For a Cleaner World

Equity story of FORTUM – For a cleaner world

Investor / Analyst material September 2020 Disclaimer

This presentation does not constitute an invitation to underwrite, subscribe for, or otherwise acquire or dispose of any Fortum shares. Past performance is no guide to future performance, and persons needing advice should consult an independent financial adviser. Any references to the future represent the management’s current best understanding. However the final outcome may differ from them.

2 Content

Fortum in brief 4 – 7 Energy market transition 8 – 11 Fortum’s strategic route 12 – 14 Half-Year Financial Report 15 – 35 Appendices 36 European and Nordic power markets 37 – 42 Fortum’s power generation 43 – 44 Historical achieved prices 45 Dividend 46 IR contacts 47

3 Fortum in brief

Good position to drive CO2-free power generation in Europe

~60% 3rd largest 2nd largest 66% Increase in Fortum’s of our electricity CO2-free generator nuclear generator CO2-free power in Europe in Europe production in Europe generation was CO2-free in 2019 Fortum in brief

Consolidated Fortum is the third largest CO2-free generator in Europe

5 Source: Company information, Fortum analyses, 2018 figures pro forma. EPH incl. LEAG Fortum in brief Fortum to grow and lead European energy transition

2019 combined comparable EBITDA(1,2) Europe & Russia

Uniper EUR 1.6 bn EUR 3.3 bn Fortum EUR 1.8 bn

Combined power generation (2019)(2) India 18 % 50 % Hydro Nuclear Other ~180 TWh 19 % Coal Gas 1 % Combined power generation assets 12 % Fortum Uniper

1) Comparable EBITDA is based on the Fortum's Comparable EBITDA and Uniper's Adjusted EBITDA as defined in Both Fortum and Uniper Fortum’s and Uniper's financial statements. No impacts from the assumed transaction has been included. 6 2) Based on 2019 reported generation volumes (accounting view in Uniper). Not consolidated in 2019. Fortum in brief

Fortum’s CO2-free power generation increases by ~60% as Uniper is consolidated as a subsidiary

Fortum's power generation, TWh 200 Fortum and Uniper 175 consolidated*:

150 • CO2-free generation +60% 125 • Gas-fired power

100 generation triples

75 • Share of coal-fired CO2-free Gas Coal Other generation ~12% 50 • Share of coal of sales

25 revenue ~1%

* based on 2019 reported figures 0 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 ind.

INDICATIVE GENERATION FOR 2020, NOT OFFICIAL GUIDANCE. Note: Fortum actuals 1990-2019 excluding associated company Stockholm Exergi. 2020 indicative figures adjusted for Nordic wind and Joensuu CHP assets sold in 2020. Uniper’s disclosed 2018 numbers used for indicative consolidation 2020 with the following corrections/assumptions: normal hydrological year, accounting view adjusted to pro forma, French coal assets sold, Datteln 4 7 approximately 2.2 TWh in 2020, no net increase in generation from Beresovskaya 3, coal-to-gas switch 2 TWh, Ringhals 2 closed on 31 Dec 2019. Energy market transition

Europe needs to eliminate CO2 emissions to reach climate goals – this requires actions from all sectors

MtCO2-eq

6 000 Greenhouse gas emissions

5 000

4 000 Coal Power - 40%

3 000 Oil Transport1 -50…-55% - 60%

2 000 Old climate targets Industry2 Gas - 80% 1 000 Buildings3 Others Others4 - 95% 0 Source Sector -100% 1990 2000 2010 2020 2030 2040 2050 Sources: EEA, IEA, Fortum 1 including international aviation and marine 2 8 iron & steel and chemicals are among the biggest contributors 3 residential and commercial heating & cooling 4 non-energy related emissions: industrial processes and product use, waste management, agriculture, fugitive emissions Energy market transition Volatility and uncertainty in the European power market increases the value of flexible assets

Intermittent renewables

Nuclear and coal closures

Increasing role of gas

Volatility and Supply-demand balance uncertainty Increased interconnection between Nordics and Continent

Commodity and CO2 prices

Weather conditions

9 Energy market transition The MSR introduces tightness to carbon market

Linear reduction factor (LRF) tightens the market Market stability reserve restores scarcity Abatement from coal to gas switching by reducing future auction volumes depends on coal and gas prices, together MtCO2 represented by a switching range 2500 Eur/t 60 24% of cumulative surplus Need for abatement

2000 ofCO2eq.) or inventory reduction Switch range CO2 price 50

1500 Mton 40

1000 Cap (excl. aviation) 57%of cap 30

500 20 EU ETS emissions (incl. call on EUAs from aviation)

0 Illustrative volumes( 10 43%of cap Free Auction MSR Auction Deficit Emissions 2010 2012 2014 2016 2018 2020 2022 2024 2026 2028 2030 2032 2034 2036 2038 2040 2042 2044 2046 2048 2050 0 allocation pre- effect post- 2017 2018 2019 2020 MSR MSR

