Into the unknown: evaluating drivers of low- carbon ...
Transcript of Into the unknown: evaluating drivers of low- carbon ...
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Into the unknown: evaluating drivers of low-carbon investment in a subsidy free world
17 October 2018
Cornwall insight
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Setting the scene
17 October 2018
Gareth Miller
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Who we are
CONSULTING
ANALYSIS
RESEARCH
TRAINING
Pre-eminent providers of
market, regulatory, and
policy research, analysis,
training and consulting
Independent experts
across borders and
markets
Trusted by customers for
our unrivalled insight
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Our customers
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2005 2010 2012 2016 2017
Company founded:- Nigel Cornwall
Unrivalled coverage- Regulation- Policy- Market
Intelligence
Full service offering:- Subscriptions- Financial
models- Consulting- Training
Growing customer base:- 300+
Secured investment:- Business
Growth Fund & Opens Irish business
Cornwall Insight’s journey
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2014 2015 2016 2017
CPS frozenBiomass conversion RO grandfathering diluted
RO bands and Onshore wind and Solar<5MW RO closureCPS freeze extended
CfD AR2 excludes solar & onshore wind & new CfD auctions for less-established only
New accounting controls for low carbon “freeze”
Your journey…
No subsidy for onshore wind Solar >5MW RO closure LECs removed
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What is subsidy free?
• It is clear that as we stand many renewable technologies are being asked to invest on a subsidy free model
• And to meet our targets the will need to succeed
• But what does subsidy free mean?
o Is it no government support or consumer levy funding at any time for a project?
o Or, is it a neutral cost position for the government or consumer over the whole life of a project?
• We would argue for the latter, even if some in government , and particularly treasury interpret it as the former in way cost controls designed
• Later we unpack a powerful model to split the difference and deliver scale deployment
• But the question remains, without new government policy now, can subsidy free actually be delivered?
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Investment is fallingRenewable energy investment, UK 2005-18 ($bn)
Annual investment lower than anytime this decade with recent spikes driven by “gold-rush” of subsidy closures
From hereon likely to be lumpy and driven by commissioning dates of large offshore projects, and lower volumes of subsidy-free
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Shaky investor attraction to the UK
Source: Renewable Energy Country Attractiveness Index, EY
Steady investment confidence under a stable regulatory environment – RO, ssFiTs, EMR white paper and prospect of change creating wobbles
The repeated incursions against renewable support schemes drives lower investor attractiveness
Attractiveness bounces back – thanks to talking up the investment potential in subsidy-free. But is it real!
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Yet we must build more…Waterfall of capacity 2018-2050
Source: National Grid FES, Two Degrees, Cornwall Insight
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New build pipeline not enough
2.72.1
0.8
16.1
7.2
0.0
2.0
4.0
6.0
8.0
10.0
12.0
14.0
16.0
18.0
Capacity in planning
GW
s
Technology
Fuelled Solar Photovoltaics Tidal Barrage and Tidal Stream Wind Offshore Wind Onshore
Current renewables planning pipeline
Source: Renewable Energy Planning Database October 2018
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Existing projects will lose support
Roll-off of subsidy for current fleet
Source: Cornwall Insight, 2018
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10
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30
40
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60
GW
RO Subsidised FIT Subsidised CFD Subsidised
CFD Forecast New Subsidy RO Subsidy Ended FIT Subsidy Ended
CFD Subsidy Ended Total Subisidies Total Subsidy Ended
Peak subsidy in 2026 Over 45GW of existing without subsidy by 2040
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And will need to be replaced…Projects within their useful 25 year asset life 2002-2039
Source: Cornwall Insight, 2018
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GW
Onshore wind Offshore wind Solar PV Nuclear Biomass Hydro EfW ACT Wave and tidal Micro CHP
Over 53GWs of renewable assets may need to be rebuilt/repowered to recover the peak
Peak operating capacity within useful asset-life
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Today we will try to answer that question!
How will we meet the challenge?
Time Topic Speaker
14:10 Wholesale prices: trends, cannibalisation and impacts on project performance
Mike Mahoney
14:40 PPA market and investment underwriting in a subsidy free world
Ben Hall
15:10 Alternative sources of return – upside and downside
Tom Palmer
15:40 Break
16:00 Small is beautiful – workable options for the post FiT world
James Brabben
16:25 The case for floor price CfDs Gareth Miller
16:50 Q&A Ben Hall
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Do you think it is possible to meet our 2050 targets on the current subsidy-free status quo policy?
