E.ON Roadshow

Three attractive core businesses

2

Adjusted EBITDA €bn

Adjusted EBIT €bn

Adjusted Net Income €bn

Adjusted EBIT1 2016 of €3.1 bn

4.9

3.1

0.9

2016

Corporate Functions/ Other2

- €0.4 bn

Non-core Business (PreussenElektra)

€ 0.6 bn

€ 1.7 bn € 0.4 bn € 0.8 bn

Key financials 20161

1. Adjusted for non-operating effects, 2. Including group consolidation effects

Energy Networks Customer Solutions Renewables

Attractive combination of businesses

1. 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. Adjusted for non-operating effects, 3. Renewables, 4. Commercial operation date

Energy Networks Renewables Customer Solutions

~ €19 bn Regulated Asset Base1 Germany €10.7 bn Sweden €3.9 bn CEE €4.4 bn

Efficiency Efficiency leader in Germany and Sweden

>99 %

Adj. EBIT2 from additional earnings pools Based on efficiency, investments and non-regulated activities

>10%

>22 m Customers across Europe Germany 6.1 m UK 7.0 m Other EU 9.2 m

Customers purchasing value added services

400,000

of Adj. EBIT2 from Heat & New Solutions Resilience from long-term customer relations built on satisfaction and trust

~15%

>6 GW Renewables capacities delivered 10 year track record of renewables development, construction & operations

Wind projects under construction Offshore: Rampion (400 MW, COD4 2018), Arkona (385 MW, COD 2019) Onshore : Radford’s Run (278 MW, COD Dec 2017), Bruenning’s Breeze (228 MW, COD Dec 2017)

Four

Green electricity produced in 2016

11.6 TWh

RES3 connections 390,000 Investments in renewables

>€10 bn

3

E.ON continues to benefit from a very stable business profile

Business profile post spin…

High share of regulated earnings

Predominantly quasi-regulated or contracted earnings in Renewables

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

Long-term contracted earnings from heat operations

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

Renewables

€4.9bn

4

Outlook 2017

EBIT1

Adj. Net Income1

Outlook 2017

1. Adjusted for non operating effects

€2.8-3.1 bn

€1.2-1.45 bn

+ Regulatory effects (e.g. NeMoG, pensions), lower maintenance costs

+ Tariff increase in Sweden

+ Positive development in CZ, HU/ normalization in Turkey

Effects for remainder of 2017

+ Omission of nuclear fuel tax payments

+ Operational improvements

– Lower hedging prices

– Asset retirement cost (ARC) effect

Energy Networks

Customer Solutions

+ Price increases in Germany & UK

+ Focus on sales and customer retention in UK

+ UK efficiency program

Renewables + Normalizing wind yields

– Arkona book gain in Q2 2016

5

Executive compensation

Profit Group EBIT1 & EPS4

Cash Cash conversion

rate2 ≥ 80 %

Return ROCE3

8 – 10 %

Growth DPS

Capital structure Strong BBB / Baa

Dividend payout FY 2017: € 30ct (fixed)

Post 2017: 50 – 60 %4

E.ON FOCUS – medium-term framework

closely linked to EPS target achievement and relative TSR5 (in addition: Share ownership obligations)

Update of 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, 5. Total Shareholder Return

6

KFK implementation in final stages

Status / Next steps Total payment amount for E.ON confirmed

2.00.2

10.0

7.8

Premium1 Provisions Payment amount1

Provision for interest costs

€ bn

• German legislative process completed

• Law approved by Bundestag and Bundesrat in December 16

• State aid approval by the EU Commission expected in Q2 17

• Additional contract finalized

• Nuclear operators are dropping storage-related legal claims and moratorium court cases

• Signing of contract expected closely after law enters into force

• Payment planned around 1st July 2017

• Financing of premium via capital measures

• Financing of base amount via liquidity on balance sheet and bond issues (up to €3 bn) as well as Commercial Paper (CP)

1. Excluding €0.2 bn for minority shareholders 7

KFK solution with positive impact on adjusted net income

• Payment amount to be transferred to

government fund around 1st July 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)

2.0 0.2

10.0

7.8

Payment Amount1

Provision interest cost

Premium1 Provisions

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%

11.29.79.4

1.50.3

FY 2016 Increase of provisions

9M 2016 Net accr. charge

FY 2015

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

1.0

2022 2021 2020 2019 2018 2017 2016

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

8

Clear deleveraging plan defined

Economic net debt Debt reduction measures

Capital measures (options incl. ABB1, hybrid)

Monetization of Uniper shares

Transfer of Nord Stream 1 into CTA

Nuc. decommissioning cost savings3

Additional measures (non-core disposals, scrip dividend)

