E.ON Roadshow Presentation - Delivering step by step · PDF filePotential overachievement of...
Transcript of E.ON Roadshow Presentation - Delivering step by step · PDF filePotential overachievement of...
E.ON Delivering step by step
Key investment highlights
Highly stable business profile with ~2/3 of EBITDA from regulated, long-term contracted businesses1
Well positioned to profit from megatrends digitization, decentralization, e-mobility, renewables
Deleveraging: from 5.3x Net Debt/EBITDA (FY 2016) to ~4.0x Net Debt/EBITDA (mid-term target)
Potential overachievement of deleveraging targets offers potential room for profitable growth and dividends
Attractive dividend payout ratio (minimum of 65%2)
Rigid focus on capital return and discipline
2 1. Including Energy Networks and a portion of Renewables and Heat 2. Based on Adjusted Net Income, from FY 2018 (payable in 2019) onwards
Highly stable business profile
Business profile
High share of regulated and long-term contracted earnings (~2/3 of EBITDA )
Predominantly quasi-regulated or contracted earnings in Renewables and heat operations Remaining merchant exposure in Renewables and PreussenElektra largely hedged
Operations in Energy Networks under stable, well established frameworks in low risk markets with strong regulatory track record
FY EBITDA 20161
~2/3 from regulated/long-term contracted businesses2
1. Adjusted for non operating effects, representation in pie charts excluding Corporate Functions/ Other; total figures including Corporate Functions/ Other, 2. Including Energy Networks and a portion of Renewables and Heat
51%
15%
12%
21%
Energy Networks
Customer Solutions
PreussenElektra (non-core)
Renewables
€3.7bn
3
E.ON at a glance
4
Key financials FY ‘16
Adjusted EBIT €bn
Adjusted net income €bn
0.9
3.1
4
Renewables Customer Solutions
Energy Networks
€1.7bn EBIT (FY 2016) €0.8bn EBIT (FY2016) €0.4bn EBIT (FY2016)
~€19bn Regulated asset base mainly in Germany and
Sweden
>22m Customers across Europe with strong cash
flow generation
New solutions: operator of largest e-mobility charging
network in Denmark
>6GW Renewable capacities delivered across Europe and
the US
3 GW onshore pipeline to drive “growth” in the US
57%1 28%1
15%1
1. FY2016 EBIT adjusted for non operating effects, representation in pie charts excluding Corporate Functions/ Other
Delivering step by step…
Potential over-achievement of deleveraging could create balance sheet head room
Economic net debt € bn
~5.3x EBITDA
FY 2016
19.7
> 4.0x EBITDA
26.3
mid term target
~4.0x EBITDA
potential balance sheet head room
post deleveraging
9M 2017
Debt Reduction
6
NFT3 ~€2.85bn ABB4 ~€1.35bn
Debt reduction measures
+ Monetization of Uniper shares
+ Transfer of NS12 into CTA
+ Nuc. decommissioning cost savings
+ Additional measures (mainly non-core disposals excl. Urenco)
No hybrid issuance necessary
~3.8
~1.0
~1.0
~1.0
1
1. Based on share price of €22 (Fortum’s bid for E.ON’s Uniper Shares), 2. Nordstream 1 stake, 3. Nuclear Fuel Tax, 4. Accelerated Book Build
Raising payout and striving for dividend growth
Payout ratios by E.ON and peers
Dividend policy:
• Raising payout ratio to a minimum of 65%2
• Striving for payout ratio in line with peers
• Specification of exact range with FY2017
results
• Targeting absolute dividend growth (base year
2017)
• Strong alignment of management and investors
through E.ON Focus
7
80%
60%
50%
Peer group1
Previous payout E.ON 50% - 60%
E.ON target
1. Peer group: Centrica, Enel, EDP, Iberdrola, innogy, SSE, 2. Based on Adjusted Net Income, from FY 2018 (payable in 2019) onwards
65%
Capex budget under review
Medium-term – Gross capex
Strict focus on capital discipline across all business units
CAPEX budget for the mid-term under review
Update with FY17 results
2017 – Gross capex
2018 2017 2016
-20%
2019 2018 2017
Group
3.6
Renewables
1.5
Customer Solutions
0.7
Energy Networks
1.4
€ bn
€ bn Energy Networks investments of 1.6x regulatory depreciation driven by new renewables connections, grid maintenance and digitization
Customer Solutions investments in heat and new solutions (i.e. contracted onsite generation) and IT upgrades in UK/Germany
Renewables investments : European offshore (~800 MW) and US onshore (~500 MW)
∑ ~10.0 ∑ ~8.0
8
RAB growth: potential for higher replacement capex on top of continuing network extensions
Energy Networks: Multi-decade growth
9
>2020 2011 2016
7.1
+2-3% p.a.
+3-4% p.a.