2 • Linear reduction factor (LRF) is the percentage of • When TNAC > 833 Mt, MSR deducts 24% of the • CO2 price has almost quadrupled since baseline supply1 by which the annual supply of TNAC from the auction volume each year placing November 2017, when the final decision was allowances (cap) is reduced every year. LRF is them into the reserve during 2019-2023 reached on the future EU ETS rules, including set at • MSR rate is 12% during 2024-2030 the intake rate of the Market Stability Reserve, • 1.74% for 2013-2020 (equals to a • When TNAC < 400 Mt, MSR releases 100 million which became operational in January 2019 reduction of 38 MtCO2/year) EUAs annually from the reserve adding them to • Market tightness forces the EUA market to find • 2.2% for 2021-2030 (equals to a future auctions ways to reducing demand, including by coal-to- reduction of 48 MtCO2/year) • 900 million back loaded allowances from 2014- gas switching, making the relative gas/coal price • In total, emissions are set to decrease by 43% by 2016 will be transferred into the MSR in 2019-2020 an important price anchor for CO2 2030 vs. 2005 • As from 2023, allowances in MSR above the total • Political risks also continue to play a role in EUA • Next LRF review is scheduled for 2024 number of allowances auctioned during the prices, with developments around Brexit and • 3.03% LRF from 2030 onwards would previous year will be cancelled national coal phase-out policies in particular deliver net zero emissions by 2050 • Next MSR review is scheduled in 2021 being closely watched

2 TNAC = total number of allowances in circulation = Efficiency assumptions in switching range; 1 10 Average annual total quantity of allowances released in 2008-2012. supply – (demand + allowances in the MSR). According to the latest at low-end: gas 52% and coal 34%; publication May 15, 2018 the TNAC corresponds to 1655 million at high-end: gas 45% and coal 42%. O&M allowances. cost assumptions apply. Energy market transition Western European countries exiting coal during this decade

FI: Phase-out • Sweden and Austria closed their last coal plants during 2020 by mid-2029 DE: Phase- SE: Last • France is committed to phase out coal by 2022 out by 2038 plant closed 2020 • Portugal has 2023 as national exit goal, but operators aim for full UK: Phase-out by DK: Phase- closure already in 2021 2024 out by 2030 • UK targets full exit in 2024 by restricting coal plants’ access to NL: Phase-out by market end-2029 • Italy and Ireland have both announced phase-out by 2025

• Greece has stated 2028 as year for full phase-out FR: Phase-out by 2022 • Netherlands and Finland have 2029 as regulated phase-out year, Denmark is committed to 2030 AT: Last plant closed 2020 • Germany to phase out coal by end-2038 latest, possibly already 2035 PT: Phase-out by 2023 • Significant coal countries without explicit exit date include e.g. Spain, Czechia and Poland

– In Spain, significant number of coal plants have recently already closed, and IT: Phase-out by 2025 operators are underway to close down even the rest by mid-2020s GR: Phase-out by 2028 – In Czechia, a multi-stakeholder commission to propose timing for phase-out during 2020 Phase-out from Phase-out from Phase-out from power sector power sector power sector – Poland expects share of coal in the power mix to decline and targets lower- latest by 2025 latest by 2030 latest by 2040 carbon generation in newbuilds, but no timeline for phase-out of coal exists 11 Fortum’s strategic route Portfolio well positioned for energy transition – overall combined share of coal based activities is moderate Coal share from generation and from sales (calculated from disclosed numbers assumptions below)

Fortum 2019 Uniper 2019 Combined Sales, MEUR 5,447 65,804 71,251(1) Coal and lignite generation based sales, MEUR 217 810 1,027(1) Share of coal based sales 4% 1% 1% Generation (power and heat), TWh 103 104 207 Coal and lignite based, TWh 7 20 27 Share of coal based power generation 7% 19% 13%

Note: Fortum sales data includes also heat production, Uniper sales data only power generation. For Fortum avg. coal based power sales price assumption 38 €/MWh and for heat 28 €/MWh; for Uniper avg. coal based sales price assumption 41 €/MWh. 1. Combined sales is presented for illustrative purposes only and do not include possible impacts from aligning differences in accounting principles, effects from co-owned power companies or eliminations of sales between the Groups.

Source: Fortum Sustainability report 2019, page 17 and Fortum Financials 2019, page 3 and Fortum Q4 2019 additional quarterly tables. Uniper Annual Report 2019, pages 2, 110 and 132

12 Fortum’s strategic route Fortum is listed in several Fortum is a forerunner in sustainability sustainability indices and ratings:

We engage our customers and society to drive the change towards a cleaner world. Our role is to accelerate this change by reshaping the energy system, improving resource efficiency, and providing smart solutions. This way we deliver excellent shareholder value.

Increasing CO2-free power generation Annual CO2-free power generation will increase appr. 60% from ~45 TWh to ~70 TWh when consolidating Uniper

Among the lowest specific emissions 96% of power generation in the EU and 59% of total power generation was CO2- free in 2019. Fortum’s specific emissions from power generation in Europe were 27 gCO2/kWh in 2019, total 183 gCO2/kWh.