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Wholesale prices: trends, cannibalisation & impacts on project performance
17 October 2018
Mike Mahoney
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Price cannibalisation“The depressive influence on the wholesale electricity price at times of high output from intermittent, weather-driven generation such as solar, onshore and offshore wind”Cornwall Insight
“The more the wind blows and the sun shines and demand is saturated, the greater decline in prices on wholesale markets.” Foresight DK
“During windy hours…the excess supply of renewable based electricity depresses the power price, this is precisely when renewables generate the most energy, disproportionately earning low prices”Lion Hearth
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Subsidy adjusted merit order
-200
-150
-100
-50
0
50
100
0 10 20 30 40 50 60 70 80 90
SR
MC
-£/
MW
h
Cumulative nameplate capacity - GW
Emissions
Gas
Coal
Biomass
ROC
CFD
Short Run Marginal Cost
Source: Cornwall Insight
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Price cannibalisation in action
0.00
10.00
20.00
30.00
40.00
50.00
60.00
70.00
80.00
£ M
Wh
Day-ahead auction prices
11-Jun 12-Jun 13-Jun 14-Jun
11-Jun, base £53.55MWh, Wind 12%12-Jun base £53.33MWh, Wind 11%13-Jun, base £53.24MWh, Wind 21%
14-Jun, base £47.12MWh, Wind 42%
Source: N2EX, Cornwall Insight
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40.00
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50.00
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60.00
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0 5 10 15 20 25 30 35 40 45
Val
ue fa
ctor
Percentage market share of generation
Value factor of wind power 2018 to date Day-ahead auction prices for 2018
show strong correlation with
wind power production
Cannibalisation effect markedly
greater with wind above 30% of the
mix
Short term conditions such as
extreme cold weather can create premium for wind
power
Value factor - variation to base load
Source: N2EX Cornwall Insight
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Distribution of wind penetration
0
5
10
15
20
25
0.0% 20.0% 40.0% 60.0% 80.0% 100.0% 120.0%
Day
s
Percentage of generation mix
Number of days renewable generation makes up X% demand
2019
2025
2050
Source: Cornwall Insight
2019: Wind power at 20% or more on half of all days
2025: Wind power at 33% or more on half of all days
2050: Wind power at 54% or more on half of all days
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Future cannibalisation impact
60%
70%
80%
90%
100%
110%
2019
2020
2021
2022
2023
2024
2025
2026
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2028
2029
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2031
2032
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Bas
eloa
d pr
ice
capt
ure
Solar
Average P05/95
60%
70%
80%
90%
100%
110%
2019
2020
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Bas
eloa
d pr
ice
capt
ure
Wind
Average P05/95
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0
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£MW
h
Forward curves - baseload power
Change Curve 30/03 Curve 28/09
• Rising since 2016
• Pace quickened spring 2018
Prices rising
steadily
• Extreme cold depleted gas stocks
• Wind ‘drought’• Nuclear
outages
Gas supply issues
• European prices chasing Asia
• Coal back in merit
• Carbon
Gas demand in Asia
Wholesale markets
Source: ICE, Cornwall Insight
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Is there a role for carbon?
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-18
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Carbon pricing (nominal)
€/t EUETS £/t CPS £/t Carbon
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2/1/18 2/2/18 2/3/18 2/4/18 2/5/18 2/6/18 2/7/18 2/8/18 2/9/18 2/10/18
EU ETS Carbon v Brent Crude price index
Brent Crude EU ETSSource: Cornwall Insight
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What will treasury do with the carbon price support in the upcoming budget in November?
