cutter - e3 valuing storage short
TRANSCRIPT
Uncertainty and the Value of Energy Storage
Storage Week January 25, 2016
San Diego, CA
Eric Cutter
UTILITY VIEW
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$0
$50
$100
$150
$200
$250
$300
$350
Combustion Turbine(2014)
Leve
lized
$/k
W-Y
r
Fixed Cost$200
Net Rev-enue$63
Net Capac-ity Cost$137
Utility view of storage: a CT
Fitting storage into a “standard” capacity product undervalues storageBest value for ratepayers requires better matching of technologies the grid services
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aka “CONE”: Cost of New Entry
$0
$50
$100
$150
$200
$250
$300
$350
Flexible Capacity Product
Leve
lized
$/k
W-Y
r
Fixed Cost
Net Rev-enue
Net Ca-pacity Cost
Reducing cost of storage
Cost benchmarks that reflect future system needsForward looking flexibility value with high RPS
Operating experience and cost reductions for the storage needed in 2020
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FUTURE BENEFITS OF STORAGE
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Flexibility needed for high renewable penetration
Over-generation
is a new challenge in
solar-dominant
systems like CA
40% RPS Spring Day Generation
Profile
Grid benefits performed by flexible resources
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Net Market Value
Utilities evaluate storage based on net market valueUtility planning assumptions and models determine benefits
Today Tomorrow
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Challenges selling to utility
Not necessarily convinced they need storageUse traditional models and valuation frameworkFocus on costFocus on today’s marketsGetting multiple departments to sing in unisonLittle sense of urgency: wait and see approach
LOOKING AHEAD - WEST
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WECC Wide Flexibility Study
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Main zone:• Optimal investment decisions• Detailed treatment of operating
reservesOther zones:• Exogenous resource assumptions
and loads by scenarioFlows may be impacted by:• Min and max intertie flow
constraints• Min and max simultaneous flow
constraints for groups of interties• Ramping constraints on interties• Hurdle rates
Example zonal structure – High Renewable West Scenario
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California dispatch, average net load day in May
California Overgeneration Driven by Mid-day Solar Production
Gas fleet operates at minimum, subject to
min gen constraint
Renewable production from solar PV causes mid-day oversupply, leading
to curtailment
Significant imports during shoulder periods
Renewable Penetration: 50%(% of load)
Renewable Curtailment: 8.7%(% of annual renewables)
Curtailment Frequency: 20%(% of hours per year)
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Northwest dispatch, average net load day in May
Renewable Penetration: 30%(% of load)
Renewable Curtailment: 6.1%(% of annual renewables)
Curtailment Frequency: 10%(% of hours)
Northwest Overgeneration Results from Combined Hydro & Wind
Curtailment occurs throughout day but is most pronounced at night
(low loads & high wind)
Hydro energy accounts for significant shares of daily load
Significant exports during off-peak hours,
but limited during middle of day
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Southwest
Scale (MW)
0
7,000
Northwest
Scale (MW)
0
4,000HE01 HE24
JanFebMarAprMayJunJulAugSepOctNovDec
HE01 HE24JanFebMarAprMayJunJulAugSepOctNovDec
California
HE01 HE24JanFebMarAprMayJunJulAugSepOctNovDec
HE01 HE24JanFebMarAprMayJunJulAugSepOctNovDecTot: 8.7%
Scale (MW)
0
16,000
Tot: 3.0%
HE01 HE24JanFebMarAprMayJunJulAugSepOctNovDec
HE01 HE24JanFebMarAprMayJunJulAugSepOctNovDec
Regional Coordination is a Low-Hanging Fruit Among Solutions
Historical IntertieLimits
Physical IntertieLimits
Tot: 5.6% Tot: 2.0%
Tot: 7.3% Tot: 6.1%
Large reductions in nighttime curtailment
Large reductions in non-spring curtailment
Limited impact on curtailment
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Storage Downward Flexibility Reduces Curtailment
Addition of 6 GW of long-duration storage relieves curtailment
Addition of 6 GW of flexible CCGTs has little impact
Source: TEPPC Western Interconnection Flexibility Assessment 04 Nov 2015
LOOKING AHEAD - EAST
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Forward curves under energy policy uncertainty
Reference case represents best in class energy market and capacity market dispatch. Extension to scenario analysis approach describing key context and impact of policy on energy market identifies critical market disruptions
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Reference Case: Compliance with existing policy, with expected technology advancements
and cost reductions
High Renewables: Implement required renewables to hit
goal despite budget constraints. Increasing to 50% renewable
generation
REV Policy Case:Assuming successful policy
implementation and increased DER participation in energy markets.