Growing in solar and wind Targeting a multi-gigawatt wind and solar portfolio, which is subject to the capital recycling business model

MSCI ESG RATINGS DISCLAIMER STATEMENT: THE USE BY FORTUM CORPORATION OF ANY MSCI ESG RESEARCH LLC OR ITS AFFILIATES (“MSCI”) DATA, AND THE USE OF MSCI LOGOS, TRADEMARKS, SERVICE MARKS OR INDEX NAMES HEREIN, DO NOT CONSTITUTE A SPONSORSHIP, ENDORSEMENT, RECOMMENDATION, OR PROMOTION OF FORTUM CORPORATION BY MSCI. MSCI SERVICES AND DATA ARE THE PROPERTY OF MSCI OR ITS INFORMATION PROVIDERS, AND ARE PROVIDED ‘AS-IS’ AND WITHOUT WARRANTY. MSCI NAMES AND LOGOS ARE TRADEMARKS OR SERVICE MARKS OF MSCI. 13 Fortum’s strategic route Fortum’s evolution and historical strategic route

Skandinaviska Birka Energi Länsivoima Elnova Østfold Elverk 50% Fortum →100% 50% → 100% 50% Stockholm Gullspång merged Shares in Divestment of Hafslund Gullspång with Stockholm Energi Stora Kraft Birka Energi TGC-1 E.ON Divestment Fingrid shares 50% → 100% established Finland of Lenenergo shares Shares in Divestment of Länsivoima Lenenergo shares → Lenenergo Oil business heat operations 45% → District heating spin-off TGC-10 outside of 65% IVO FORTUM in Poland → Stockholm

NESTE 1996 1997 1998 2000 2002 2003 2005 2006 2007 2008 2011

2012 2014 2015 2016 2017 2018 2020

Divestment of Divestment of electricity Divestment of DUON Nordkraft wind power Investment in Uniper Divestment of district non-strategic distribution business electricity distribution heating business in heat business business Joensuu Ekokem Restructuring of Divestment of Divestment of electricity ownership in Hafslund ownership in distribution and heat businesses Hafslund Produksjon Majority owner in Uniper Divestment of Turebergs Russian wind power JV small scale hydro Divestment of Grangemouth Recycling power plant Nordic wind capital recycling (80%)

Divestment of Gasum shares

14 Half-year Financial Report January-June 2020

Fortum Corporation 19 August 2020 Priorities for the new CEO

Create a joint Maintain the Foster a strong strategy for the Group’s leadership Fortum-Uniper financial culture based Group strength on openness

16 Q2 2020 – Exceptionally low Nordic spot prices largely offset by solid hedges

• Power and heat consumption stable in the Nordics – Nordic spot price down 84% – Wet hydrology in Q2

– Volatile commodity and CO2 prices • Limited impact of Covid-19 on Fortum group – adverse effects on the Russian operations • Comparable EBITDA at EUR 512 (372) million • Comparable operating profit at EUR 207 (232) million • Fortum’s share of profits from associates of EUR 37 (461) million • EPS at EUR 0.35 (0.69) – Items affecting comparability EUR 0.20 (-0.05) • Net cash from operating activities before change in net margin liabilities negatively affected by change in working capital

17 Q2 2020 highlights Disclosed divestments Limited impact from totalling Covid-19, Russian EUR 1.2 billion operations affected

Ownership in Stockholm Exergi under Focus on short term strategic review actions to maintain financial flexibility

Strategic review of district heating assets in Poland and Baltics Joint strategy continues process during 2020

18 Power demand development in different areas Nordic power demand at 2019 level, demand in other regions affected by Covid-19 Nordics CWE Russia (First price zone) 110 65 190 2019 2020 180 105 60 170 100 55 160 95 50 150 90 GW GW 45 140 85 0% 130 -10% -6% 40 120 80 35 110 75 30 100 70 01/01 01/20 02/08 02/27 03/17 04/05 04/24 05/13 06/01 06/20 07/09 07/28 08/16 09/04 09/23 10/12 10/31 11/19 12/08 12/27 01/01 01/19 02/06 02/24 03/13 03/31 04/18 05/06 05/24 06/11 06/29 07/17 08/04 08/22 09/09 09/27 10/15 11/02 11/20 12/08 12/26 01/01 01/17 02/02 02/18 03/05 03/21 04/06 04/22 05/08 05/24 06/09 06/25 07/11 07/27 08/12 08/28 09/13 09/29 10/15 10/31 11/16 12/02 12/18

Germany France Italy 65 80 45 75 60 70 40 65 55 60 35 -10%

GW 55 GW GW 50 50 30 -13% 45 -17% 45 40 25 35 40 30 20 01/01 01/18 02/04 02/21 03/09 03/26 04/12 04/29 05/16 06/02 06/19 07/06 07/23 08/09 08/26 09/12 09/29 10/16 11/02 11/19 12/06 12/23 01/01 01/18 02/04 02/21 03/09 03/26 04/12 04/29 05/16 06/02 06/19 07/06 07/23 08/09 08/26 09/12 09/29 10/16 11/02 11/19 12/06 12/23 01/01 01/18 02/04 02/21 03/10 03/27 04/13 04/30 05/17 06/03 06/20 07/07 07/24 08/10 08/27 09/13 09/30 10/17 11/03 11/20 12/07 12/24