8.0
€ bn
Example: Power RAB in Germany
€100-200m p.a. add. capex
potential on back of improved regulation
Mega trends support multi decade growth
Mega trends driving multi decade growth
Emergence of bi-directional flows as opposed to the purely one-directional flows in the past
Higher complexity of asset management, asset operations and asset optimization
Renewables build out
Majority of renewables connected to the distribution networks (instead of the transmission networks)
Increasing role of distribution system operators (DSOs) vs. the transmission system operators (TSOs) for overall system optimization
Smart meter roll-out
Sector coupling
Electrification of e.g. heating, cooling and transport via heat pumps and electric cars
DSO is in a preferred role enabling a system-optimal use since all this equipment is connected to the DSO networks
CS: Very good progress and growth also from asset-backed solutions
District Heating / B2M
Strong district heating business in Sweden, Germany, UK with yearly EBIT of ~€130m
Stable and resilient earnings profile often based on network assets
New €250m capex project in Högbytorp close to Stockholm to be finalized in 2019; 100 MW CHP plus district heating network extension
Energy Solutions B2B
Focus on industrial generation (6-120 MW CHPs), on-site generation solutions (small/medium CHPs, PV), energy and CO2 efficiency and flexibility
Order intake1 YTD of ~€0.4bn on track to double order intake to >€1bn yoy in 2017
E-Mobility
Leading E-Mobility player in Denmark (>50% market share)
Established strong partnerships (e.g. Clever and Sixt)
Roll-out of service offerings to other E.ON markets
Aim for leading role in developing role in developing Europe’s charging infrastructure 10
€130m
Heat contributes ~20% of Customer Solutions EBIT
ROCE: >10%
Order intake to pick up significantly
2016 2015 2017
>€1bn
1. TCV: Total contract value
Renewables: Risk & return focus
Highlights
5.3 GW Operated capacity1
4.6 GW Owned capacity2
1.1 GW Offshore capacity
3.5 GW Onshore + PV capacity 1. Operated sites, where E.ON is the operator, regardless the ownership share, 2. Pro rata
2.1 GW
3.2 GW
US onshore
Safe-harbored pipeline of > 3,000MW with 100% PTC support
New project Stella (201MW) with FID expected in Q3-17
~500 MW on track for completion in 2017
Europe onshore
Opportunistic approach
Recent example: FID on Morcone in Italy (57 MW, FiT of 66 €/MWh for 20 years)
Several hundred MW potential (e.g. in Scotland and Sweden)
Offshore
Stringent risk & return discipline
~800MW on schedule to be operational in 2018/19
Focus on PPA and FiT secured pipeline
11
Embedding operational excellence and establishing a strong performance culture: the Phoenix project
Scope Targets
4.1
Costs in scope of Phoenix
1.2
Total E.ON
5.3
Controllable cost1 baseline
€ bn • Phoenix target: €400 m EBIT contribution p.a. from 2018 onwards
• About €300 m predominantly from central overhead & support functions
• Restructuring of pension plans & other measures deliver ~€100 m
1. Controllable Costs include operational costs that management can meaningfully influence, such as material expenses, consultancy and personnel expenses. Margin-effective components such as fuel costs as well as cost item that are largely uncontrollable by the management are not included.
Performance Culture to be sustainably embedded across all functions
• Focus on operational excellence • Improve customer centricity • Digitization to improve processes and customer
experiences
Phoenix well on track
H1 2017
~€30m ~€30m
€400m
Total Q3 2017 Q4 2017
~€40m
2018
~€300m
Beyond Phoenix
12
Outlook 2017 confirmed
EBIT1
Adj. Net Income1
Outlook 2017
1. Adjusted for non operating effects
€1.2-1.45 bn
Effects for the remainder of 2017
13
– Lower hedging prices
– Additional depreciation of asset retirement costs
Energy Networks
Customer Solutions
Renewables
+ Regulatory effects (e.g. pensions), lower maintenance costs
+ Tariff increase in Sweden
+ Positive development in CEE
+ Price increases in Germany & UK, focus on efficiency
– Competitive dynamics in UK
+ Normalizing wind yields
€2.8-3.1 bn
E.ON Focus – Our basis for steering the company
E.ON KPIs without Uniper contribution, 1. Adjusted for extraordinary effects and divested operations, FY 2017 guidance range as basis for medium-term outlook, 2. OCFbIT divided by EBITDA, 3. Based on EBIT (= pre-tax), 4. Based on Adjusted Net Income, from FY 2018 (payable in 2019) onwards, 5. Total Shareholder Return
14
• Update of E.ON Focus with FY 2017 results
• Increased payout ratio to minimum of 65%4
• Striving for payout ratio in line with peers (specification of exact range with FY 2017 results)
• Target of absolute dividend growth (base year 2017)
• Strong alignment of management and investors
Segments
Energy Networks at a glance
16
Highlights EBIT1 in m€
Further key financials1 in m€
70%
866
2.601
1.923
864
2.973
2.135
Economic Investments
OCFbit3 EBITDA
9M 2017 9M 2016
Germany
+ Regulatory benefits
+ Lower maintenance cost
Sweden + Tariff increases
CEE & Turkey
+ Positive effects in Czech Republic, Hungary
– One-off effect (book loss on hydro power plant divestment), low hydro flows and FX in Turkey
288 345
638788
284270
+18%
CEE & Turkey
Sweden
Germany
9M 2017
1.417
9M 2016
1.196
1. Adjusted for non operating effects 2. Does only cover the three core businesses, Energy Networks, Customer Solutions and Renewables 3. Operating cash flow before interest and taxes.
