Cargegie seminar Stockholm - Mikael Lilius - Fortum
Cargegie seminar Stockholm - Mikael Lilius - Fortum
Cargegie seminar Stockholm - Mikael Lilius - Fortum
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Capturing the Russian<br />
growth opportunity<br />
<strong>Mikael</strong> <strong>Lilius</strong><br />
CEO & President<br />
Carnegie Nordic Large Cap Seminar, <strong>Stockholm</strong><br />
March 4, 2008
<strong>Fortum</strong>'s strategy<br />
<strong>Fortum</strong> focuses on the Nordic, Russian and Baltic Rim<br />
markets as a platform for profitable growth<br />
2<br />
Become the leading<br />
power and heat<br />
company<br />
Become the<br />
energy supplier<br />
of choice<br />
Benchmark business performance
A strong position in Nordic countries and Russia<br />
Nordic countries<br />
Generation 51.1 TWh<br />
Electricity sales 58.5 TWh<br />
Heat sales 20.4 TWh<br />
Distribution cust. 1.6 million<br />
Poland<br />
Heat sales 3.5 TWh<br />
Electricity sales 7 GWh<br />
3<br />
Baltic countries<br />
Heat sales 1.2 TWh<br />
Distribution cust. 24,000<br />
Russia – existing<br />
TGC-1 (~25% minority stake*)<br />
Power generation ~6 TWh<br />
Heat production ~8 TWh<br />
Electricity cust. 1.3 million *<strong>Fortum</strong>’s share<br />
Russia – acquisition<br />
TGC-10 (majority)<br />
Power generation 18 TWh<br />
Heat sales 27 TWh
A huge need for new capacity in the Nordic market<br />
Demand and capacity development<br />
in the Nordic market<br />
TWh<br />
500<br />
400<br />
300<br />
200<br />
100<br />
0<br />
2000 2005 2010 2015 2020<br />
Demand<br />
Existing / remaining generation<br />
Committed projects<br />
4<br />
80 TWh<br />
• Electricity demand is expected to increase by ~45<br />
TWh by 2020 compared to 2006<br />
• Estimated retiring generation approx. 35 TWh*)<br />
• Total need for investments roughly 80 TWh<br />
– decisions for another 35 TWh still needed<br />
Committed new production ~45TWh<br />
Thermal<br />
CHP<br />
Wind<br />
Hydro<br />
Nuclear, OL3<br />
Nuclear upgrades<br />
*) Partly decommissioned due to increasing environmental requirements,<br />
partly replaced by more efficient new plants; may still be available as<br />
peak-load capacity.
New capacity will require an EUR 50+ power price<br />
EUR/MWh<br />
110<br />
100<br />
90<br />
80<br />
70<br />
60<br />
50<br />
40<br />
30<br />
20<br />
10<br />
0<br />
1995 -97 -99 -01 -03 -05 -07 -09 -11 -13<br />
Source: Nord Pool<br />
5<br />
Futures<br />
29 February 2008<br />
EUR/MWh<br />
110<br />
100<br />
90<br />
80<br />
70<br />
60<br />
50<br />
40<br />
30<br />
20<br />
10<br />
0<br />
CO2 cost 20 €/ton<br />
Fuel costs<br />
Fixed costs<br />
( variation)<br />
Coal Gas Nuclear Hydro Wind<br />
Clean<br />
coal<br />
Source: IEA "World Energy Outlook 2006"; Elforsk "El från nya anläggningar" 2003,<br />
and <strong>Fortum</strong>.<br />
Adjusted to indicate nominal costs year 2012.<br />
Large variations in cost of new hydro and wind due to location and conditions
<strong>Fortum</strong>´s carbon exposure among the lowest in Europe<br />
g CO 2 /kWh electricity<br />
1200<br />
1000<br />
800<br />
600<br />
400<br />
200<br />
0<br />
DEI<br />
Drax<br />
RWE<br />
6<br />
Scottish & Southern<br />
Edison<br />
EDP<br />
CEZ<br />
Endesa<br />
Union Fenosa<br />
Enel<br />
E.ON<br />
Essent<br />
Dong: Elsam+Energy E2<br />
Vattenfall<br />
Electrabel<br />
PVO<br />
Average 372 g/kWh<br />
Iberdola<br />
Verbund<br />
British Energy<br />
<strong>Fortum</strong><br />
EDF<br />
2006 data<br />
Statkraft<br />
Source:<br />
PWC & Enerpresse, 2007<br />
Changement climatique et Électricité
<strong>Fortum</strong>'s Nordic power production<br />
TWh<br />
60<br />
50<br />
40<br />
30<br />
20<br />
10<br />
Continued increase in CO 2 -free power production through<br />