Source: ENTSO-E hourly reported power demand, 7 day moving avg CWE = Central Western Europe (Germany, France, Netherlands, Belgium) 1 Percentage change in Q2 2020 compared to Q2 2019 9 Risk assessment of Covid-19 impact on Fortum So far very limited effect from Covid-19 on Group level, adverse effects in Russia

Not directly Covid-19 related Directly (also) Covid-19 related • Power price – hedging supports result • Power and heat price – CSA and CCS • Power demand – impacted by weather capacity payments provides stability and predictability conditions and seasonality • Power and heat demand – impacted by • Power demand – affected by industrial weather conditions and seasonality demand in the Nordics • Power and heat demand – affected by • Planning of annual overhauls of nuclear industrial demand plants and regular maintenance of power GENERATION RUSSIA • Negative EUR translation effect - weaker RUB plants • Potential bad debts – affected by customers’ financial situation and solvency

• Heat and power prices – resilience as • Sales price and gross margin – impacted by heating is contracted, power prices power price hedged • Potential credit losses - affected by • Heat demand – impacted by weather CONSUMER customers’ financial situation and solvency conditions and seasonality CITY SOLUTIONS SOLUTIONS • Negative EUR translation effect – weaker • Power and heat demand – affected by NOK, SEK and PLN industrial demand • Recycling and waste business – affected by industrial demand and smoothness in supply chain logistics

20 Nordic water reservoirs

Reservoir content (TWh) 120

100

Norway 20 Average Sweden 2000 2003 2018 2019 2020 2000-2018 Finland 0

Q1 Q2 Q3 Q4

Source: Nord Pool, 2020 by country 21 Fuel and CO2 allowance prices

USD / t Coal price (ICE API2 2021) EUR / tCO 2 CO2 price (EUA DEC 2020) 120 36

100 30

80 24

60 18

40 12

20 6

0 0 Q1/19 Q2/19 Q3/19 Q4/19 Q1/20 Q2/20 Q3/20 Q1/19 Q2/19 Q3/19 Q4/19 Q1/20 Q2/20 Q3/20

EUR / MWh Gas price (TTF 2021) USD / bbl Crude oil pprice (ICE( Brent)) 30 120

25 100

20 80

15 60

10 40

5 20

0 0 Q1/19 Q2/19 Q3/19 Q4/19 Q1/20 Q2/20 Q3/20 Q1/19 Q2/19 Q3/19 Q4/19 Q1/20 Q2/20 Q3/20

Source: Bloomberg 22 1 September 2020 Wholesale power price

EUR/MWh Nordic spot and forward prices

Realised system price 60 Futures 1 September 2020

0 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2018 2019 2020 2021

23 Source: Nord Pool, Nasdaq Commodities Hedging supported Fortum’s achieved power price as power prices fell in the Nordics, Russia power prices declined

Spot price for power in Nord Pool power exchange Spot price for power (market price), Urals hub EUR/MWh RUB/MWh 42 38,6 1 500 35,6 34,7 1 151 35 1 250 1 107 1 081 1 068 1 021 28 1 000

21 750 15,4 -11% 14 500 5,6 7 250 -84% 0 0 Q2/2019 Q3/2019 Q4/2019 Q1/2020 Q2/2020 Q2/2019 Q3/2019 Q4/2019 Q1/2020 Q2/2020

EUR/MWh Generation's Nordic power price Achieved power price for PAO Fortum EUR/MWh 42 37,6 30 27,2 27,5 28,2 35,7 35,0 34,0 33,6 24,5 24,5 35 25

28 20 -4% -10% 21 15

14 10

7 5

0 0 Q2/2019 Q3/2019 Q4/2019 Q1/2020 Q2/2020 Q2/2019 Q3/2019 Q4/2019 Q1/2020 Q2/2020 Changes refer to year-on-year difference (Q2 2020 versus Q2 2019) NOTE: Achieved power price (includes capacity payments) in rubles decreased by 5% 24 Generation Q2 2020 H1 2020 • Lower power generation • Higher power generation – hydro -0.2 TWh, – hydro +1.3 TWh – nuclear -0.3 TWh – nuclear -0.3 TWh • Lower achieved power price, -4% – wind +0.1 TWh (1.4 EUR/MWh), supported by • Lower achieved power price, -8% high hedge levels, spot power (2.9 EUR/MWh) supported by price high hedge levels, spot price -75% -84%

MEUR II/2020 II/2019 I-II/2020 I-II/2019 2019 LTM Sales 450 500 1,024 1,101 2,141 2,064 Comparable EBITDA 212 225 485 484 939 940 Comparable operating profit 173 191 409 414 794 789 Comparable net assets 5,790 6,147 Comparable RONA % 12.8 12.4 Gross investments 34 63 68 101 260 227 Imatra, Finland