EBIT 9M 20171,2
Energy Networks: E.ON has a strong European regulated asset base
0.9 0.4 0.4
GER SWE CEE Total
IG4
E.ON operates 858,000 networks km
Presence in countries with AAA rating/ catch-up potential
CEE (CZE, SVK, HUN, ROM)
€4.4 bn3
Sweden €3.9 bn2
Germany €10.7 bn
~€19 bn1
EBIT 2016 (€ bn)
1.7 ~ 54% ~ 24%
~ 23%
% of Total Energy Networks EBIT
AAA
Well diversified footprint
5
Regulated asset base (€ bn)
68
107
349
58
Power
Gas
Power
Gas
37
5
136
2
269
44
45
44
GER SWE
Distributed volumes (TWh)6
Grid length (‘000 km)
CEE3
1. Current total 2016 RAB of country/region - In general, RABs from different regulatory regimes are not directly comparable due to significant methodical differences. These include for example different regulatory asset lifetimes, asset valuation methods, or treatment of customer contributions for network connections. 2. Converted at SEK/EUR rate of 9.46, 3. Hungary converted at EUR/HUF of 311.4, Czech Republic converted at EUR/CZK of 27.0, and Romania converted at EUR/RON of 4.5; Including 100% of Slovakia, not including Turkey , 4. IG = Investment Grade; Except of Hungary and Turkey, 5. Including at equity income from Slovakia and Turkey, 6. Volumes including grid losses
AAA
17
Predictable earnings generated from RAB-based returns
Start of next regulatory period (Power)
2017
2019
2018
2020
Germany 5.9%2
Sweden 4.56%3
CEE 4.7% - 8.0%4
% of Total EBIT 2016
Pro-forma allowed WACC as solid base1 Regulatory stability in the near term
~90%
1. Power WACC for latest regulatory period. In general, allowed WACCs from different regulatory regimes are not directly comparable (even if they are adjusted for pre-tax/post-tax of real/nominal) because they are applied on RABs that are derived from different regulatory accounting rules, 2. Pro-forma calculated, nominal WACC, pre corporate tax and pre commercial tax. Instead of using a WACC-approach the German regulator publishes allowed equity returns. WACC figures for existing (Return on equity: 7.14% pre corporate tax and after commercial tax) and new investments (Return on equity: 9.05% pre corporate tax and after commercial tax) are assuming c. 4% cost of debt and a 60/40 debt/equity capital structure. The pro-forma WACC figure of 5.9% is then derived by weighting the share of existing assets (WACC: 5.7%) and new assets (WACC: 6.5%), 3. Pre-tax real WACC for Sweden of 4.56%; Current WACC challenged in court by network operators, 4. Hungary: pre-tax real WACC 4.69%, Czech Republic: pre-tax nominal WACC 7.951%, Romania: pre-tax real WACC 7.7%, Slovakia: pre-tax nominal WACC 6.47%
18
Customer Solutions at a glance
Highlights EBIT1 in m€
Further key financials1 in m€
17%
392
1.140
763
350
732584
EBITDA Economic Investments
OCFbit3
9M 2016 9M 2017
177
227
144
116
144
93
9M 2017
Germany
UK
Other
353
-36%
548
9M 2016
1. Adjusted for non operating effects 2. Does only cover the three core businesses, Energy Networks, Customer Solutions and Renewables 3. Operating cash flow before interest and taxes.