Nordic investment programme<br />
0<br />
1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005<br />
CO 2 -free production<br />
(nuclear power, hydro power, bio fuels)<br />
7<br />
Other<br />
(peat, gas, coal, other)<br />
2006 2007<br />
After the<br />
investment<br />
programme<br />
• ~9 TWh increase in<br />
CO2 -free<br />
production*<br />
• ~10 TWh increase<br />
in total production*<br />
* compared to 2006
<strong>Fortum</strong> is committed to sustainability<br />
Strong track record in the EU<br />
- Strict specific emission targets<br />
• Electricity: specific emissions below<br />
80 gCO 2 /kWh by 2020<br />
(5-year average)<br />
• Heat: specific emissions (gCO 2 /kWh)<br />
reduced by at least 10% by 2020 from<br />
the 2006 level<br />
in each district heating area<br />
8<br />
Commitment to utilise own<br />
know-how outside the EU<br />
Targets within the EU Commitment outside the EU<br />
• Increase energy and<br />
environmental efficiency<br />
with latest technologies<br />
• Transfer and apply expertise to<br />
Russian production plants<br />
• Agreement on Joint<br />
Implementation projects<br />
in Russia
Russia – The acquisition of Territorial<br />
Generating Company No 10
Delivering growth and value creation<br />
• <strong>Fortum</strong> to acquire a majority stake of 63-76% in TGC-10<br />
– 100% ownership targeted through a mandatory offer to remaining minority<br />
shareholders<br />
• Total consideration EUR 1.7-2.7 billion (737 USD/kW)<br />
– of which the capital increase EUR 1.3 billion to finance the committed investment<br />
program<br />
• Significant increase to <strong>Fortum</strong>’s power generation: TGC-10’s volume 18 TWh/a – <strong>Fortum</strong><br />
52 TWh/a in 2007<br />
• Doubles <strong>Fortum</strong>’s heat sales: TGC-10 27 TWh/a – <strong>Fortum</strong> 27 TWh/a<br />
• Earnings dilutive for two years<br />
• Value creation based on power price development, volume growth and annual efficiency<br />
improvement of at least EUR 30 million<br />
• Fully debt financed, financing fully committed<br />
<strong>Fortum</strong> becomes a major player in the fast developing Russian market<br />
10
Transaction structure<br />
Key steps in the transaction<br />
1<br />
2<br />
3<br />
End-Feb 2008 RAO UES stake sale of TGC-10 shares 29% EUR 0.8 billion<br />
Mid-March 2008 TGC-10 capital increase 34-47%* EUR 0.9-1.3 billion<br />
April-July 2008 Mandatory offer to minorities<br />
Potential squeeze-out<br />
11<br />
24-37% EUR 0.6-1.0 billion<br />
Total purchase price for <strong>Fortum</strong> 100% ~EUR 2.7 billion<br />
Shareholder structure of TGC-10<br />
Pre-transaction Post sale of RAO UES stake and<br />
1 2<br />
capital increase<br />
RAO UES<br />
82%<br />
Minorities<br />
18%<br />
<strong>Fortum</strong><br />
63-76%<br />
Minorities<br />
10-23%<br />
RAO UES minorities<br />
14%<br />
* Depending on the extent minorities will use their pre-emption rights in the share offering<br />
3<br />
Post mandatory offer<br />
<strong>Fortum</strong><br />
63-100%<br />
Minorities<br />
0-37%
TGC-10 – a regional company with huge potential<br />
• Regional power and heat company<br />
with the best capacity utilisation<br />
among TGCs<br />
• Operates in the heart of oil and<br />
gas producing Urals region<br />
• Very high demand growth<br />
• Significant capacity expansion<br />
plans<br />
– Electricity capacity from 3,000<br />
MW (18 TWh/a) to 5,300 MW<br />
• Total annual heat sales exceed<br />
<strong>Fortum</strong>’s heat sales in the Nordic<br />
region<br />
– Heat capacity 15,800 MW<br />
(27 TWh/a)<br />
• 6,100 employees<br />
12<br />
OGK-4 investment potential outweighs the concerns<br />
Argayashsk Chelyabinsk Tobolsk Tyumen 1<br />
Chelyabinsk 1<br />
Chelyabinsk 2<br />
Chelyabinsk 3<br />
Tyumen 2
TGC-10 is a unique investment opportunity<br />