25 Russia Q2 2020 H1 2020 • Lower power margin and generation • Lower power margin and generation • Lower CSA payments • Lower CSA payments • Higher heat tariffs • Higher heat tariffs • Q2 2019: Positive one-time effect • FX effect of EUR -4 million related to credit losses • FX effect of EUR -7 million

MEUR II/2020 II/2019 I-II/2020 I-II/2019 2019 LTM Sales 202 239 519 537 1,071 1,053 Comparable EBITDA 74 107 213 242 469 440 Comparable operating profit 37 69 135 168 316 283 Comparable net assets 2,807 3,205 Comparable RONA % 12.3 11.0 Gross investments 47 14 51 19 133 165 Kalmykia, Russia

CSA=Capacity Supply Agreements

26 City Solutions Q2 2020 H1 2020 • Lower result in Norwegian district • Lower heat sales volumes heating business • Lower power sales prices • Improved profit in the recycling and • Lower Norwegian heat sales prices waste business • Pavagada 2 solar plant contributed • Positive result contribution from positively Pavagada 2 solar plant

MEUR II/2020 II/2019 I-II/2020 I-II/2019 2019 LTM Sales 212 228 554 633 1,200 1,121 Comparable EBITDA 32 31 138 168 309 279 Comparable operating profit -15 -15 43 77 121 87 Comparable net assets 3,577 3,892 Comparable RONA % 4.7 3.8 Gross investments 30 136 69 207 322 184 Stockholm Exergi, Värtaverket, Sweden

27 Consumer Solutions Q2 2020 H1 2020 • Competition continued to be intense • Higher sales margins as a result of with high customer churn active development of the service offering following the Hafslund • 11th consecutive quarter of EBITDA integration and subsequent improvement development of the business • Accelerated Covid-19 pandemic increased uncertainty especially in the small and medium size enterprise segment – no impact of credit losses

MEUR II/2020 II/2019 I-II/2020 I-II/2019 2019 LTM Sales 237 346 661 1,015 1,835 1,481 Comparable EBITDA 35 34 82 75 141 148 Comparable operating profit 19 19 51 44 79 86 Comparable net assets 540 640 Customer base, million 2.36 2.43 2.38 Göta Energi branded electricity Gross investments 13 13 28 27 55 56 related insurance service

28 Uniper Q2 2020 H1 2020 • Uniper income statement • In Q1, Fortum’s share of Uniper’s consolidated as of Q2 as a profits as Uniper recorded as an subsidiary associated company in Other Operations • Sales figure inflated by commodity trading business • Uniper contribution to Fortum’s EPS 0.65 (0.50) • Normal seasonality; Q1 and Q4 strong quarters, while Q2 and Q3 are weak quarters

MEUR II/2020 II/2019 I-II/2020 I-II/2019 2019 LTM Sales 11,365 - 11,365 - - 11,365 Comparable EBITDA 184 - 184 - - 184 Comparable operating profit 27 - 27 - - 27 Comparable net assets - 7,035 - - Gross investments 145 - 145 - - 145 Moforsen, Sweden

29 Q2 2020 – Lower power prices and volumes

Comparable operating profit EUR million

• 0.5 TWh lower volumes • 1.4 EUR/MWh • Lower power lower achieved margin and • Uniper price volumes consolidated as • Higher heat tariffs a subsidiary • No increase in credit losses (Q2 2019: positive one-time effect) • FX- effect EUR -7 million

30 H1 2020 – Lower power and heat prices, higher hydro volume

Comparable operating profit EUR million

• 1.0 TWh higher • Lower power volumes margin and • 2.9 EUR/MWh volumes • Lower heat sales • Uniper lower achieved • Lower CSA volume • Higher sales consolidated as price payments • Lower power margins as a a subsidiary • Higher heat prices result of active from Q2 2020 tariffs • Lower Norwegian development of • FX- effect heat prices the service EUR -4 • Divestment of offering million Joensuu following the • Pavagada 2 Hafslund contributed integration and positively subsequent development of the business

31 Income statement

II/2020 II/2019 I-II/2020 I-II/2019 2019 LTM MEUR • Uniper’s income statement consolidated as of Q2 2020 Sales 12,330 1,144 13,687 2,834 5,447 16,300 • Uniper’s sales of EUR 11.4 bn mainly related to energy trading and optimisation Other income 2,134 23 2,157 44 110 2,223 business