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Future capture prices
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2018/19 2019/20 2020/21 2021/22 2022/23 2023/24
£MW
h
Solar capture prices
Solar (April) Solar (October)
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25
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55
2018/19 2019/20 2020/21 2021/22 2022/23 2023/24 2024/25
£MW
h
Wind capture prices
Wind (April) Wind (October)Source: Cornwall Insight
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Wholesale value
Source: Cornwall InsightDelivery Balancing Mechanism
Intra-day trading
Day-ahead Auction
Seasonal contractsCapacity Market T-1
Capacity Market T-4Floor pricing
Corporate PPA
Forwards Market
Years 5-15Mid & Long term PPA
Short term PPA
Higher risk/shape discounts
Low value floor prices, partial volumes
Steep de-rating expected
Lower risk/shape premiums
Fixed prices
Off-taker competition
High value, high risk , low utilisation
Third party trading, share of upside
Years 3-5
Year 1
Prompt
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Networks
Generation
Markets
Additional factors
Networks• Constraints in the BM adding
to volatility in SIP• ‘Western bootstrap’ allowing >
north to south flow• Interconnector capacity
growing more scope for export but also imports
Markets• Price coupling via EUPHEMIA
at day-ahead at risk from no-deal Brexit
• interconnector trading• falling liquidity• New products for flexibility
Supply• Capacity and subsidy for
nuclear power• increasingly efficient flexible
gas plat
GB Market• Major transition in
progress• Value in flexibility for
some, significant risk to others
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• Fossil fuel prices become progressively less influential, setting the marginal
price in fewer periods and renewables output grows
• First mover advantages for deployment to capture higher near-side prices
• Subsidised projects established as major proportion of the merit order and
remaining in situ into 2030s and holding a competitive advantage over
subsidy free projects
• Direction of market value heading closer towards delivery and flexibility.
Volatility is good for some but risky for others
Key take-aways
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PPA market and investment underwriting in a subsidy free world
Ben Hall
17 October 2018
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Current terms available from utilitiesLarge & growing renewables market
We calculate 23.5GW (~65% of market) is under some form of PPA
High liquidity & re-tendering Especially in short-term FiT and Roc
deals
New entry ~40 PPA providers with capacity, 20
offering long-term PPAs
Improved PPA pricing Competition and liquidity driving improved retention
for generators. Typically:• ~97% for solar; ~96% for wind
• 97% on Rocs; similar for embedded benefits
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Are these the best terms we will ever see in the PPA market?
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What comfort can the wholesale market give?
• Strong growth in wholesale power priceso But lack of liquidity post 12-18 monthso Difficult to fix prices for longer than 2-3 yearso Backwardation continues in the wholesale marketo Longer fix usually = larger discounts
35
45
55
65
75
85
Sep
17
Oct
17
Nov
17
Dec
17
Jan
18
Feb
18
Mar
18
Apr
18
May
18
Jun
18
Jul 1
8
Aug
18
Sep
18
£/M
Wh
Winter 18 Summer 19 Winter 19Summer 20 Winter 20
35
45
55
65
75
85
Day-ahead
Oct Nov Q418 W18 S19 W19 Ann Oct18
£/M
Wh
Last week Two weeks ago Last year
Seasonal power prices (baseload) Power forward curve
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Source: Cornwall Insight
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Stability through PPA floor prices?Previous structures
• Historically most lenders have requested a floor price, especially in Roc PPAs
• Less/ no requirement in FiT/ CfD• Hard floor • Some offtakers have the risk of wholesale prices dipping below now
Changing wholesale market: fewer offtakers have been willing to offer hard floors
Emerging structures• Floor design where the offtaker absorbs the reduction when wholesale
prices fall below the floor price and then recoups these loses when wholesale prices rise back above it
• Currently offered floor prices are £10-20/MWh, if offered at all
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• Most popular structure in GB aka sleeving– common for subsidised CPPAs
• PPA between corporate and generator
• Back-to-back PPA with corporate and supplier
• Generator transfers electricity to supplier who sleeves to end user sites
CPPAs – direct structureGenerator CorporateSupplier
PPA price agreed
Power and certificates
Power (and certificates)
Potentialsleeving fee
Potentialsleeving fee
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Source: Cornwall Insight
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• AKA synthetic PPA• PPA between generator and supplier• Supply contract between corporate and supplier• Price guarantee agreement between generator and corporate• Can be packaged to more than one corporate
CPPAs – indirect structure
Generator CorporateSupplier
Price guarantee instead of PPA
Back to back PPA and supply contract for supplier
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Source: Cornwall Insight
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Who are the buyers?