Platform for growth in the<br />
World’s #4 power market<br />
– Liberalisation to increase power prices<br />
– Significant organic growth through<br />
investment programme<br />
– <strong>Fortum</strong> has a unique competence<br />
base in operating in Russia<br />
Attractive asset portfolio with<br />
significant upside<br />
– Medium-sized regional generating<br />
company (TGC) with high capacity<br />
utilisation<br />
– Significant operational efficiency upside<br />
– Power and heat plants located in the<br />
heart of the fast growing Russian oil,<br />
gas and metal producing regions<br />
– Efficient CHP plants<br />
13<br />
TGC-10<br />
A financially attractive<br />
investment<br />
– Material upside in profitability through<br />
power prices and operational<br />
efficiencies<br />
– Significant growth potential through<br />
investments
Significant growth in <strong>Fortum</strong>’s power generation<br />
Power generation, TWh<br />
<strong>Fortum</strong> 52<br />
10.9<br />
70<br />
<strong>Fortum</strong> <strong>Fortum</strong><br />
+ TGC-10<br />
Capacity, GW<br />
13.9<br />
<strong>Fortum</strong> <strong>Fortum</strong><br />
+ TGC-10<br />
Committed TGC-10 investments<br />
<strong>Fortum</strong>’s Nordic capacity investment programme<br />
14<br />
93<br />
<strong>Fortum</strong> + TGC-10<br />
with new investments<br />
17.5<br />
<strong>Fortum</strong> + TGC-10<br />
with new investments<br />
EDF<br />
E.ON + WGC 4<br />
Enel + Endesa + WGC-5<br />
RWE<br />
Vattenfall<br />
Electrabel<br />
Rosenergoatom<br />
Iberdrola<br />
<strong>Fortum</strong>+TGC-10<br />
Hydro WGC<br />
EnBW<br />
Irkutskenergo<br />
British Energy<br />
CEZ<br />
TGC 3<br />
DEI<br />
WGC 2<br />
WGC 1<br />
Statkraft<br />
Annual power generation by largest producers<br />
TWh/a 0 100 200 300 400
TGC-10 will double <strong>Fortum</strong>’s heat volumes<br />
• Main heat supplier in the area, 27 TWh/a<br />
• Mainly CHP, additionally heat boilers<br />
• From networks 1/3 owned and 2/3 operated<br />
• An area with large temperature changes<br />
– cold winters, January aver. -16 °C<br />
– warm summers, aver. +18 °C<br />
• Significant efficiency improvement potential<br />
in heat networks<br />
• Heat pricing regulated, set by local authorities<br />
within the limits set at the state level<br />
• 45% of output sold to households,<br />
28% to industry<br />
15<br />
TGC-10 heat generation and local network<br />
Heat output by customer segment (2007)<br />
Others 5%<br />
Heat resale 15%<br />
State financed<br />
organisations 7%<br />
Households 45%<br />
Industry 28%
Russia is the World’s 4th largest power market<br />
– and growing rapidly<br />
TWh<br />
2,500<br />
2,000<br />
1,500<br />
1,000<br />
500<br />
> 4,000<br />
0<br />
US<br />
Russia is the 4th largest power<br />
market in the World<br />
Source: IEA, 2005,<br />
*) Ministry of Industry and Energy<br />
16<br />
China<br />
Japan<br />
Russia<br />
India<br />
Canada<br />
Germany<br />
France<br />
Brazil<br />
Nordic<br />
UK<br />
2,200<br />
2,000<br />
1,800<br />
1,600<br />
1,400<br />
1,200<br />
1,000<br />
800<br />
Demand for electricity in Russia to<br />
increase 50% by 2020 *)<br />
• Base scenario: 1,700 TWh/a by 2020<br />
• High scenario 2,000 TWh/a by 2020<br />
Demand growth 700+ TWh<br />
before year 2020<br />
2000 2005 2010 2015 2020<br />
2,000<br />
1,700
Russian prices reflect demand and supply<br />
– market-based volume increasing<br />
€/MWh<br />
50<br />
40<br />
30<br />
20<br />
10<br />
0<br />
Russian price development *<br />
2006 2007<br />
2008<br />
• New wholesale market model was launched in September 2006<br />
• Russian government approved liberalisation targeting full implementation in 2011<br />
*) Price includes liberalised energy price and regulated capacity payment<br />
