Onshore wind financing landscape in France and Germany 12 ... · • Amongst the 11.5 GW that will...
Transcript of Onshore wind financing landscape in France and Germany 12 ... · • Amongst the 11.5 GW that will...
Onshore wind financing landscape in France and Germany
12 November 2019
OFATE – DFBEW
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Active in 46 countries, including 18 in Europe
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• Strong and stable macroeconomic fundamentals, supportive political dynamics for renewable energy
• Three onshore wind regimes providing production diversity
• The recently enacted PPE aims at doubling the share of renewables in electricity generation to reach 40% by 2030
French onshore wind market
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Positive momentum for the French onshore wind sector
Ambitious political agenda for renewable energy
25.5 25.7 26.4 26.7
15.1 24.6 34.1 35.68.5
20.6
35.644.5
2.4
4.75.2
1.1
1.1
1.21.2
0
20
40
60
80
100
120
2018 2023e 2028e (low) 2028e (high)
Hydro Onshore wind Solar PV Offshore wind Other
Source: 2019-2028 Programmation Pluriannuelle de l’Energie (PPE) Source: CRE, Bundesnetzagentur
Strong market fundamentals for onshore wind
Planned renewables installed capacity increase (PPE)
65.4 66.9 63.0 66.5
0.00
20.00
40.00
60.00
-
200
400
600
800
1,000
Q1 2018 Q3 2018 Q2 2019 Q3 2019
French onshore wind tender results
MW bid MW awarded Average tariff (FR)
MWEUR/MWh
0
5
10
-
1
2
Q2 2
019
Q3 2
019
Q4 2
019
Q1 2
020
Q2 2
020
Q3 2
020
Q4 2
020
Q1 2
021
Q2 2
021
Q3 2
021
Q4 2
021
Q1 2
022
Q2 2
022
Q3 2
022
Q4 2
022
Q1 2
023
Q2 2
023
Q3 2
023
Q4 2
023
Q1 2
024
Q2 2
024
Q3 2
024
Q4 2
024
PPE onshore wind tendered capacity (GW)
Cumulative tendered capacity Tendered capacity
GW
Market premium
The operator receives a feed-in premium from EDF OA, calculated ex-post, topping-up the sale of electricity on the wholesalemarket or to an aggregator
French onshore wind market
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Since 2016, the contract for difference has replaced the feed-in-tariff support mechanism
The feed-in premium is calculated as
The sum of
• Market premium, difference
between the strike price and the
M0 (the monthly average of
market prices in the sector)
• Management premium,
compensation for the costs of
direct marketing
Less
• Capacity revenues (except for
projects under a tender CfD)
received separately to remunerate
the ability to generate electricity
during peak-demand periods
Capacity revenues
Management premium
Revenues
Strike price
Feed-in premium
Capacity revenues
Project revenues Feed-in premium calculation
+
-
Sources: Official decrees
M0Market revenues
0 50 100 150 200 250
TTR
Nordex
Boralex
Total Quadran
Volkswind
An avel braz
Valeco EnBW
WPD
H2AIR
RES
Valorem
Eurowatt
Vents du Nord
Nethys
JPEE
Escofi
Enertrag
Voltalia
EDPR
Neoen
David Energies
Akuo
WEB Energies
Epuron
VSB Energies Nouvelles
SE Haute-Vienne
Engie
Baywa r.e
ABO Wind
ENO Energy
EDF EN
French onshore wind tenders (MW)
#1 Q12018 #2 Q3 2018 #3 Q2 2019 #4 Q3 2019
French onshore wind market
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11.5 GW pipeline to fall out of 2016 CfD Developers/IPPs still dominate tenders
A total of 13.0 GW of onshore wind projects had applied fora 2016 CfD with signing pending (at mechanical completion)
DGEC confirmed early October that only the first 1.5 GW ofprojects will be able to sign their 2016 CfD (EC notification)
• ca. 1.0 GW of projects already signed their 2016 CfD,
leaving room for only the first next 500 MW of projects
• Amongst the 11.5 GW that will fall outside the 2016 CfD
scheme, some will look for 2017 CfD and not all others
are expected to bid into the upcoming tenders as some
permitting/procurement work is still needed
Source: Green Giraffe
13.0 11.5
1.5 1.0 0.52016 CfDvolume
Fruitless volume Cap for 2016CfD
Signed 2016CfD
2016 CfDvolume open
2016 CfD capacity breakdown (GW)
2017 CfD
CfD tender
0.0
4.0
8.0
12.0
16.0
0.0
0.5
1.0
1.5
2.0
Q219
Q319
Q419
Q120
Q220
Q320
Q420
Q121
Q221
Q321
Q421
Q122
Q222
Q322
Q422
Cumulative tendered capacity Tendered capacity
Local and small developers have been the most active in thepast decade and shaped the German onshore wind market
• Many projects were developed by local communities,
farmers and other land owners (“Bürgerwindparks”)
• The sharp decrease of costs combined with the introduction
of auctions in 2017 led to an increased competition
• The decrease of developers’ returns pushed them to look for
new drivers of growth and to develop internationally
German developers are now facing new challenges
• Developing internationally comes at a cost and local lenders
and investors are not always able to fund the projects abroad
• Amidst concerns around land scarcity and increasing
number of appeals against projects, the high new capacity
addition in 2018 and 2019 hide disappointing auctions
• The end of the EGG tariff for the first operating projects and
the pipeline of stranded projects is increasing
German onshore wind market
CONFIDENTIAL
German onshore wind market snapshot
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Source: Bundesverband WindEnergie
EEG future tender volume from 2019 to 2022 (in GW)
Onshore wind past capacity addition in Germany (in GW)
Source: Bundesverband WindEnergie
0
20
40
60
0.0
2.0
4.0
6.0
20
00
20
01
20
02
20
03
20
04
20
05
20
06