Today 2020 2030 2040Long-term
commitments
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Corporate/ buyerDrivers of interest in CPPAs
Developer/generator
Removal and reduction of subsidies
Bankability/creditworthy
counterparties
Lower cost of capital and
levelised costs
Long term route to market
Lack of forward liquidity to provide fixed price long-
term certainty
Meet/match demand requirements
No upfront capital
requirements
Long-term wholesale
price certainty/ hedges
against price volatility
Internal/public renewables/ low-carbon
targets
Corporate social
responsibilityEstablished project finance
markets
Government-led targets
Success of CPPAs in other markets (e.g.
US)
Experience of developers/utilities
is growing
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Source: Cornwall Insight
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Developer/ generator Corporate/ buyer
Complexities and issues
Creditworthiness of offtaker becomes even
more important if subsidy free
More complex to negotiate and
likely to take more time
Fairly limited pool
of corporates
– but increasing
CPPA may create 100% of revenue
Board appetite for the deal
Unlikely to agree to pay more in the short-term for long-term certainty
Not core business – Lack of knowledge and expertise in closing the contract
Security may be required e.g. a direct agreement
Contract termination costs
Still requires a supplier for top-up, spill and registering of metes
for settlement
Power offtake not core for
corporates
Complexity and costs associated
Pricing is heavily dependent on forward curve/ forecasts of prices
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Source: Cornwall Insight
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What do you think is the biggest barrier to more CPPAs?
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2008 2008-17 2017 2018-19 2020
First CPPA signed • Sainsbury’s 10-
year agreement with Lochhead wind farm
CPPA market breaches 400MW • ~2% of
total PPA market
First subsidy free solar farm• Anesco
project co-located with batteries
First subsidy free wind farms• EnergieKontor
wind projects –England (and potentially Scotland)
Furtherdevelopments?• Vattenfall
South Kyle• Hive
Hampshire/ Kent
UK CPPA and subsidy free
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European subsidy free• Överturingen – 235MW in Sweden
o GIG recently reached financial close o 29 year CPPA with Norsk Hydro, an
aluminium producero Some limited subsidy
• Vattenfall Dutch offshore wind by 2022o Hollandse Kust Zuid – 750MWo “Is profitable with our view on
market prices and market price development”
• Other European comparisons o German “subsidy-free” offshore
wind by 2024-25, but with grid connections provided for by German government and ready-defined sites
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Source: Cornwall Insight
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Key take-aways
• The wholesale market is currently buoyant and the utility PPA market is at its most competitive
o PPA fees at all-time low
• Despite this, investments in subsidy free projects are challenging
o Lack of stability/ certainty in forward prices – utility PPA market is not providing this
o Levelised costs too high for many investments for merchant only projects
o Network charging review adds to the uncertainty
• CPPAs can provide some stability but there is a lack of liquidity and contract negotiation is complex/ time consuming
• Other subsidy free developments are very site-specific
o Other revenue sources, “cheaper” network access, PoC schemes
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Alternative sources of return – upside and downside
Tom Palmer
17 October 2018
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• In the absence of any subsidies, assets with need to stack and jump between elements if better opportunities exists
• Will be competing and locating with flexibility assets and likely to result in sharing connection / infrastructure / O&M or portfolio management virtually
It used to be so simple
Wholesale Market
Subsidy
Markets in transformation
Capacity Market
Balancing Market
Wholesale Market
Balancing Services
Other
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Source: Cornwall Insight
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• Renewables with subsidies were unable to participate in the Capacity Market o Not compliant with state aid rules
• No de-rating factors for wind and solar in practice means its not possible to participate
• Hydro (excluding tidal / waves / ocean currents/ geothermal) and biomass have been able to participate
• This is despite the objective of the CfD to lead to ‘return to market investment’ renewables
Though shall not enter
Why not try?
Glen Kyllachy Wind Farm owned by Innogy registered
for 2021/22 delivery year
48MW site initially registered as Hydro before finally being
rejected
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• Government held its 5 year review into the Capacity Market
• Renewable involvement identified as a priority
• Likely to be in 2018 auction (delivery for 2023/24
Well that was quick
Historically had low carbon support schemes – CfD, RO, FiT, FiDER
Assumed to participate once Renewable Obligation support ended
Contribution of solar to Security of Supply?