17<br />
TWh/a<br />
1400<br />
1200<br />
1000<br />
800<br />
600<br />
400<br />
200<br />
0<br />
Pace of liberalisation<br />
Regulated<br />
volume<br />
Market-based<br />
volume<br />
2007 2008 2009 2010 2011
Positive power price outlook<br />
• Overall power price increase expected<br />
due to tight demand/supply balance and<br />
planned gas price increases<br />
• The need to build new generation<br />
capacity will lead to convergence<br />
towards the cost of new entry<br />
• Russian reserve margin currently<br />
accounts for only ~11% of installed<br />
capacity<br />
• Regional and technological restrictions<br />
further tighten the demand/supply<br />
balance<br />
* Source: Brokers’ consensus estimates on the Russian power price<br />
** Source: RF Ministry of Industry and Energy<br />
18<br />
Analyst consensus on the Russian power price outlook*<br />
EUR/MWH<br />
50<br />
45<br />
40<br />
35<br />
30<br />
25<br />
20<br />
15<br />
10<br />
5<br />
0<br />
Price index<br />
2,5<br />
2<br />
1,5<br />
1<br />
0,5<br />
0<br />
2007 2009 2011<br />
Russian gas prices as planned by the Government**<br />
2007 2009 2011
Strong regional growth outlook in electricity<br />
Tyumen<br />
South<br />
Moscow and region<br />
Urals w/o Tyumen<br />
North-West<br />
Centre w/o Moscow<br />
Average annual growth in electricity<br />
consumption by region 2005 - 2007*<br />
Siberia<br />
Volga<br />
Far East<br />
19<br />
0 5 10<br />
Source: Rosstat, broker estimates<br />
Current TGC-10 capacity split by region<br />
Tyumen<br />
60%<br />
TGC-10 capacity split post the<br />
investment programme<br />
Tyumen<br />
74%<br />
Urals without<br />
Tyumen<br />
40%<br />
Urals without<br />
Tyumen<br />
26%
Growth through TGC-10’s committed investment programme<br />
• Planned value EUR ~2.2 bn<br />
• Gas-fired production<br />
• Financed by the EUR 1.3 bn share<br />
issue and partly debt/cash<br />
• Commissioning 2010–2013 according<br />
to TGC-10's estimation<br />
• The relative share of electricity<br />
capacity will increase<br />
MW<br />
6,000<br />
5,000<br />
4,000<br />
3,000<br />
2,000<br />
1,000<br />
0<br />
+73%<br />
+2,270 MW<br />
3,020<br />
2007 2013<br />
20<br />
5,290<br />
1,200 MW<br />
Greenfield<br />
Nyagan<br />
210 MW<br />
Tobolsk Tyumen 1<br />
Chelyabinsk 3<br />
220 MW<br />
190 MW<br />
Tyumen 2<br />
450 MW
<strong>Fortum</strong> has long experience of successful co-operation with<br />
Soviet Union and Russia<br />
1950 1960 1970 1980 1990 2000<br />
Construction of hydro power<br />
plants in Kola area<br />
*) Including single largest purchase agreement of uranium with TVEL<br />
21<br />
Construction of Loviisa<br />
nuclear power plant<br />
Electricity import to Finland �<br />
Nuclear fuel import to Finland *) �<br />
Construction of North-West<br />
CHP in St. Petersburg<br />
Lenenergo shareholding<br />
Automation & information system deliveries to<br />
thermal power plants )<br />
Permanent presence in Moscow & Safety improvements for nuclear<br />
St. Petersburg �<br />
power plants<br />
St Petersburg Sales Co<br />
Main Power Circuits<br />
TGC-1<br />
Agreement Joint<br />
Implementation of Kyoto<br />
Protocol with TGC-1
<strong>Fortum</strong> brings competence<br />
• Strong competence and over 10-years experience in liberalised power<br />
markets – trading, risk management<br />
• Excellence both in optimisation and performance of power plants;<br />
availability and energy efficiency<br />
• Benchmark operation of different production forms – efficiency with<br />
proper environmental approach<br />
• Strong competence in combined heat and power (CHP)<br />
• Global experience in operation and maintenance<br />
• Long track record in cooperation with Russia<br />
Efficiency improvements of at least EUR 30 million annually<br />