20
07
20
08
20
09
20
10
20
11
20
12
20
13
20
14
20
15
20
16
20
17
20
18
H1
201
9
Capacity addition Cumulative capacity (right axis)
0
10
20
30
40
50
60
70
-
500
1,000
1,500
2,000
2,500
3,000
May. 17 Aug. 17 Nov. 17 Feb. 18 May. 18 Aug. 18 Oct. 18 Feb. 19 May. 19 Aug. 19 Sep. 19 Oct. 19
German onshore wind tender results
MW put to auction MW submitted MW awarded Average bid (weighted average)
MW EUR/MWh
German onshore wind market
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Success of tenders is at risk since 2019
After promising and heavily oversubscribed auctions in 2017, the pace rapidly decreased to reach a worrying level in 2019
• When 2 GW of projects were bidding in each of the three auctions in 2017, less than 500 MW have bid in the last four auctions
• The absence of competition in 2019 led to bid price stabilizing close to 62 EUR/MWh, i.e. the maximum price allowed
• Germany would have accumulated a backlog of 11 GW of stranded projects according to public sources
• Decision makers are calling for an update of the spatial development plan and unlocking of permitting hurdles
Source: Bundesnetzagentur
Senior debt market trends
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How we see the current debt market for onshore wind assets with CfDs
Germany France
Margin 85–95 bps 105–115 bps
Sizing min. P90 DSCR 1.15x–1.20x 1.15x–1.20x
Max. gearing 90% 90%
Debt tenor CfD + 3 years CfD + 3 years
Non-recourse debt financing in European onshore wind
Source: WindEurope
20
15
20
16
20
17
20
18
20
19
20
20
20
21
20
22
20
23
20
24
20
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28
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30
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32
20
33
20
34
20
35
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20
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Shareholder loan - repayment Shareholder loan - interests paid Dividends paid (after taxes on dividends)
Senior debt - principal repayment Senior debt - interest payment Corporate taxes
Operating costs Operating revenues
End of tariff period
Typical project cashflows for debt financed onshore wind assets with CfDs
Total capital expenditures
Construction
Turbines
Or EPC wrap
Equity and quasi equityFoundations
Electricals
Installation
Insurance
Construction managementSenior debt
Development costs
Finance
MLA and DD costs
Debt fees (arranging & commitment)
Interest during construction
DSRA/DSRF costs
Senior debt market trendsRevenue side constraint – Low/no tariff Capex constraint – Current tariffs
P90 DSCR constraint on fixed-price revenues: 1.15x–1.20x
• No or very limited price risk on revenue side
• Net availability number in the 95-97% range
• Contracted O&M & insurance cost assumptions
Higher DSCR constraint for merchant price revenues
Debt : Equity < 90:10
• No tolerance for junior debt mechanisms
• General preference for equity to be paid upfront
O&M costs
Insurance costs
DSCR/cash available for dividends
Cash used for senior debt service
Buffer
15 years tenor senior
debt
20 years project life
time
Gross revenues
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All-in interest rates have decreased since 2014
• Were relatively stable until 2014, base rate and margins
being compensated by ECB rate
• Have decreased since 2014 to an all-time low today
• Onshore wind risk margin remained around 70 bps
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In Germany, most projects are small projects
-1
0
1
2
3
4
5
6
7
8
9
2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019
ECB rate Euribor Swap Swap fee Germany with KfW France premium Italy premium
Source: BloombergNEF
Germany France
Small projects< 30 MW
Landesbanks
Sparkassen
KfW funding program
French regional banks• CIC• CEPAC• Natixis Energeco• Crédit Agricole
regional banks• Auxifip• Crédit coopératif
German banks• Saar LB• Nord LB• Hamburg CB
Big projects> 30 MW
Commercial banks• CommerzBank• DekaBank• Unicredit
French banks• Natixis• Société Générale • BNP Paribas• Crédit Agricole
International banks
All-in interest rate is plummeting Active lenders
Onshore wind all-in interest rate
Senior debt market trends
Project M&A market
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Various investor profiles
CODFC/FIDShovel ready
Equi
ty IR
R
Stage 1:Early & mid development
Stage 2: Late development
Stage 3:Construction
Experienced financial investors
Pure developers
Independent power producers
Turbine contractors
Pension funds
Stage 4:Operation
CONFIDENTIAL
Utilities & oil majors
Infrastructure funds
Asian trading houses
Corporate M&A market trends – France
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Today, utilities are the most active buyers of renewable energy developers
Market consolidation by utilities has sped up since 2017 in France
2005 2006 2007 2008 2011 2012 2014 2015 2017 2018
PHASE 1 PHASE 2 PHASE 3
Saméole
ENGIE
Albioma
Uniper
Perfect Wind
Iberdrola
Uniper
E.ON Energie
Nass & Wind
GdF
Voltalia
Mulliez family
Aerowatt
JMB Energie
Enel
Boralex
SolaireDirect
ENGIE
EREN RE
Total
Langa
ENGIE
InnoVent
AES Corp
Cie du Vent
Electrabel
Enel
Axenne
Target
Buyer
Quadran
Direct Energie
Cie du Vent
ENGIE
Epuron
ERG
Direct Energie
Total
Eneco France
Undisclosed
Maïa Eolis
ENGIE
2019
Valeco
EnBW
Urbasolar
AXPO
Vol-V
CNR
InnoVent
Ongoing
Vent d’oc
Total
Luxel
EDF
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