Development costs for projects decreased quicker than expected
New Routes to market – Corporate PPA and subsidy free PPAs
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Source: Cornwall Insight
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• All other assets that participate in the Capacity Market are dispatchable and controllable with the exception of Interconnectors
• Responding to a Capacity Market event is not possible, but may still deliver in periods of stress
• Desire to focus on wind and hybrid sites, potentially solar
This is all new for me
Review de-ratings for solar and wind
How to treat hybrid projects
Penalty Regime
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• Officially no de-rating for wind and solar
• Winter Outlook suggested a de-rating of around 17% for wind
• Experience from Ireland and others suggest o Solar – 5.5%o Wind – 10.3%
• May impact the returns for East-West facing solar panels
There when I needed you
Source: Cornwall Insight
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• Increasing number of sites will not be purely a renewable deployment, understanding the need for flexibility to support deployment
• Hedge against the uncertainty in revenue volatility
• Increasing interaction with o Storageo Gas reciprocatingo Other renewableso EV charging
Let’s get physical?
Uncertainty in renewable generation
Exposure to system
imbalance price
Meet end user shape
Revenue diversification
(cannibalisation)
Contracted revenues
Capture locational benefits
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• Identified concerns on the penalty regime – limited penalty
• Concerns penalties are insufficiento Increased form of penalties likely
to be punitive to renewableso Potentially linked to Value of Lost
Load (VOLL)
• Would require further development of secondary trading market – only 145MW of assets in 2018 delivery year
Paying the penalty
Penalties
All capacity providers holding an agreement must deliver
sufficient electricity during a stress event to meet their
obligation or pay a penalty.
The penalty rate (on a MWh basis) is set at 1/24th of a
provider’s annual capacity payments and capped at 200%
of its monthly capacity payments and 100% of its annual capacity payments.
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• Will capacity market prices be worth it to justify entry
• Rewards will be minor, but nonetheless meaningful over the lifetime
• Importance of being contracted revenues for debt
• Real value will be determined by the change in penalty scheme
Enough Value?
Estimated de-rating Value £/MWh
Onshore Wind 17% £0.35 to £1.32
Solar 5% £0.23 to £0.86
Source: Cornwall Insight
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• Balancing Services are going through significant reform under System Needs and Product Strategy (SNaPS)
• Opening up existing market previously occupied by large thermal assets – now storage, reciprocating engines and DSR
• Solar and wind only really provided intertrip arrangements with National Grid in South West Scotland
• Subsidy free – provides greater flexibility to participate and more competitive with other forms of generation
Managing the system
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The art of the possible?
System Needs and Products Strategy
InertiaFrequency Response
Reserve Reactive Black start
NoYes, but limited
No Yes Maybe
Enablers• Power electronics• Hybridisation• Location
Limitations• Flexible generation• Market size• Location
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Source: Cornwall Insight
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• Currenltly no wind participates in any of the Balancing Services competitive markets as lack of certainty
• Desire for high only response (reducing output) in Balancing Services
• Increased opportunity if able to integrate hybrid / co-located solution
• Future emissions target in Balancing Services?
Competitive?
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• National Grid uses to balance electricity supply and demand close to real time
• Not new - traditionally 100MW in E&W; 30MW in South Scotland; and 5-10MW in north Scotland
• The Balancing Mechanism is not new for wind, but solar has not participated to date
• However, predominantly taken to manage regional constraints through system actions rather than energy actions
Matching supply and demand
0
2,000,000
4,000,000
6,000,000
8,000,000
10,000,000
12,000,000
14,000,000
16,000,000
18,000,000
20,000,000
Tota
l val
ue (£
)
Bid Value Offer Value
Value of BM actions by technology
Source: Cornwall Insight
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• Project TERRE (Trans European Replacement Reserve Exchange) will create a platform for the sharing of Replacement Reserves between TSOs via P344
• Create new entities that will allow small assets connected to distribution network and demand Side response to provide flexibility
• Solar and wind will likely still find it tough to competeo Thermal assets normally pay
to reduce their generation
TERREing up the rulebook
Source: Cornwall Insight
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Key take-aways
• None of the alternative revenue streams are easily accessible for assets that are not dispatchable
• Experience from flexibility market makes it clear these markets are complex and highly competitive so not clear if subsidy free has much of a role
• Potential need for Power Purchase Agreement for subsidy free to be flexible enough to optimise the assets in different market, but again not straightforward
• These other forms of revenue could bring in some contracted revenues that improve the ability to bring in debt, although likely to be time limited and minimal
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Sli.do
Is it economically viable for an onshore wind farm to secure investment on merchant wholesale revenues, capacity market and balancing services?