Sources: <strong>Fortum</strong>, VGB/Germany, NERC/USA<br />
22
Financial summary<br />
• EPS dilution for two years<br />
• <strong>Fortum</strong>’s Balance sheet remains strong<br />
– Net debt/EBITDA below 3.0x<br />
• <strong>Fortum</strong>'s EUR 3 billion Nordic capacity investment programme to<br />
continue as planned<br />
• Financial flexibility retained<br />
23
Conclusions
<strong>Fortum</strong> delivers on its strategy<br />
• Russian economic growth and <strong>Fortum</strong>’s know-how will create<br />
one of Russia’s most efficient power generators<br />
• TGC-10 operates in the heart of oil and gas producing region in<br />
the Urals with very fast growth<br />
• Significant potential for efficiency and environmental<br />
improvements<br />
• <strong>Fortum</strong> has substantial long-term experience in the Russian<br />
energy market<br />
• <strong>Fortum</strong> retains its financial flexibility and its capability for further<br />
investments<br />
25<br />
<strong>Fortum</strong> well positioned for the fast growing<br />
Russian power markets
<strong>Fortum</strong> is well positioned for the future<br />
• Focus on the Nordic and Baltic areas, Russia and Poland<br />
– well positioned in Russia<br />
• Climate change mitigation creates business opportunities<br />
– flexible and climate-benign production portfolio<br />
– investments in new CO 2-free production capacity<br />
– efforts in developing new technologies<br />
• Strong financial position<br />
26
Supplementary material
Transaction timetable<br />
Feb 28 Bidding day (submission of offers for Secondary Shares)<br />
Feb 29 BoD TGC 10 set the Final Offer Price, public<br />
announcement of the Final Offer Price<br />
March 17 - 21 Payment of Primary shares<br />
March 18 - 26 Transfer of Primary shares<br />
March 21 – April 15 Payment and transfer of Secondary shares<br />
June/July TGC-10 EGM to nominate the Board of Directors<br />
June-August Mandatory offer completed<br />
29
TGC-10 – overview of the asset base and investment plans<br />
• A portfolio of ~3,000 MW installed<br />
electricity capacity<br />
• The highest load factor of all TGCs<br />
• Committed investment programme<br />
of an additional 2,270 MW of<br />
electricity capacity<br />
• TGC-10 owns a 925 km heat<br />
distribution network and operates<br />
a total network of 2,175 km<br />
30<br />
Chelyabinsk<br />
Power capacity 1,106 MW<br />
Heat capacity 7,299 MW<br />
Boiler heat capacity 910 MW<br />
Tyumen<br />
Kurgan<br />
Khanty-Masiysk<br />
Power capacity 1,679 MW<br />
Heat capacity 6,386 MW<br />
Electricity capacity (MW) Heat capacity (MW)<br />
Plant Fuel type Existing Planned Total Existing Planned Total<br />
Tyumenskaya CHP-2 Gas 755 450 1,205 1,640 399 2,039<br />
Tyumenskaya CHP-1 Gas 472 190 662 1,641 297 1,938<br />
Tobolskaya CHP Gas 452 210 662 3,105 3,105<br />
Chelyabinskaya CHP-3 Gas 360 220 580 1,270 170 1,440<br />
Chelyabinskaya CHP-2 Coal, gas 320 320 1,112 1,112<br />
Argayanskaya CHP Coal, gas 195 195 866 866<br />
Chelyabinskaya CHP-1 Coal, gas 149 149 1,560 1,560<br />
Chelyabinskaya GRES Gas 82 82 2,491 2,491<br />
Nyaganskaya GRES Gas 1,200 1,200 279 279<br />
Boilers - 910 910<br />
Kurgan Generation (49%) Gas 235 235 1,149 1,149<br />
TGC-10 3,020 2,270 5,290 15,744 1,145 16,889
Historical Russian transaction multiples<br />
(enterprise value) €/kW<br />
€/kW<br />
600<br />
500<br />
400<br />
300<br />
200<br />
100<br />
0<br />
466<br />
445<br />
31<br />
367<br />
497<br />
543<br />
512<br />
344<br />
WGC 3 TGC 3 TGC 5 WGC 5 WGC 4 TGC 1 WGC 2 TGC 8 TGC 9 TGC 12 WGC 6 TGC 3 TGC 10<br />
Calculated with €/RUB exchange rate at each transaction day. RUB/kW figure based on transaction price at each day<br />
406<br />
434<br />
264<br />
336<br />
€/RUB at each<br />
transaction day<br />
528<br />
490