Germany
+ Price increase in Q2 2017
– Lower power margins due to increased TSO fees
– Lower gas margin due to price decrease in Nov 2016
UK
+ Stabilizing customer numbers & price increases in Q2 2017
– FX weakening after Brexit decision & price cap on PPM customers
Other
– Energy procurement crisis in Romania in Q1 2017
– Higher gas procurement costs in Eastern Europe
EBIT 9M 20171, 2
19
Customer Solutions: Introducing new solutions
E.ON Aura: PV & storage B2B Large: continuously gaining traction
All-in-one solution including PV, battery, energy management app, service & guarantee package and green electricity tariffs
Successful launch and scaling up across Germany
Introduction of virtual storage product E.ON SolarCloud
10x increase in unit sales in 2016 Target 2017: 10-15% market share
E-mobility: gearing up
Significant sales growth with tailor-made energy solutions (on-site generation, energy efficiency, flexibility, storage,…)
Diversified portfolio of customers (auto suppliers, tires, chemical, retail,…)
Innovative solutions like e.g. fuel cells & battery storage
2017 ambition: new contracts with several hundred million in total revenues
Established dedicated unit to take leading role in developing Europe’s charging infrastructure
E.ON has extensive experience in e-mobility market leader in Denmark (2,500 charging points)
Data-based development of services for further markets
Partnerships with car rental company Sixt and e-mobility specialists 20
Customer Solutions addresses customer needs across different segments
Energy Sales Power & Gas
Heat District Heating,
Local Heating
Foundation New Solutions
B2B Large & B2M
B2C & B2B SME
21
Customer Solutions: Financial highlights
Energy sales
Adjusted EBIT1 by business pillars
Heat 2016
2016
2016
~0.71
0.8
0.3 0.3
0.1
Total Adj. EBIT
Energy sales financials
1.3 1.2 2016
Gross Margin
1.0 2016 0.8
OPEX2
UK Continental Europe
€bn
€bn
1. Adjusted for non-operating earnings; Slight differences may occur due to rounding, 2. Costs to serve, costs to acquire and all other cost related to running the energy sales business including D&A 22
Renewables at a glance
23
Highlights EBIT1 in m€
Further key financials1 in m€
12%
637525584
961
540508
Economic Investments
OCFbit3 EBITDA
9M 2017 9M 2016
243186
66
62
-20%
Offshore/Other
Onshore/Solar
9M 2017
248
9M 2016
309 Offshore
– Arkona book gain in Q2 2016
– Low wind conditions in the UK
Onshore
+ COD of Colbeck’s Corner in May 2016
+ Higher production of US wind farms & better wind conditions in Europe
1. Adjusted for non operating effects 2. Does only cover the three core businesses, Energy Networks, Customer Solutions and Renewables 3. Operating cash flow before interest and taxes.
EBIT 9M 20171, 2
E.ONs capabilities in most attractive technologies and markets
Technology Geography Business model
• Focus on Onshore wind, off-shore wind & utility-scale PV
• Strong E.ON capabilities and experience
• Capture trends in line with E.ON’s capabilities / markets
Wind Onshore
PV
Wind Offshore
• Focus on Europe & North America
• Stable countries / low-risk
• Still attractive returns achieved
• Integrated renewables player
• Portfolio optimization strategy, bringing:
- Scale advantages
- Maintain capabilities
- Value creation
- Reduce cluster risk
2.1 GW
3.2 GW
24
Segments: PreussenElektra
Highlights
– Lower volumes due to Brokdorf outage – Lower achieved power prices
– Additional depreciation of asset retirement costs (ARC)
+ End of nuclear fuel tax payments in 2016 + One-off effects in relation to court case & KFK
solution
Hedged Prices Germany (€/MWh) as of 30 Sept 2017
1. Adjusted for non operating effects 2.Operating cash flow before interest and taxes.
25
E.ON 9M 2017 results
32
28
27
37
2019
2018
2017
2016
94%
62%
100%
100%
EBIT1 in m€ 357345
+3%
Germany
9M 2017 9M 2016
Further key financials1 in m€
12
259
410
10
497
Economic Investments
OCFbit2
-7.069
EBITDA
9M 2017 9M 2016
PreussenElektra: Asset overview
Decommissioning Shut down
Active and operated by PreussenElektra
Active and minority share PreussenElektra
Brunsbüttel Brokdorf
Stade
Unterweser Krümmel
Hannover Emsland
Grohnde
Würgassen
Grafenrheinfeld
Isar 1/2
Gundremmingen A/B/C
Geographic presence in Germany Overview nuclear plants
1. Atomgesetz, 2. Start-up year 1971, transfer to Preußische Elektrizitäts-Aktiengesellschaft in 1975 26
Nuclear decommissioning is no limitation for dividends or capex
€ bn
EBITDA1
~0.4-0.6
Utilization of nuclear provisions
OCF bIT
1. Adjusted for non operating effects 27
• Nuclear decommissioning provisions are part of E.ON’s economic net debt (END)
• Utilization of nuclear provisions is currently part of operating cash flow and thus implies a burden for the financial leeway
Current
Economic view
EBITDA1 OCF bIT
Current approach
Economic view
• However, economically the utilization is comparable to a redemption of debt and thus has features of financing cash flow
• Nuclear decommissioning could therefore be paid and replaced with financial debt (END neutral) and is thus no limitation for dividend or capex
Discount rates for nuclear provisions
Build up of provisions status quo
t+100 t+1 t+2 t+3
Accretion Storage Decommissioning
Real discount rate: +0.9%
Build up of provisions post KFK1
t+n t0 t+1 t+2
Accretion Decommissioning
Real discount rate: -0.9%
• Remaining provisions with shorter duration
• Real discount rate of -0.9% (2015: +0.9%) increases provisions to €11.2 bn (new END definition: €10.1 bn2 with real discount rate of 0.0%)
Duration effect
Total costs in t0 Total costs
in t0
t 0
t 0
1. Utilization not taken into account, 2. Current cost value used for FY 2016 END definition 28
KFK solution with positive impact on adjusted net income
• Payment amount has been transferred to
government fund on July 3rd 2017
• Accretion of interest (4.4% p.a.) on €7.8 bn stops as of 1 Jan 2017
• Increases net income by ~€200-250 m2 p.a.