Materials and services -11,424 -526 -12,000 -1,443 -2,721 -13,278 Q2 2020 • Items affecting comparability includes Employee benefits -353 -123 -477 -245 -480 -712 • EUR 154 million changes in fair Depreciations and amortisation -306 -141 -456 -278 -575 -753 values of derivatives hedging future cash flow Other expenses -2,174 -146 -2,312 -273 -591 -2,630 • EUR 69 million capital gains (mainly Fortum Recharge AS) Comparable operating profit 207 232 600 640 1,191 1,151 • EUR 71 million of impairment Items affecting comparability 328 -48 527 -98 -81 544 charges and reversals • Net finance costs impacted by Uniper’s 534 184 1,126 542 1,110 1,694 Operating profit finance income Share of profits/loss of associates 37 461 516 572 744 688 and joint ventures H1 2020 Finance costs - net -2 7 -59 -38 -125 -146 • The comparable effective income tax rate was 21.6% Profit before income tax 570 652 1,583 1,076 1,728 2,235 Income tax expense -191 -45 -266 -109 -221 -378 Profit for the period 379 607 1,317 967 1,507 1,857 32 Cash flow and change in financial net debt in H1 2020

+1,090

7 772 147 6

790 977 6 682 1 770 1 020 1 849

4 833

Financial net Acquired Including CF from Investments Divestments Dividends paid Dividends paid FX and other Financial net debt Q4/19 financial debt acquired debt operating paid to minorities debt Q2/20 activities before net 33 margin liab Focus remains on optimising of cash flow and maintaining of financial flexibility

Fortum targets to have a solid investment grade rating of at least BBB to maintain its financial strength, preserve financial flexibility and good access to capital markets for the enlarged group. Focus on cash flow - profitability, optimizing of cash flow and tight prioritising of capital expenditure in the current market and business environment.

Maturity profile 3 250 Total loans of EUR 9,251 million: 3 000 2 750 • Average interest rate of 1.7% (2019: 2.3%) 2 500 for Fortum Group loan portfolio including 2 250 derivatives hedging financial net. 2 000 1 750 • EUR 721 million (2019: 787) was swapped 1 500 to RUB with average interest 7.0% (2019: 1 250 7.8%) including cost for hedging. 1 000 1) • Average interest for EUR loans 0.9% (2019: 750 0.9%). 500 250 0 Liquid funds of EUR 2,403 million 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029+ Undrawn credit facilities of EUR 5,400 million Bonds Financial institutions Other long-term debt Short-term debt

1) In addition, Fortum has received EUR 217 million based on collateral agreements with several counterparties. This amount has been booked as a short-term liability.

34 Outlook

Hedging 2020 Estimated annual capital Income taxation expenditure, including maintenance Generation Nordic hedges: In 2020, the comparable effective and excluding acquisitions corporate income tax rate for For the remainder of 2020: Fortum is estimated to be in the 85% hedged at EUR 34 per MWh EUR 700 million range 20-25%, as Uniper is Note: capital expenditure guidance does not consolidated into Fortum’s results For 2021: include capital expenditure for the Uniper 65% hedged at EUR 33 per MWh segment from the end of the first quarter. (Q1: 50% at EUR 34) The wider range is mainly a consequence of volatility in the Uniper Nordic hedges: Fortum and Uniper share the view of taxation of Uniper’s operations. For the remainder of 2020: the importance of credit rating and take 90% hedged at EUR 29 per MWh it into account when making new For 2021: capex decisions 80% hedged at EUR 27 per MWh (Q1: 70% at EUR 28) For 2022: 40% hedged at EUR 24 per MWh (Q1: 15% at EUR 23)

35 Appendices European and Nordic power markets Still a highly fragmented Nordic power market Fortum has the largest electricity customer base in the Nordics

Power generation in 2018 Electricity retail 400 TWh 16 million customers >350 companies ~350 companies

Vattenfall Others Fortum

Others Vattenfall 36% Statkraft 50%49% E.ON

Ørsted BKK Ørsted Fortum Norlys Agder Energi Fjordkraft Norsk Hydro Uniper Helen PVO Hafslund E-CO Oomi SEAS-NVE Din El, Göteborg

Source: Fortum, company data, shares of the largest actors, pro forma 2018 figures 37 Norlys was formed through the merger of the companies SE and Eniig in Denmark Oomi was formed through the merger of the retail businesses of Oulun Seudun Sähkö, Lahti Energia, Vantaan Energia, Pori Energia and Oulun Sähkönmyynti Oy and its stakeholders Oulun Energia, Tornion Energia, Haukiputaan Sähköosuuskunta, Raahen Energia, Rantakairan Sähkö and Tenergia in Finland European and Nordic power markets Fortum mid-sized European power generation player – major producer in global heat

Power generation Heat production Customers Largest producers in Europe and Russia, 2018 Largest global producers, 2018 Electricity customers in Europe, 2018 TWh TWh Millions

EDF Gazprom Enel Rosenergoatom T Plus RWE Sibgenco EDF Enel Gazprom Inter RAO UES E.ON RusHydro Veolia Inter RAO UES RusHydro Iberdrola Uniper En+ ENGIE Vattenfall EDF ENGIE Fortum DEI EPH Quadra NNEGC Energoat. CEZ Fortum TGC-2 En+ KDHC Vattenfall PGE Minskenergo Iberdrola Vattenfall EDP CEZ PGE Centrica Statkraft Lukoil T Plus EnBW EnBW Tatenergo Sibgengo PGNiG Tauron EDP Kyivteploenergo EPS Ørsted PGE DTEK EPH SSE Verbund Stockholm Exergi Naturgy Axpo E.ON SSE E.ON CEZ Fortum Naturgy Helen DEI TGC-14 Ørsted 0 100 200 300 400 500 600 0 20 40 60 80 100 120 140 0 10 20 30 40