Historical Russian transaction multiples<br />
(enterprise value) RUB/kW<br />
RUB/kW<br />
25 000<br />
20 000<br />
15 000<br />
10 000<br />
5 000<br />
0<br />
16 052<br />
32<br />
15 625<br />
12 768<br />
17 338<br />
19 098<br />
17 986<br />
12 148<br />
14 410<br />
15 571<br />
9 404<br />
11 937<br />
18 985<br />
17 817<br />
WGC 3 TGC 3 TGC 5 WGC 5 WGC 4 TGC 1 WGC 2 TGC 8 TGC 9 TGC 12 WGC 6 TGC 3 TGC 10
Russian power reform completed in July 2008<br />
Ownership structure after liberalisation<br />
State<br />
100%<br />
Nuclear<br />
>75%<br />
FGC<br />
75%<br />
System<br />
Operator<br />
50%<br />
Hydro-<br />
WGC<br />
TGC-10 key financials<br />
MEUR LTM Q3/07 2006 2005<br />
Sales<br />
EBITDA<br />
EBIT<br />
Net profit<br />
Balance sheet total<br />
Interest-bearing net debt<br />
€/RUB exchange 35.986 (31.12.2007)<br />
34<br />
590<br />
55<br />
26<br />
12<br />
677<br />
61<br />
493 430<br />
42 55<br />
15 29<br />
574<br />
8 19<br />
542<br />
40 -3
Attractive operating characteristics<br />
• Power plants located in fast growing<br />
areas with oil, gas and metal<br />
production<br />
• Efficient combined heat and power<br />
(CHP) generation<br />
• Significant efficiency improvement<br />
potential<br />
• Significant investment programme<br />
further increases efficiency and power<br />
generation capacity<br />
• Potential for CO2-emission reductions<br />
through Joint Implementation<br />
1) Average fuel efficiency = generation volume / fuel consumption<br />
2) Load factor = actual generation / maximum generation with full load all time<br />
35<br />
Average fuel efficiency<br />
45 %<br />
40 %<br />
35 %<br />
30 %<br />
25 %<br />
20 %<br />
15 %<br />
10 %<br />
5 %<br />
0 %<br />
1)<br />
TGC 3<br />
TGC 10<br />
Load factors<br />
80 %<br />
70 %<br />
60 %<br />
50 %<br />
40 %<br />
30 %<br />
20 %<br />
10 %<br />
0 %<br />
2)<br />
TGC 10<br />
TGC 3<br />
TGC 1<br />
TGC 12<br />
TGC 5<br />
TGC 9<br />
TGC 7<br />
TGC 8<br />
TGC 13<br />
TGC 14<br />
TGC 6<br />
TGC 13<br />
TGC 11<br />
TGC 5<br />
TGC 2<br />
TGC 6<br />
TGC 4<br />
TGC 11<br />
TGC 8<br />
TGC 1<br />
TGC 12<br />
TGC 7<br />
TGC 9<br />
TGC 4<br />
TGC 14<br />
TGC 2
Integration built on solid experience<br />
• Integration team headed by Tapio Kuula<br />
• Experienced professionals committed to the integration team with key<br />
competencies in<br />
– after-transaction issues<br />
– power generation<br />
– heat production<br />
– power market<br />
– implementation of investment programme<br />
– business control and group functions<br />
• Transfer of <strong>Fortum</strong>’s business culture and systems<br />
– management and leadership co-operation and development<br />
36
The transaction is debt financed<br />
• Maximum consideration EUR 2.7 billion, of which the capital increase<br />
EUR 1.3 billion<br />
• Adjusted Net Debt / EBITDA at acquisition 2.8x<br />
• Financial flexibility and efficient capital structure retained<br />
• Committed financing is fully in place<br />
– new committed credit facility of EUR 3.5 billion obtained to be<br />
syndicated in the bank market<br />
– two tranches: 3-year term-loan and 5-year revolving credit facility<br />
37<br />
<strong>Fortum</strong> retains its financial flexibility
Maintaining a solid capital structure<br />
Capital employed<br />
Interest-bearing net debt<br />
EBITDA<br />
Adjusted Net debt / EBITDA 3)<br />
38<br />
Current 1)<br />
Pro forma 2)<br />
13,544 16,412<br />
4,466 5,954<br />
2,298 2,353<br />
2.2 2.8<br />
1) <strong>Fortum</strong> 2007<br />
2) Pro forma is based on full-year 2007 of <strong>Fortum</strong> and LTM Q3/2007 of TGC10 assuming 100% ownership based on bidding price.<br />
3) Based on EBITDA excluding capital gain from sale of <strong>Fortum</strong>'s holding in Lenenergo amounting to 232 MEUR.