Operational measures

Savings from efficiency program Phoenix

Reduced capex budget

€ bn

26.3

~ 20.0 (~4x EBITDA)

2016 (new definition)

~-6.3

Medium-term

€ bn

~2.0

~2.4

~1.0

~1.0

~1.0

1. Accelerated book build: capital increase of up to 10% of shares outstanding, 2. Based on Uniper share price of €14.19 as of March 10, 2017, 3. Cost savings have been identified technical expert opinions required before savings can be included in ARO calculation

2

9

Efficiency program Phoenix: Securing sustainable competitiveness

Principles Scope Targets, status, and next steps

Competitive services 4

Business empowerment 1

Lean management holding 2

Divisional steering 3

1.2

Costs in scope of Phoenix

4.1

Total E.ON

5.3

Controllable cost1 baseline

€ bn

• Phoenix target: €400 m EBIT contribution p.a. from 2018 onwards

• About €300 m from central overhead & support functions

• Restructuring of pension plans & other measures deliver ~€100 m

• Status/ Next steps

• 100% of target measures identified

• First measures being implemented

• Negotiations with workers’ council in Q2 2017

10

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.

Disciplined capital allocation

Medium-term – Gross capex

• Strict focus on capital discipline across all business units

• Three year capex budget decreased by ~20%

• Reduced investments in renewables projects, notably starting in 2018 given committed project pipeline

2017 – Gross capex

2018 2017 2016

-20%

2019 2018 2017

1.4

0.7

1.5

3.6

Group Renewables Customer Solutions Energy Networks

€ 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

11

Stringent incentive plan for the Management Board

KPI

Relative TSR1

EPS & individual performance

Cap

200% of target value

200% of target value

Calculation

TSR development relative to STOXX Europe 600 Utilities over 4 years

EPS × individual performance multiplier

Long-Term Incentive

Short-Term Incentive

Share Ownership Guidelines

Board members obliged to acquire E.ON shares equaling 150 – 200% of annual base salary

1. Total Shareholder Return 12

≥2025

4.2

2024

0.1

2023

0.4

2022

0.1

2021

0.0

2019

1.1

2018

2.3

2017

2.7

1.4

2020

Other

YEN

USD

GBP

EUR

Sound liquidity profile to support upcoming maturities and KFK solution

Split Financial Liabilities Maturity profile (as of end Q1 2017)1

€ bn € 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)

31 Mar

2017

Bonds -11.9

in EUR -4.7

in GBP -4.0

in USD -2.8

in JPY -0.2

in other denominations -0.2

Promissory notes -0.4

Commercial papers 0.0

Other liabilities -1.9

Total -14.2

13

Q1 2017 Results

E.ON fully on track for FY 2017

– EBIT1 below prior year mainly due to expected developments in commodity retail and non-core

+ Q1 not representative for FY 2017 performance

+ Lower interest accretion and tax rate compensate for operational drivers at Adj. Net Income1 line

+ Full year guidance for 2017 confirmed

+ Economic net debt improved by €1.6bn due to high cash flow and capital increase

Highlights

525

Adj. Net Income1

1.038

EBITDA1 EBIT1

1.517

Q1 2017

1. Adjusted for non operating effects

€ m

15

EBIT below prior year

60

-221

Corp. Functions & Other,

Consolidation

-90

Renewables

-3

Customer Solutions

-258

-512

Q1 2016 w/o div. operations

1.550

Divested Operations

-21

Energy Networks

1.571

Q1 2017

1.038

Preussen Elektra

Q1 2016

EBIT1 Q1 2017 vs. Q1 2016 € m

1. Adjusted for non operating effects 16

Adjusted Net Income supported by lower accretion and taxes

EPS (€ per share)

Q1 2017 € m

0.26 525

843

Adjusted Net Income1

Minorities -108

Income Taxes -210

Profit before Taxes1

Other interest expenses

-20

Interest on fin. assets/

liabilities2

-175

Group EBIT1 1.038

~€ 20m improvement YoY

~€200m improvement due to significant lower accretion of nuclear provisions

Tax rate of 25% (vs. 33% in Q1 2016)

Unchanged to previous year

Adjusted net income is supported by lower nuclear accretion charges and taxes

1. Adjusted for non operating effects, 2. Without accretion of nuclear provisions 17

Segments: Energy Networks

• Germany:

+ Regulatory benefits

+ Lower maintenance costs • Sweden:

+ Tariff increases • CEE:

+ Positive effects in Czech Republic, Hungary

– One-off effect (book loss on hydro power plant divestment), low hydro flows and FX in Turkey

