impact mornings and
evenings more than daylight and middle of the night hours
– LED traffic lights operate at all hours
52
ENERGY CENTERState Utility Forecasting Group (SUFG)
ENERGY CENTERState Utility Forecasting Group (SUFG)
53
Further Information
• Doug Gotham– 765-494-0851– [email protected]
• http://www.purdue.edu/discoverypark/energy/SUFG/