Source: Company information, Fortum analyses, 2018 figures pro forma. 38 EPH incl. LEAG, E.ON incl. Innogy customers. No data from China. European and Nordic power markets Wholesale power prices

EUR/MWh Spot prices Forward prices 100

60 German

50 Nordic

40 Russian* 30

1 September 2020 0 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021

* Including weighted average capacity price

39 Source: Nord Pool, Bloomberg Finance LP, ATS, NP “Market Council”, Fortum European and Nordic power markets Nordic year forwards

Year10 Year11 Year12 Year13 Year14 Year15 Year16 Year17 Year18 Year19 Year20 Year21 Year22

€/MWh 1 September 2020

Year22 70 Year21 28

26 60 24 22

18 50 May June July Aug 2020 2020 2020 2020

0 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020

40 Source: Nasdaq Commodities, Bloomberg European and Nordic power markets German and Nordic forward spread at all time high

Spot price • Nordic system price depressed by the strong hydrological surplus EUR/MWh Nordic and German daily spot prices in Jan 2019 –August 2020 since the beginning of the year. 100 • Continental European spot prices pushed down by dampening gas 80 price and lowered demand by Covid-19 measures especially in April 60 and May. 40 • Supported by lower French nuclear production, low winds and 20 booming EUA price, the Continental spot prices started recovering 0 again in June. -20 Q1 Q2 Q3 Q4 Q1 Q2 Q3 • German-Nordic spread for Q2 realized at 14 €/MWh, a few euros 2019 2020 more than in Q1. Nordic Germany

Forward price EUR/MWh Nordic and German year 2021 forwards in Jan 2019 – August 2020 • The German contract for 2021 delivery is trading close to 40 €/MWh, 60 while corresponding Nordic SYS contract is close to 20 €/MWh. 50 • The German-Nordic spread for 2021 delivery has increased from 11 40 EUR/MWh in the beginning of the year to close to 20 EUR/MWh in 30 July. 20 • German contract is tracking the changes in short-run marginal costs 10 for gas and coal fired condensing units, reflecting the stronger 0 Q1 Q2 Q3 Q4 Q1 Q2 Q3 exposure to fossil fuel and CO2 prices. 2019 2020 • The Nordic contract has become more influenced by continuing Nordic Germany

strong hydrological surplus and weak system spot price. Including 1 September 2020 41 Source: Nord Pool, Bloomberg European and Nordic power markets Nordic, Baltic, Continental and UK markets are integrating – Interconnection capacity growing to over 13 GW by end-2023

• 700 MW COBRAcable from DK to NL has been Several interconnectors are currently 1 under construction or decided to be built Current Nordic/Baltic taken into operation in September 2019 interconnector 2 New 400 MW Zealand – DE connection via Kriegers • New interconnections will increase the projects Flak offshore wind area due in December 2020 rd Nordic export capacity from the current 3 EU’s Connecting Europe Facility co-financing 3 EE- 7.8 GW to over 13 GW by end of 2023 C LV transmission line, due to be ready by end-2020 4 DK1-DE capacity has grown to 2500 MW in July +94% 2020, with further 1,000 MW increase by end-2023 13.4 1,400 MW NordLink as first direct NO-DE link is 5 B due to start commercial operation in March 2021 Norway - UK 1,400 MW North Sea Link (NSL) 11.0 11.0 6 6 is due to be ready by end-2021 3 1,400 MW DK-UK Viking Link has been 5 A 7 8.2 contracted to be built by end-2023 6.9 7 1 8 700 MW LT-PL Harmony Link to be built by 2025 6.2 9 as a part of the Baltic synchronisation project 8 4 2 700 MW Hansa PowerBridge DC link between Interconnection capacity (GW) 9 Sweden and Germany by 2026/2027 A 1200 MW SE3-SE4 South West Link ready Oct New interconnectors New Nordic lines 2020 B 800 MW with first measures on SE2-SE3 by 2023 Existing interconnectors C 800 MW 3rd 400 kV line SE1-FI ready in 2025

2019 2020 2021 2022 2023 2024 Russia Poland Germany 42 Estonia Netherlands Years in the chart above refer to a snapshot of 1st of January each year. Source: Fortum Market Intelligence Lithuania United Kingdom Fortum’s power generation Fortum’s Nordic, Baltic and Polish generation capacity

GENERATION CAPACITY MW NORWAY MW FINLAND MW Hydro 4,677 Price areas Hydro 1,553 NO4, Wind 82 Nuclear 1,487 Nuclear 2,821 NO4 SE1 NO1, CHP 20 CHP 452 CHP 831 Generation capacity 102 Other thermal 565 Other thermal 565 Generation capacity 4,057 Wind 159 SE2 FI NO3 Nordic, Baltic and Polish generation capacity 9,053 NO5 NO1 SWEDEN MW BALTICS AND Figures 31 December 2019 Price areas POLAND MW