Energy Networks Highlights

113 13280109

418

+11%

CEE & Turkey

Sweden

Germany

Q1 2017

630

Q1 2016

570

348

1. Adjusted for non operating effects

EBIT1 € m

€m

Q1 2016 Q1 2017 % YoY Q1 2016 Q1 2017 % YoY Q1 2016 Q1 2017 % YoY Q1 2016 Q1 2017 % YoY

Revenue 3,458 3,426 -1 276 298 +8 447 475 +6 4,181 4,199 +0

EBITDA 1 492 562 +14 154 173 +12 159 134 -16 805 869 +8

EBIT 1 348 418 +20 113 132 +17 109 80 -27 570 630 +11

thereof Equity-method earnings 10 16 +60 0 0 - 30 -29 -197 40 -13 -133

OCFbIT 308 722 +134 122 142 +16 137 152 +11 567 1,016 +79

Investments 118 98 -17 43 60 +40 34 102 +200 195 260 +33

TotalGermany Sweden CEE & Turkey

18

Segments: Customer Solutions

Customer Solutions Highlights

• Germany:

– Higher costs due to increased TSO fees

– Lower gas margin due to price decrease in Nov 2016 • UK:

– Higher customer churn rates combined with higher cost of sales

– FX weakening following Brexit decision • Other:

– Energy procurement crisis in Romania

– Higher gas procurement costs in Eastern Europe

188 117

280

161

120

-44%

Other

UK

Germany

Q1 2017

330 52

Q1 2016

588

EBIT1 € m

1. Adjusted for non operating effects

€m

Q1 2016 Q1 2017 % YoY Q1 2016 Q1 2017 % YoY Q1 2016 Q1 2017 % YoY Q1 2016 Q1 2017 % YoY

Revenue 2,414 2,291 -5 2,635 2,151 -18 2,050 2,104 +3 7,099 6,546 -8

EBITDA 1 140 71 -49 304 185 -39 218 154 -29 662 410 -38

EBIT 1 120 52 -57 280 161 -43 188 117 -38 588 330 -44

thereof Equity-method earnings 2 0 -100 0 0 - 1 3 +200 3 3 +0

OCFbIT -79 -186 -135 -13 10 +177 211 21 -90 119 -155 -230

Investments 14 8 -43 45 46 +2 48 10 -79 107 64 -40

TotalUKGermany Other

19

• Offshore:

– Low wind yields

– Adverse FX development following Brexit decision • Onshore:

+ COD of Colbeck’s Corner in May 2016

+ Higher Production of US wind farms

Segments: Renewables

Renewables Highlights

59 61

104 99

-2%

Offshore/Other

Onshore/Solar

Q1 2017

163 160

Q1 2016

EBIT1 € m

1. Adjusted for non operating effects

€m

Q1 2016 Q1 2017 % YoY Q1 2016 Q1 2017 % YoY Q1 2016 Q1 2017 % YoY

Revenue 196 188 -4 201 188 -6 397 376 -5

EBITDA 1 112 113 +1 143 136 -5 255 249 -2

EBIT 1 59 61 +3 104 99 -5 163 160 -2

thereof Equity-method earnings 11 11 +0

OCFbit 207 187 -10

Investments 241 251 +4

Onshore Wind / Solar Offshore Wind / Others Total

20

Segments: PreussenElektra

PreussenElektra Highlights

27

248

-89%

Q1 2017 Q1 2016

– Lower achieved power prices

– Lower volumes due to outages

– ARC Depreciation

Hedged Prices Germany (€/MWh) as of 31 March 2017

EBIT1 € m

1. Adjusted for non operating effects

€m

Q1 2016 Q1 2017 % YoY

Revenue 453 364 -20

EBITDA 1 270 74 -73

EBIT 1 248 27 -89

thereof Equity-method earnings 21 26 +24

OCFbIT 223 207 -7

Investments 4 5 +25

PreussenElektra

27

26

32

37

2017

2016

2019

2018

100%

94%

30%

100%

21

END improves €1.6 bn due to high cash flow and capital increase

-0.2-0.6

-4.0-4.0

0.8

END Q1 2017

-21.4

END FY 2016

-0.9

-26.3

-24.7

Change in AROs

-21.5

Build & Sell/ Divestment

0.1

Capital Measures

1.4

Investments

0.9

OCF

€ bn

END1 Q1 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.