<strong>Fortum</strong> will improve asset efficiency<br />
• Improving<br />
– fuel efficiency<br />
– plant availability<br />
– optimization of district heating production<br />
– refurbishing existing power plants and<br />
heating networks<br />
• Improving specific CO2 emissions<br />
• Utilising modern technologies<br />
• TGC-1 experience<br />
• Extensive power plant O&M experience<br />
1) Energy availability = available generation capability<br />
39<br />
%<br />
100<br />
95<br />
90<br />
85<br />
80<br />
75<br />
70<br />
Energy availability, gas-fired power plants<br />
95 96 97 98 99 00 01 02 03 04 05 06<br />
Meri-Pori<br />
(modern site)<br />
Operation and maintenance costs<br />
Modeled Europ.<br />
best practice<br />
US peer plants,<br />
average<br />
US peer plants,<br />
best quartile<br />
USA Germany <strong>Fortum</strong><br />
100%<br />
145%<br />
180%<br />
395%
<strong>Fortum</strong> has extensive international O&M experience<br />
• International O&M 4300 MW e + 900 MW th<br />
electricity/ district heat/ steam<br />
Grangemouth (UK) gas 140 / - /250 MW<br />
Bristol (UK) gas 50 MW<br />
Exeter (UK) gas 50 MW<br />
Croydon (UK) gas 50 MW<br />
Heartlands (UK) gas 100 MW<br />
Hythe (UK) gas 55/-/62 MW<br />
Sullom Voe (UK) gas 95 /-/ 330 MW<br />
Allington EfW (UK) waste 500,000t/a 34 MW<br />
Lakeside EfW (UK) waste 420,000t/a 32 MW<br />
Herbrechtingen (Germany) bio 16 /- / 25 MW<br />
Trianel (Germany) gas 800 MW<br />
Knapsack (Germany) gas 800 MW<br />
Al Taweelah (UAE) gas 2,070 MW<br />
Panjin Liaohe (China) coal 44 /- /250 MW<br />
• Technical support agreement<br />
Tanjung Jati (Indonesia) coal 1,320 MW<br />
Kapar (Malaysia) coal, gas, oil 2,440 MW<br />
Dhofar (Oman) distribution<br />
Port Said Suez (Egypt) gas 683 MW<br />
40<br />
Great Britain<br />
Germany<br />
NW Russia<br />
Baltic countries<br />
UAE<br />
Oman<br />
China<br />
Malaysia<br />
Thailand
<strong>Fortum</strong>'s Nordic investment programme<br />
41<br />
• Olkiluoto 3, Finland, nuclear<br />
• Swedish nuclear<br />
• Suomenoja, Finland (CHP)<br />
• Värtan, Sweden (bio CHP)<br />
• Järvenpää, Finland (bio CHP)<br />
• Brista, Sweden (waste CHP)<br />
• Refurbishing of existing hydro assets<br />
• Wind power, Sweden<br />
Value of the investment programme around EUR 3 billion<br />
of which ~90% CO 2-free<br />
In addition<br />
• Automated meter management (EUR 240 million)<br />
• Security of supply in distribution (EUR 700 million)<br />
Total<br />
~ 1,300 MW