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Small is beautiful
17 October 2018
James Brabben
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The FiT scheme cycle
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200
400
600
800
1000
1200
1400
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MW
Photovoltaic Wind Anaerobic digestion Hydro Micro CHP
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talla
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usan
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Photovoltaic Wind Hydro Anaerobic digestion Micro CHP Average Solar Tariff
Lift off “Let’s see how this goes”
Manage“We need to control costs”
Cap and manage“We need to control costs…. More!”
Annual capacity uptake
Installations
Source: Cornwall Insight
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Closure and impacts
FiT
31 March 2019 closure date announced by BEIS. Removal of generation tariffs and export tariffs to new sites
BEIS suggest a guaranteed route to market may be developed… but only if they lower bills
An already distressed supply chain could suffer
a further slow down
Pipeline projects may now be halted or re-assessed
until after BEIS announcements
Separate call for evidence on the future of low-carbon generation
Other technical adjustments announced including metered exports (above 30kW) being brought into levelisation process
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What now for small-scale developers?
“Go it alone” a.k.a build merchant• What price stability?• What PPA?
Co-locate• What battery price? • Can you arbitrage 500kW?• What degradation rate?
Behind the meter• Through one supplier? • What about TCR impacts?
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Subsidy free still in the distance
Source: Pixie Energy
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The cost and value of on-site solar PV (2018 and 2023)
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The case for a transitional offtake tariff
2019 2024
• 10-15 year agreements
• Same technologies as FiT but reduced thresholds (500kW for community, 250kW solar and 100kW for others)
• Continued MSC accreditation process
• Opt out of this arrangement – but never back in
• SIP reference price – banded pricing could incentivise deployment of load shifting and storage
• Supplier obligations above 250k – but SIP reference means no levelisation
• All output HH metered
End in 2024: • HH settlement to
have been implemented
• ToU tariffs widespread
• Aggregation and multi-supplier as mainstream
• Commercial storage
• Local flex markets
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Wider imperatives
“Removing barriers to smart technologies, including storage… enabling smart homes and businesses”
Is further small scale generation a missing link in implementing wider plans?
DSOs
Generation/ wholesale
Networks/ supply Consumers
Peer to peer
HH settlement
StorageMulti-supply
Local servicesRenewables penetration
Flex assets
System services
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1. FiT scheme has seen higher than expected uptake over its lifetime. But the scheme has been slowly winding down since changes in 2015
2. Scheme closure presents challenges for new developments. Price stability has been potentially removed and an already distressed supply chain needs buildable projects
3. We see the risks and complexities of merchant development, co-location and behind the meter as a barrier to development
4. BEIS’ guaranteed route to market option needs to be explored, as otherwise generation could stall
Key take-aways
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Sli.do
Do you think the small-scale (below 5MW) renewables market will develop without a guaranteed route to market?
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The case for a CfD floor
17 October 2018
Gareth Miller
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Over 9GWs of pent up onshore demand in the planning system awaiting support
Need to build/repower 100GWs+ of low carbon capacity to meet 2050
Traditional investment model relies on de-risking volatility to ensure repayment of debt
Utility and corporate PPAs unlikely to provide the “scalable” answer
Why revenue stabilization is needed?
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The “zero-subsidy” red-herringEven if computer models say LCOE trending lower than projected wholesale prices over lifetime showing positive NPV, policy support still required…
At same time wholesale power market volatility is increasing
And the direction of captured prices is
down, regardless of commodity value
Pool of investors capable of pricing volatility/merchant risk is very small and cost
of capital high
And lenders not interested in just total, but regular repayments – volatility matters
Comparisons to baseload wholesale prices misleading – captured prices are real
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Project finance the engine of growth
Source: Based on BNEF data provided by (OECD, 2016)
Global asset financing of new investment in renewable energy
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In particular for wind and solar
Source: Energy Economics Volume 69, January 2018, “The Importance of Project Finance for Renewable Energy Projects”. 341 projects (73%) out of 468 new power projects 2010-2015.