AROs

Net financial position

Pension provisions

22

Cash conversion at 68% due to seasonal effects in Customer Solutions business

Q1 2017 € bn

Cash Adjustments

0.0

0.9

Interest Payments

Tax Payments

-0.1 -0.1

OCF bIT

1.0

Changes in WC

-0.5

OCF

-0.6

Capex

0.3

FCF EBITDA1

1.5

CCR2: 68%

1. Adjusted for non operating effects, 2. Cash Conversion Rate: OCF bIT / EBITDA 23

Segments

Digitization in practice

Energy Networks 2017: Regulatory & operational update

Germany: preparations for next regulatory

period ongoing

Enhanced customer focus

Modernized regulation framework with yearly RAB true-up and efficiency bonus

Review of RoE for 3rd period finalized

Cost reviews for power & gas ongoing

General efficiency factor to be newly determined

“fuNke”: joint project of German network companies with the aim to completely re-design processes strictly from the customers’ perspective and digitize wherever possible

Example: reduction of preparation time for a home connection offer from 19 to 2 days (first pilot, to be rolled out)

Traditional approach to protect power lines from falling trees: manual identification of danger trees and logging with heavy equipment

New minimally invasive method:

Laser screening and analysis based on digitized data

Cutting only tree tops (from helicopter)

Higher efficiency & customer satisfaction and low impact on environment

25

Sweden

Positive court decision on allowed WACC

Adjustment of network charges to ensure continuously high investment level and ongoing quality improvements

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

26

AAA

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%

27

Enerjisa: Financial highlights

1. Enerjisa net income consolidated at 50% in E.ON Adjusted EBITDA/EBIT/Net Income, FX rates (average) : 2015 TL/EUR 2.79; 2016 TL/EUR 3.40, Adjusted for non-operating effects

Turkey 2015 2016

Revenues (TL m)1 11,827 12,635

EBITDA (TL m)1 1,886 2,474

Distribution 877 1,178

Retail 246 247

Generation 777 1,054

Net Income (TL m)1 285 296

E.ON share of 50% (TL m) 143 148

E.ON share of 50% (€m)2 51 44

Divestment related impairments (one offs) -30 0

Acquisition related depreciation charges (run gate) -24 -24

FX hedges and other -19 3

Contribution to E.ON Adjusted EBITDA/Net Income3 (€m) -22 23

28

Customer Solutions 2017: 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 29

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

30

Customer Solutions: Financial highlights

Energy sales

Adjusted EBIT1 by business pillars

Heat

0.3

0.8

0.3

0.1

2016

2016

2016 ~0.71

Total Adj. EBIT

Energy sales financials

1.2 1.3 2016

Gross Margin

0.8 1.02016

OPEX2

Continental Europe UK

€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 31

Renewables 2017: Build-out fully on track

Rampion (400 MW in UK)

Installations of 116 mono-pile foundations completed

On time and within budget for completion in 2018

Arkona (385 MW in Germany)

Installation of 60 wind turbine foundations planned for 2017

Expected to be fully operational in 2019

US Onshore

US Storage

Radford’s Run (278 MW in Illinois)

Bruenning’s Breeze (228 MW in Texas)

Both farms scheduled to be in commercial operation in December 2017

E.ON actively developing projects in fast-growing energy storage market

Iron Horse (10 MW/2.5 MWh): first grid-scale project to support grid stability in Arizona (planned COD in H1 2017)

Texas Wave: two further projects (10 MW/5 MWh) in Texas on track to be completed in late 2017

Europe Offshore

Repowering projects started in Germany & UK

Won 57 MW auction in Italy with 20 years tariff of €66/ MWh

Europe Onshore

32

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

1

33

Highlights

5.3 GW Operated capacity1

4.6 GW Owned capacity2

1.1 GW Offshore capacity

3.5 GW Onshore + PV capacity

Renewables portfolio of E.ON

1. Operated sites, where E.ON is the operator, regardless the ownership share, 2. Pro rata

2.1 GW

3.2 GW

34

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 35

Discount rates for nuclear provisions

Build up of provisions status quo

t+3 t+100 t+2 t+1 Storage Accretion Decommissioning

Real discount rate: +0.9%

Build up of provisions post KFK1

t+2 t+1 t+n t0

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 36

E.ON Investor Relations contacts

T +49 (201) 184 2806 investorrelations@eon.com

Alexander Karnick T+49 (201) 184 28 38

Head of Investor Relations alexander.karnick@eon.com

Dr. Stephan Schönefuß T +49 (201) 184 28 22

Manager Investor Relations stephan.schoenefuss@eon.com

Martina Burger T +49 (201) 184 28 07

Manager Investor Relations martina.burger@eon.com

Conny Ripphahn T +49 (201) 184 28 34

Manager Investor Relations conny.ripphahn@eon.com

37

Financial calendar & important links

Financial calendar

August 9, 2017 Interim Report II: January – June 2017

November 8, 2017 Interim Report III: January – September 2017

March 14, 2018 Annual Report 2017

May 8, 2018 Interim Report I: January – March 2018

May 9, 2018 2018 Annual Shareholders Meeting

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

38

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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 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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