NO2 SE3 SE2, Hydro 1,550 Generation capacity, CHP EE The capacity includes the 52 MW Joensuu CHP plant SE2, Wind 75 in Estonia 49 in Finland, which has been sold in January 2020. SE3, Hydro 1,574 in Latvia 34 The capacity includes the 157 MW wind portfolio in LV SE3, Nuclear 1,334 in Lithuania 18 Norway and Sweden, of which a majority 80% DK1 SE4 ownership has been sold in May 2020. SE3, CHP 9 in Poland 233 LT The capacity includes the 23 MW Järvenpää CHP DK2 Generation capacity 4,542 plant in Finland, which has been sold in August 2020. in Latvia, Wind 2

PL Associated companies’ plants (not included in the MWs) Stockholm DENMARK, DK1 MW Exergi (Former Fortum Värme), Stockholm; TSE, Naantali Generation capacity, CHP 16

43 Excluding capacities of Uniper power plants Fortum’s power generation Fortum is growing towards gigawatt scale target in solar and wind power generation

Ånstadblåheia 10 MW PORTFOLIO STATUS CAPACITY, MW FORTUM SHARE, MW SUPPLY STARTS/STARTED (Fortum share) FINLAND 90 18 Nygårdsfjellet ● Kalax Under construction 90 18 (20%) Q1 2021 6 MW (Fortum Sørfjord 97 MW NORWAY 179 113 share) ● Nygårdsfjellet Operational 32 6 (20%) 2006 and 2011 ● Ånstadblåheia Operational 50 10 (20%) 2018 Solberg 15 MW ● Sørfjord Under construction 97 97 Q4 2019-Q3 2020 (Fortum share) Ulyanovsk-2 Kalax 18 MW 25 MW SWEDEN 76 15 (Fortum share) (Fortum share) ● Solberg Operational 76 15 (20%) 2018 RUSSIA 2,009 1,098 35 MW solar Ulyanovsk ● Bugulchansk Operational 15 15 2016-2017 power plants 35 MW ● Pleshanovsk Operational 10 10 2017 ● Grachevsk Operational 10 10 2017 Astrakhan 88 MW Under development 110+6 110+6 2021-2022 Rostov 150+50 MW (Fortum share) ● Ulyanovsk Operational 35 35 2018 (Fortum share) ● Ulyanovsk 2 Operational 50 25 (50%) 1.1.2019 Operational/Under Bhadla 31 MW (Fortum share) ● Rostov 300+100 150+50 (50%) Q1 2020-Q4 2021 Kalmykia 100 MW construction (Fortum share) Amrit 2 MW (Fortum share) ● Kalmykia Under construction 200 100 (50%) Q4 2020 Rajasthan 250 MW ● Astrakhan Under construction 176 88 (50%) Q4 2021 (Fortum share) Kapeli 4 MW (Fortum share) ● Rusnano JV Under development 997 499 (50%) 2021-2023 INDIA 685 581 ● Amrit Operational 5 2 (44%) 2012 ● Kapeli Operational 10 4 (44%) 2014 Pavagada 250+44 MW ● Bhadla Operational 70 31 (44%) 2017 First focus markets (Fortum share) ● Pavagada Operational 100 44 (44%) 2017 Wind power plants ● Pavagada 2 Operational 250 250 Q3 2019 ● Rajasthan Under construction 250 250 Q4 2020 Solar power plants TOTAL 3,039 1,825 Under development 1,113 615 Under construction 913 603 *) NOTE: Table numbers not accounting; tells the size of renewables projects. All not consolidated to Fortum capacities. Operational 1,013 607 All figures in MW and rounded to nearest megawatt. Additionally, target to invest 200 – 400 million euros in India solar and create partnership for operating assets. Under construction includes investment decisions made.

44 Historical achieved prices Hedging improves stability and predictability – principles based on risk mitigation

45 2009 onwards thermal and import from Russia excluded Dividend Capital returns: 2019 EUR 1.10 per share ~ EUR 1 billion

Five year history of dividend per share Fortum's target is to pay a stable, sustainable, and over time increasing dividend of 50-80% of EUR earnings per share excluding one-off items 1,2 1.10 1.10 1.10 1.10 1.10

1,0 Fortum’s dividend policy is based on the following preconditions: 0,8 • The dividend policy ensures that shareholders receive a fair remuneration for their entrusted capital, supported 0,6 by the company’s long-term strategy that aims at increasing earnings per share and thereby the dividend. 0,4 • When proposing the dividend, the Board of Directors 0,2 looks at a range of factors, including the macro environment, balance sheet strength as well as 0,0 2015 2016 2017 2018 2019 future investment plans. Since 1998 Fortum has paid dividends totaling 24% 196% 112% 116% 66% EUR 16.5 billion

46 Next events: January-June Half-year Financial Report on 19 August January-September Interim Report on 17 November The CMD planned for 3 December 2020

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