New power projects in Germany 2010-15, financing proportions
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Higher returns to equity from raising debt
Banks like stable cashflows resulting from stabilisationpolicies
Some utility balance sheets under pressure
Allows equity to be invested in
multiple projects/recylcing
Volume of pipeline in subsidized markets attractive
Why?
Technology maturation has reduced risks
BanksEquity investors
Drivers
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Revenue stabilization matters
Source: Energy Economics Volume 69, January 2018, “The Importance of Project Finance for Renewable Energy Projects”. 341 projects (73%) out of 468 new power projects 2010-2015.
German renewable financing sources by scaleGerman energy financing proportions by revenue
stabilisation
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Loan capital and interest is repaid bi-annually
Project cash-flows also tested bi annually
Needs to be both enough projected cash to repay the entire loan, and to comfortably repay fixed installments
So banks will lend less, at higher costs, or not at all
Hard to pin down where/when this will arise before making a loan
Volatility in wholesale prices creates risks of periods in which installments can’t be made
Low risk lenders want projects to regularly reduce loan through repayment
Why stabilisation is needed?
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Can PPAs provide it?
Committing to long term prices a challenge
Less easy/more complex to transact
Interested in scale and shape
Floors not insulated against change in law
Floor prices very low - £10-20/MWh
– and wont support debt to make
projects viable
Ability to fix prices 3-5 years, but not
whole term
Utility Corporate PPAs
And not all PPA providers will offer a floor
Buyers need strong credit rating
Only 400MWs to date signed up in GB (2% of PPA market)
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What is a CfD “floor”?
Source: Cornwall Insight
•When prices are below the floor the generator is topped up
Floor protection
•But when prices are above the floor the generator pays back fully what has been paid out before getting value
•After that there is “upside”
Rebate to the
consumer + Upside
How the “CfD floor” works in principle
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Date
Payback Top-UpN2Ex DaH Floor price
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Auctions and contracts
BEIS could cap floor price bids at levels they deem sufficient to drive viable projects
Bidders would bid floor prices into CfD auctions under existing “pay as clear” approach
The CfD contract settlement (and levy forecast) would be changed to accommodate “rebate” model
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Lower strike prices
• Upside means lower floors
• Developers will instead focus on the level of floor necessary to raise viable debt levels
No subsidy
• Low floors will fall under long-run wholesale power prices (c£30/Mwh)
• Rebate model means it is “working capital”
• No impact under low carbon levies
Attracts low cost of capital investors
• Removes revenue volatility
• Floor acts like the ROas guaranteedbankablerevenue
Delivers scale capacity
• Absence of subsidy cost means no financial limit to the scale of capacity that can be supported
Benefits of CfD floor
No material changes to CfD structure
BENEFITS
• Can be auctioned – people just bid floors not two way SPs
• CfD contract changes not extensive
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Focussing on life-time wholesale revenues versus LCOE is a fallacy
What matters is investor assessment of risks and what drives their decisions
Volatility in prices creates challenging risks for debt providers in particular
Debt has been the engine of growth in renewable deployment to date, allowing growth to be achieved at maximum scale and lowest cost
Stabilising price is required in a world of increasing wholesale power volatility
CfD floor structure removes the risk of volatility at zero cost to the consumer – driving the growth in low-cost capacity to meet targets
Key take-aways
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Q&A and conclusions
Ben Hall
17 October 2018
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www.cornwall-insight.com
Today’s Cornwall Insight presentersWho Role Contact
Gareth Miller Chief executive 01603 542101 [email protected]
Mike MahoneyHead of Wholesale & Modelling
01603 542143 [email protected]
Ben Hall Head of New Business 01603 542102 [email protected]
Tom Palmer Principal Consultant 01603 542103 [email protected]
James Brabben Head of Training 01603 542141 [email protected]
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www.cornwall-insight.comHELPING YOU MAKE SENSE OF THE ENERGY AND WATER SECTORSHELPING YOU MAKE SENSE OF THE ENERGY AND WATER SECTORS
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