1. Nuclear fund (KFK) 2. Discount rates 3. Additional asset retirement cost (ARC)
7.8
Premium1 Provisions Provision interest cost
Payment Amount1
~10
2.0 0.2
1. Excluding €0.2 bn for minority shareholders, 2. Net effect, depending on refinancing costs, 3. Current cost value used for FY 2016 END definition, 4. Depending on discount rate to be applied, 5. Risk-free discount rate of ~0.5%
FY 2016 FY 2015 Net accr. charge
9M 2016
9.7
Increase of provisions
9.4
0.3 1.5
11.2 Storage related provisions, € bn
• Remaining provisions with shorter duration
• Real discount rate of -0.9% (2015: +0.9%)
increases provisions to €11.2 bn (new END
definition: €10.1 bn3 with real discount rate of
0.0%)
• Reduces accretion charges by ~€350 m4 p.a.
• Accretion charges based on risk free rate5
• Quarterly fluctuations of provisions
2018 2016 2021 2019
1.0
2017 2020 2022
ARC € bn
• Duration effect increases Asset Retirement
Costs (ARC)
• Additional ARC are capitalized as of Q4 2016
• Annual depreciation over remaining lifetime of
nuclear plants
• Reduces non-core EBIT by ~€185 m p.a.
Decommissioning provisions, € bn
29
Financials
9M 2017 Results
9M 2017 Results
8th November 2017
Solid 9M 2017: well on track to achieve FY 2017 target E.ON 9M 2017 results
Solid EBIT development: + 13% Q3 2017 vs Q3 2016
Adj. Net Income up ~50% YoY
Economic Net Debt reduced to €19.7 bn (vs. €21.5 bn in H1 2017)
FY 17 guidance confirmed: EBIT €2.8-3.1 bn, Adj. Net Income €1.2-1.45 bn
Highlights
32
641
965
Adj. Net Income EBITDA EBIT
3,540
2,117 2,311
3,640
9M 2017 9M 2016
Key Financials1
€ m
1. Adjusted for non operating effects
– Lower prices & volumes, additional depreciation of asset retirement costs (ARC)
+ End of nuclear fuel tax, one-off effects in relation to court case & KFK solution
+ Higher regulated revenues in Germany and CEE
+ Tariff increases in Sweden
+ Price increases in Germany and UK – Higher costs (e.g. ECO2), PPM3 cap,
competitive dynamics in UK, Energy procurement crisis in Romania (Q1 2017)
– Arkona book gain in Q2 2016 (offshore)
Catch-up continues in Q3 2017
12
221
2.282 9M 2016 w/o div. operations
-195
Energy Networks
-61
Customer Solutions
-142
Renewables
2.117
Corp. Functions & Other,
Consolidation
9M 2017
165
EBIT1 9M 2017 vs. 9M 2016 € m
1. Adjusted for non operating effects, 2. Energy Company Obligation (ECO) 3. Prepayment Meter (PPM)
33
E.ON 9M 2017 results
Energy Networks
Customer Solutions
Renewables
Preussen Elektra
Key 9M Effects
Adjusted Net Income supported by lower interest accretion and taxes
9M 2017 € m
~€ 55m decline yoy mainly due to lower interest income
1. Adjusted for non operating effects, 2. Without interest accretion of nuclear provisions 34
E.ON 9M 2017 results
EPS (€ per share)
965
Minorities -191
Income Taxes -386
Adjusted Net Income1
Profit before Taxes1 1.542
Other interest expenses -53
Interest on fin. assets/
liabilities2
-522
Group EBIT1 2.117
Tax rate of 25% (vs. 32% in 9M 2016)
~€600m improvement yoy mainly due to significant lower interest accretion of nuclear provisions and other interest expenses
Adjusted net income up 51% over prior year
€0.46
END improves significantly due to high cash flow and refund of nuclear fuel tax
+6.6
END 9M 2017
-19.7
-4.9
-3.6
-11.2
Others
0.6
AROs6
10.2
Pensions
0.4
Divestments
0.2
Dividend
-0.5
ABB5
1.35
Investments
-2.2
KFK payment to government
fund4
-10.3
Cash impact of NFT refund3
3.4
OCF2
3.5
END FY 2016
-26.3 -0.9
-4.0
-21.4
€ bn
END1 9M 2017 vs. FY 2016
1. Economic net debt definition takes into account the decommissioning provisions calculated with a real discount rate of 0.0% as opposed to IFRS ARO’s. 2. OCF adjusted for KFK and NFT effects, 3. Nuclear Fuel Tax (NFT) including positive interest income effect, before taxes and payment to minorities 4. Kommission zur Überprüfung der Finanzierung des Kernenergieausstiegs (KFK), 5. Accelerated Book Build (ABB), 6. Includes transfer of nuclear storage liabilities to government fund
AROs Pension provisions Net financial position
35
E.ON 9M 2017 results
Operating Cash Flow: -3.3
Appendix Financial Details
37
E.ON 9M 2017 results Appendix: Table of Contents
40 Energy Networks 41
Customer Solution
42 Renewables 43 Preussen Elektra
38 Financial Highlights 39
Cash Conversion
44 Financial Appendix
Financial Highlights
€m 9M 2016 9M 2017 % YoY
Sales 28,198 27,937 -1
EBITDA 1 3,640 3,540 -3
EBIT 1 2,311 2,117 -8
Adjusted net income 1 641 965 +51
OCF bIT 3,827 -3,091 -181
Investments 1,981 2,222 +12
Economic net debt ² 26,320 19,699 -25
38
E.ON 9M 2017 results
EBIT • Energy Networks: +18% YoY.