Changing the load profile and load factor
$0
$20
$40
$60
$80
$100
$120
2008
2010
2012
2014
2016
2018
2020
2022
2024
2026
2028
2030
2032
2034
Ener
gy P
rice
($/M
Wh)
Year
HistoricalBusiness-as-usual
High Renewables
Long Island Baseload Energy Price ($/MWh)
Results show significant changes in market fundamentals depending on policy case and zone
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REV Background and Impact
The goal of the REV proceeding is to facilitate the deployment of distributed energy resources (DER), provide consumers with choice and value over their energy use, and improve system efficiencyDetails of how to these goals will be achieved are not finalized, but a successful REV program should improve system efficiencyTo assess wholesale impacts of distributed resources, we assume NYISO’s system load factor improves to 60% by 2030 (agnostic to technology)Details
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1 24
Load
(MW
)
Hour
Hourly Load Shape in 2030
Base load shape
REV load shapeFlatter due tovarious DER deployment
40%
45%
50%
55%
60%
65%
70%
75%
80%
1995
1997
1999
2001
2003
2005
2007
2009
2011
2013
2015
2017
2019
2021
2023
2025
2027
2029
Load
Fac
tor (
%)
Year
NYCA Annual Load Factor
Historical
BaseSystem efficiencycontinues to decline
REV ScenarioDER improvessystem efficiency
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0
1,000
2,000
3,000
4,000
5,000
6,000
BAU High RE REV
Sum
mer
Cap
abili
ty (M
W)
Scenario
New Gas Plant Investment by 2035
CT Gas
CC Gas
Investment Outlook for New Plants
Economics of new investment varies substantially across scenarios
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Technology BAU High RE REV
Combined Cycle High Low Medium
Combustion Turbine Medium Medium Low
Onshore Wind Medium High Medium
Offshore Wind Low High Low
Utility-scale Solar Low High Low
CC outlook poor due to depressed energy marketCTs still attractive in capacity market
DER impact on load shapereduces need for peaking plants
Summary of Investment Outlook
LOOKING AHEAD - HAWAII
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System Overview
Oahu MauiMolokaiHawaii
Energy Production by Type
Peak Load (MW) 193 6 1176 197.3Min Load (MW) 82 2 521 86.7Pmin+ Downward Reserve (MW) 61 1.8 277 46.98Intermittent RE Capacity ‘15 (MW) 111.8 1.7 420.1 134.3Preapproved DG PV (MW) 25 0.426 117.2 35
44% RE 8% RE 8% RE 32% RE
Island system constrained by Pmin & reserves
Determine whether the net load ever drops below Pmin + reserves• If so, normal system operations are
interruptedHow often do these events occur?What is the frequency and size of the problem?What are the potential solutions?
headroom
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Comparing Curtailment Cost to Battery Cost
2016
Curtailing renewables is cheaper than installing storage – using traditional evaluation framework
STORAGE VS. OTHER SOLUTIONS
Renewable integration solutions
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Various solutions have been proposed, with different performance characteristics and costs• Energy storage (pumped hydro, batteries,
compressed air, etc)• Flexible loads or advanced DR• Flexible gas resources (new flexible CCGTs,
Aero CTs, Reciprocating Engines or retrofits to existing plants)
• Expansion/consolidation of balancing areas• Time-of-use rates
Teslamotors.com
http://renews.biz/67193/vattenfall-pumps-new-life-into-80mw
Wartsila.com
http://allthingsd.com/files/2012/10/Nest-Cooling-2.jpg
http://www.theiet.org/membership/member-news/31a/ev-charging-course.cfm
Economics of renewable integration
The consequence of failing to supply enough flexibility to integrate renewables is renewable curtailment
Full capability from procured renewables
Delivered energy from procured renewables
Curtailment
Renewable energy target
Option 1. Overbuild renewables
Anticipated renewable build
Curtailment-related renewable overbuild
Option 1. Overbuild the renewable fleetOverbuilding the renewable fleet allows for policy goal to be met with some allowance for curtailment
Curtailment
Option 2. Pursue integration solutions
Option 2. Pursue integration solutionsIntegration solutions (eg. storage, balancing area consolidation) permit more effective delivery of existing renewable fleet
Energy Storage
Renewable build
Energy storage build
Option 3. Mix of solutions (Options 1 & 2)