Higher regulated revenues in Germany and CEE and tariff increases in Sweden
• Customer Solutions: -36% YoY. Lower margins and increased competitors dynamic
• Renewables: -20% YoY. Arkona book gain in Q2 2016 and lower wind conditions
OCF bIT • Cash provided by operating
activities €6.3 bn below prior-year level
• Key drivers: €10.3 bn payment to nuclear fund (KFK3) (-) and €3.4 bn4 nuclear fuel tax (NFT) refund (+)
Adj. Net Income • €324 m above last years
9M result • Improvement YoY mainly
driven by significant lower interest accretion of nuclear provisions, other interest expenses and a tax rate of 25% (vs. 32% in 9M 2016)
1. Adjusted for non operating effects, 2. Economic net debt as per 31 Dec 2016 and 30 Sept 2017; Economic net debt definition takes into account the decommissioning provisions calculated with a real discount rate of 0.0% as opposed to IFRS ARO’s 3. Kommission zur Überprüfung der Finanzierung des Kernenergieausstiegs (KFK) 4. Nuclear Fuel Tax (NFT) including positive interest income effect, before taxes and payment to minorities
Investments • Energy Networks: €864 m
(vs. €866 m YoY) • Customer Solutions: €350
m (vs. €392 m YoY) • Renewables: €961 m
(vs. €637 m YoY )
Capex
-2.2
OCF
3.5
Tax Payments
-0.3
Interest Payments
-0.3
OCF bIT4
4.2
Changes in WC
0.9
Cash Adjustments3
-0.2
EBITDA1
3.5
+120%
FCF
1.3
High cash conversion rate2 of 120% supported by strong operating cash flow
9M 2017 € bn
1. Adjusted for non operating effects, 2. Cash Conversion Rate: OCF bIT / EBITDA, adjusted for NFT and KFK effects, 3. Net non cash effective EBITDA items incl. provision utilizations, 4. Adjusted for KFK and NFT effects
39
E.ON 9M 2017 results
Highlights
Segments: Energy Networks
• Germany:
+ Regulatory effects
+ Lower maintenance costs
• Sweden:
+ Tariff increases
• CEE & Turkey:
+ Tariff increases in Hungary
+ Higher allowed revenues in Czech Republic & Romania
Energy Networks
284
288 345
270
788
+18%
CEE & Turkey
Sweden
Germany
9M 2017
1,417
9M 2016
1,196
638
1. Adjusted for non operating effects
EBIT1 € m
€m
9M 2016 9M 2017 % YoY 9M 2016 9M 2017 % YoY 9M 2016 9M 2017 % YoY 9M 2016 9M 2017 % YoY
Revenue 10,288 10,797 +5 736 831 +13 1,183 1,239 +5 12,207 12,867 +5
EBITDA 1 1,084 1,217 +12 411 467 +14 428 451 +5 1,923 2,135 +11
EBIT 1 638 788 +24 288 345 +20 270 284 +5 1,196 1,417 +18
thereof Equity-method earnings 54 60 +11 0 0 - 47 -7 -115 101 53 -48
OCFbIT 1,809 2,106 +16 398 443 +11 394 424 +8 2,601 2,973 +14
Investments 517 396 -23 180 228 +27 169 240 +42 866 864 -0
TotalGermany Sweden CEE & Turkey
40
E.ON 9M 2017 results D
etai
ls
Segments: Customer Solutions
Customer Solutions Highlights
• Germany:
– Lower power margins due to increased TSO2 fees (Q1 2017)
– Lower gas margin due to price decrease in Nov 2016
+ Price increases as per Q2 2017
• UK:
– Higher ECO3 costs & FX weakening
– Price cap on PPM4 customers
– Competitive dynamics
• Other:
– Energy procurement crisis in Romania in Q1 2017
177
227
144
144
93
116
-36%
Other
UK
Germany
9M 2017
353
9M 2016
548
EBIT1 € m
1. Adjusted for non operating effects 2. Transmission system operator (TSO) 3. Energy Company Obligation (ECO) 4. Prepayment meter (PPM)
€m
9M 2016 9M 2017 % YoY 9M 2016 9M 2017 % YoY 9M 2016 9M 2017 % YoY 9M 2016 9M 2017 % YoY
Revenue 5,526 5,424 -2 5,676 5,083 -10 4,877 4,972 +2 16,079 15,479 -4
EBITDA 1 192 147 -23 297 218 -27 274 219 -20 763 584 -23
EBIT 1 144 93 -35 227 144 -37 177 116 -34 548 353 -36
thereof Equity-method earnings 0 0 - 0 0 - 8 11 +38 8 11 +38
OCFbIT 352 226 -36 283 229 -19 505 277 -45 1,140 732 -36
Investments 47 42 -11 158 142 -10 187 166 -11 392 350 -11
TotalUKGermany Other
41
E.ON 9M 2017 results D
etai
ls
• Offshore:
– Arkona book gain in Q2 2016
– Lower wind conditions in UK, FX (GBP) weakening
• Onshore:
+ COD of Colbeck’s Corner in May 2016
+ Higher production of US wind farms
– Lower wind conditions in Europe (esp. Italy & UK)
Segments: Renewables
Renewables Highlights
243186
6266
-20%
Offshore/Other
Onshore/Solar
9M 2017
248
9M 2016
309
EBIT1 € m
1. Adjusted for non operating effects
€m
9M 2016 9M 2017 % YoY 9M 2016 9M 2017 % YoY 9M 2016 9M 2017 % YoY
Revenue 567 691 +22 455 439 -4 1,022 1,130 +11
EBITDA 1 229 209 -9 355 299 -16 584 508 -13
EBIT 1 66 62 -6 243 186 -23 309 248 -20
thereof Equity-method earnings 11 18 +64
OCFbit 525 540 +3
Investments 637 961 +51
Onshore Wind / Solar Offshore Wind / Others Total
42
E.ON 9M 2017 results D
etai
ls
Segments: PreussenElektra
PreussenElektra Highlights
357345
+3%
9M 2017 9M 2016
– Lower volumes due to Brokdorf outage
– Lower achieved power prices
– Additional depreciation of asset retirement costs (ARC)
+ End of nuclear fuel tax payments in 2016
+ One-off effects in relation to court case & KFK solution
Hedged Prices Germany (€/MWh) as of 30 Sept 2017
EBIT1 € m
1. Adjusted for non operating effects
€m
9M 2016 9M 2017 % YoY
Revenue 1,068 1,230 +15
EBITDA 1 410 497 +21
EBIT 1 345 357 +3
thereof Equity-method earnings 50 44 -12
OCFbIT 259 -7,069 -2,829
Investments 12 10 -17
PreussenElektra
43
E.ON 9M 2017 results
32
28
27
37
2019
2018
2017
2016
94%
62%
100%
Det
ails
100%
Adjusted Net Income
€m 9M 2016 9M 2017 % YoY
EBITDA 1 3,640 3,540 -3
Depreciation/amortization -1,329 -1,423 -7
EBIT 1 2,311 2,117 -8
Economic interest expense (net) -1,118 -575 +49
EBT 1 1,193 1,542 +29
Income Taxes on EBT 1 -387 -386 +0
% of EBT 1 -32% -25% -
Non-controlling interests -165 -191 -16
Adjusted net income 1 641 965 +51
1. Adjusted for non operating effects
44
E.ON 9M 2017 results
Economic interest expense (net) • Improvement mainly driven
by significant lower interest accretion of nuclear provisions and other interest expenses
Tax rate • Tax rate of 25% (vs. 32%
in 9M 2016)
Reconciliation of Adj. EBIT to IFRS Net Income
€m 9M 2016 9M 2017 % YoY
EBITDA 1 3,640 3,540 -3
Depreciation/Amortization/Impairments -1,329 -1,423 -7
EBIT 1 2,311 2,117 -8
Economic interest expense (net) -1,118 -575 +49
Net book gains 1 288 n/a
Restructuring -221 -173 +22
Mark-to-market valuation of derivatives 768 -453 -159
Impairments (net) -44 5 +111
Other non-operating earnings -79 3,298 n/a
Income/Loss from continuing operations before income taxes 1,618 4,507 +179
Income taxes -624 -604 +3
Income/loss from discontinued operations, net -10,293 0 +100
Non-controlling interests -5,351 197 +104
Net income/loss attributable to shareholders of E.ON SE -3,948 3,706 +194
1. Adjusted for non operating effects
E.ON 9M 2017 results
45
Cash effective investments by unit
1. Adjusted for non operating effects
€m 9M 2016 9M 2017 % YoY
Energy Networks 866 864 -0
Customer Solutions 392 350 -11
Renewables 637 961 +51
Corporate Functions & Other 78 42 -46
Consolidation -4 -5 -25
PreussenElektra 12 10 -17
Investments 1,981 2,222 +12
E.ON 9M 2017 results
46
Economic Net Debt1
1. Economic net debt definition takes into account the decommissioning provisions calculated with a real discount rate of 0.0% as opposed to IFRS ARO’s, 2. Net figure; does not include transactions relating to our operating business or asset management
E.ON 9M 2017 results
47
€m 31 Dec 2016 30 June 2017 30 Sept 2017
Liquid funds 8,573 14,252 5,450
Non-current securities 4,327 3,850 3,801
Financial liabilities -14,227 -14,691 -14,304
Adjustment FX hedging ² 390 311 158
Net financial position -937 3,722 -4,895
Provisions for pensions -4,009 -3,748 -3,586
Asset retirement obligations -21,374 -21,459 -11,218
Economic net debt -26,320 -21,485 -19,699
Economic interest expense (net)
€m 9M 2016 9M 2017 Difference
(in € m)
Interest from financial assets/liabilities -467 -522 -55
Interest cost from provisions for pensions and similar provisions -64 -61 +2
Accretion of provisions for retirement obligation and similar provisions -647 -49 +597
Construction period interests¹ 29 29 +0
Others 31 29 -2
net interest result -1,118 -575 +543