Option 3. Find optimal solutionOptimal solution combines multiple strategies based on costs and benefits
Energy Storage
Curtailment
Energy storage build
Anticipated renewable build
Curtailment-related renewable overbuild
Option 3 is Optimal Solution Balances Storage with Overbuild
Optimal amount of storage is highly
sensitive to assumed technology costs
Identifying optimal investment in solutions
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Single solution case:• The cost of the solution can
be weighed against the avoided cost of overbuilding renewables for RPS compliance
Multiple solution case:• Multidimensional
optimization• Complex interactive effects• Requires sophisticated
model that treats both operations and investment costs
Optimal investment point:
Marginal avoided cost of renewable overbuild
=Marginal cost of solution
Example analysis:Optimal storage investment
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Wide uncertainty in future cost reductions
Wide range in optimal storage build
Base Assumption
Q. Given the wide range of potential future cost trajectories, what is the optimal amount of energy storage?RESOLVE: Storage cost scenarios can be designed to provide a plausible range of least-cost storage procurement strategies; can also:• Identify timing of storage build
across sensitivities• Test cost impacts of suboptimal
storage build
Storage technology costs ultimately determine the optimal energy storage investmentHigh level of uncertainty complicates the planning problem
STORAGE IN WORLD OF UNCERTAINTY - IDSM
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Capacity Value of Renewables Declines Significantly Above 33%
High penetration of solar PV pushes the “net peak” demand that must be met with dispatchable resources into evening hoursCalifornia will continue to need capacity resources to meet peak demands
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10
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Load
(GW
)
Hour
0
1
2
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0 6 12 18Pe
ak L
oad
Redu
ction
(GW
)
Installed Solar PV Capacity (GW)
Daily Load Shape with Increasing Solar PV Cumulative Peak Load Reduction
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Storage as Part of Optimal Portfolio
DescriptionCurrent situation
Key metrics13.5 MW:Current peak56,000 MWh:Energy5%/year:Load Growth
24 hr load profile
Year on year load profile
Base
Cas
e Fo
reca
st
Alternative future states
Upg
rade
ele
men
ts
DER 1Hardware DER 211 MW 8 MW 4 MWHardware
SolarDREEStorage
Key
met
rics
24 hr load profile
0 MW 1.6 MW 4.4 MW0 MW 3.3 MW 3.3 MW0 MW 1.6 MW 1.6 MW0 MW 0 MW 5 MW
Cash flow
24 hr load profile
Cash flow
24 hr load profile
Year on year load profile
Year on year load profile
Year on year load profile
Cash flow
High load growth in urban area where upgrades are expensive due to site constraints
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Storage Reduces Risk
Next gen solution
▪ Plan based on value of reliability and cost of upgrade
▪ Factor in forecast uncertainty into investment decision
IDSM ApproachCurrent solution
▪ Engineering studies to identify N-1 redundancy requirement
Identifying investment
▪ Choose from traditional T&D capital investment supply options
▪ Expand options to meet load growth and reliability needs to include DER
▪ Integrate DER and traditional investments in decision process
Investment options for maintaining reliability
Peak load served (MW)Sys
tem
ava
ilabi
lity
(% li
kelih
ood)
99.999%
Additional service from investment
Forecast Years
Pea
k Lo
ad (M
W) Forecast
uncertainty captured
subs
tatio
n
mod
ular
Inte
grat
ed
DE
R
Pre
sent
val
ue $
subs
tatio
n
mod
ular
Inte
grat
ed
DE
R
Exp
ecte
d ou
tage
$
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Conclusions for energy storage
Utilities feel little sense of urgency: have a wait and see approachTraditional models and valuation frameworks undervalue the flexibility that storage providesTo utilities regional coordination and renewable curtailment look like cheaper alternatives to storageLooking further ahead with stochastic, portfolio models is crucial to fully value storageNeed to show utilities that storage is part of an optimal portfolio in an uncertain world
Thank You!Energy and Environmental Economics, Inc. (E3)101 Montgomery Street, Suite 1600San Francisco, CA 94104Tel 415-391-5100Web: http://www.ethree.com
Eric Cutter ([email protected])