1. Borrowing cost that are directly attributable to the acquisition, construction or production of a qualified asset. Borrowing cost are (virtual) interest costs incurred by an entity in connection with the borrowing of funds. (interest rate: 5.6%)
48
E.ON 9M 2017 results
Financial Liabilities
Split Financial Liabilities
€ bn
30 Sept
2017
Bonds -12.5
in EUR -5.7
in GBP -3.9
in USD -2.5
in JPY -0.2
in other denominations -0.2
Promissory notes -0.4
Commercial papers 0.0
Other liabilities -1.4
Total -14.3
49
E.ON 9M 2017 results
2018
1.1 1.4
2019
1.8
≥2025
4.8
0.6
2024
0.4
2023 2022
0.8
2020
0.1
2021 2017
2.1
GBP EUR USD Other YEN
Maturity profile (as of end 9M 2017)1
€ bn
1. Bonds and promissory notes issued by E.ON SE, E.ON International Finance B.V. and E.ON Beteiligungen GmbH (fully guaranteed by E.ON SE)
Appendix Contacts, Calendar & Disclaimer
E.ON Investor Relations contacts
T +49 (201) 184 2806 [email protected]
Alexander Karnick T+49 (201) 184 28 38
Head of Investor Relations [email protected]
Martina Burger T +49 (201) 184 28 07
Manager Investor Relations [email protected]
Dr. Stephan Schönefuß T +49 (201) 184 28 22
Manager Investor Relations [email protected]
51
Andreas Thielen T +49 (201) 184 28 15
Manager Investor Relations [email protected]
Financial calendar & important links
Financial calendar
March 14, 2018 Annual Report 2017
May 8, 2018 Interim Report I: January – March 2018
May 9, 2018 2018 Annual Shareholders Meeting
August 8, 2018 Interim Report II: January – June 2018
November 14, 2018 Interim Report III: January – September 2018
Important links
Presentations https://www.eon.com/en/investor-relations/presentations.html
Annual Reports https://www.eon.com/en/investor-relations/financial-publications/annual-report.html
Interim Reports https://www.eon.com/en/investor-relations/financial-publications/interim-report.html
Shareholders Meeting https://www.eon.com/en/investor-relations/shareholders-meeting.html
Bonds / Creditor Relations https://www.eon.com/en/investor-relations/bonds.html
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This document is being presented solely for informational purposes. It should not be treated as giving investment advice, nor is it intended to provide the basis for any evaluation or any securities and should not be considered as a recommendation that any person should purchase, hold or dispose of any shares or other securities.
This presentation may contain forward-looking statements based on current assumptions and forecasts made by E.ON management and other information currently available to E.ON. Various known and unknown risks, uncertainties and other factors could lead to material differences between the actual future results, financial situation, development or performance of the company and the estimates given here. E.ON does not intend, and does not assume any liability whatsoever, to update these forward-looking statements or to conform them to future events or developments.
Neither E.ON nor any respective agents of E.ON undertake any obligation to provide the recipient with access to any additional information or to update this presentation or any information or to correct any inaccuracies in any such information.
Certain numerical data, financial information and market data (including percentages) in this presentation have been rounded according to established commercial standards. As a result, the aggregate amounts (sum totals or interim totals or differences or if numbers are put in relation) in this presentation may not correspond in all cases to the amounts contained in the underlying (unrounded) figures appearing in the consolidated financial statements. Furthermore, in tables and charts, these rounded figures may not add up exactly to the totals contained in the respective tables and charts.
Disclaimer
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