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The Nordic power market
Tapio KuulaSenior Vice PresidentFortum Corporation
Fortum Investor/Analyst day 200627 November, London
2
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.
3
Contents
• The functioning of the Nordic power market• Main drivers for Nordic power price• Integration to other European markets
4
Large customers
Market design is as important as infrastructure development
Retail marketRetail market
Retail companies
Competitive businesses
DistributionRegulated monopolies
Transmission and system services
Nordic wholesale
market
Nordic wholesale
market
Nord Pool and bilateral
Generation
Independent TSO Independent DSO
Small customers
5
Retail marketRetail market
Wholesale market price is a result of balance in liquid Nordic market – retail markets still mainly national
Large customers
Retail companies
Competitive businesses
Nordic wholesale
market
Nordic wholesale
market
Nord Pool and bilateral
Generation
Small customers
Supply DemandWholesaleprice
Supply DemandRetailprice
6
2005 figures; the effects of the structural changes in Denmark and in Finland have been taken into account.
Fortum
Dong Energy
Vattenfall
others
E.ON53%Hafslund
PlusenergiSEAS-NVE
HelsinkiFjordkraft
Östkraft
Fortum
Vattenfall
Dong Energy
others
Hafslund
E.ON51%
HelsinkiSEAS-NVE
StatkraftGöteborg
BKK
Fortum
Vattenfall
Dong Energy
others
Statkraft
29%
E.ON
PVO
E-CO Energi
Helsinki
Norsk Hydro
BKK
Still a highly fragmented Nordic power market
Distribution
14 million customers~ 500 companies
Retail
14 million customers > 450 companies
Generation
395 TWh> 350 companies
7
Price volatility on a year-to-year basis is driven by the annual generation mix - the system is hydro driven
Condensing power
0
50
100
150
200
250
300
350
400
450
1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005
TWh/a
Nuclear power
CHP
Wind power
Hydro power
0
5
10
15
20
25
30
35
40
Market price
EUR/MWh
Net import
Nordic total
production
8
Competitiveness demonstrated through power prices
Source: Eurostat 7/2006; prices for electricity and distribution excl. taxes 1/2006
€/MWh
020406080
100120140
Latv
iaEs
toni
aN
orw
ayFi
nlan
dC
roat
iaBu
lgar
ia
Aust
ria
Pola
ndLi
thua
nia
Swed
en
Gre
ece
Hun
gary
Rom
ania
Mal
taH
olla
ndC
zech
R.
Spai
nPo
rtuga
lSl
ovak
iaBe
lgiu
m UK
Ger
man
yIre
land
Italy
Cyp
rus
cent/kWh
05
10152025
Gre
ece
Finl
and
Swed
en
Fran
ce
Spai
n
Aust
ria UK
Den
mar
k
Nor
way
Belg
ium
Hol
land
Irela
nd
Portu
gal
Ger
man
y
Luxe
mbo
urg
Italy
Industry 50 GWh/a
Households 3,500 kWh/a
Source: Reuters, OMEL
Yearly moving average spot price Forwards
€/MWh
German
Spanish
Nord Pool
Dutch
UK
0
102030405060708090
100
2001 2002 2003 2004 2005 2006 2007 2008 2009Nov 17, 2006
9
The liquidity of the Nordpool financial market ensures the credibility of the forward-looking price signals
• Transparent price formation and market information
• Hundreds of actors, liquid market
• Physical spot trade60% of Nordicconsumption*
• Financial clearingmore than five timesthe Nordicconsumption
• Strict insider rules
Nord Pool volume development
TWh
400
300
200
100
0
400
300
200
100
0-93 -94 -95 -96 -97 -98 -99 -00 -01 -02 -03 -04
500
1.000
2.000
3.000
-05
Spot trade
Financial/bilateral clearing
Nord Pool members
2,658
3,108
1,764 1,797 2,156
Mem
bers
* Nord Pool 1-9/2006
10
Information on the status of generation and network (among other key facts) is publicly available
Nord Pool provides a multitude of information readily available online…
Planned outages in Finland 9.10. – 16.10.
UnitEffect (MW)
* Fingrid, for example, reports all operational failures in transmission network online instantlySource: Fingrid; Nord Pool
Period
Inkoo B1
Kristiina B1
Inkoo B3
Meri-Pori B1
Tahkoluoto G1
230
210
230
565
240
10.10.-10.10.
9.10.-16.10.
9.10.-11.10.
9.10.-13.10.
9.10.-9.10.
… the Finnish TSO, Fingrid, also publishes all information online
Example from Fingrid’s state of the power system report*
11
Demand response to short-term price peaks is often the most efficient "reserve capacity" on the market
Source: SSB (Statistic Norway), Nord Pool
2,0
2,2
2,4
2,6
2,8
3,0
3,2
Aug-02 Feb-03 Aug-03 Feb-04 Aug-04 Feb-05 Aug-05 Feb-060
100
200
300
400
500
600
Aug2002
Feb2003
Aug2003
Feb2004
Aug2004
Feb2005
Aug2005
Feb2006
Example from Norwegian metals industryEnergy consumption in metals production per month (TWh)
Average Nord Pool spot price per month (NOK/MWh)
12
Strong focus on market operations through organisation structure in Fortum
Physicaland
financial Nordic power market
Generation
Focus on technical, environmental and asset productivity issues of the generation portfolio.
Portfolio Management & Trading (PMT)Focus on market operations of the generation portfolio. Physical and financial trading.
13
Contents
• The functioning of the Nordic power market• Main drivers for Nordic power price• Integration to other European markets
14
An increasing trend in Nordic power prices
0
10
20
30
40
50
60
70
80
90
1995 1997 1999 2001 2003 2005 2007 2009 2011
EUR
/ M
Wh
System Price Forward Curve 21.11.2006
15
Fundamental Price Drivers
• Demand-Supply balance– Tightening all over Europe– Need for new capacity
• Weather: precipitation, temperature and wind• CO2-allowance prices - Kyoto period and beyond• Fuel prices• Convergence of power markets on European level
– Increasing interconnection capacity– Common need for new capacity; common cost for building it– Increasing dependence on condensing power - coal and gas?– EU-wide CO2-trading increases correlation between markets
16
Spot price is based on supply and demand balance
SUPPLYHydro production
• Uncertain future volumes• Long term profit maximisation sets the
value• Storable and run of river hydro power
Thermal production• CHP, nuclear, condense• Available capacity• CO2 price changes• Fuel price changes
Exchange with Europe• Price difference between Nordic and
European market
DEMAND• Seasonal variation, hourly profile• Temperature dependence• Price elasticity
Volume
PriceOil condense
NuclearHydro
CHP
Demand Supply
Coal condense
17
Electricity demand in Nordic countries 1980-2005
GWh/a
Source: Nordel
0
50 000
100 000
150 000
200 000
250 000
300 000
350 000
400 000
450 000
1980
1982
1984
1986
1988
1990
1992
1994
1996
1998
2000
2002
2004
SwedenNorwayFinlandDenmark
18
0
20
40
60
80
100
120
140
160
Denmark Norway Sweden Finland
Other
Households
Retail and services
Industries
TWh/a
Source Nordel
Electricity demand in Nordic countries 2005
19
GWh/a
Lähde:: Nordel
Power generation and procurement 2000-2005
0
50 000
100 000
150 000
200 000
250 000
300 000
350 000
400 000
450 00019
80
1982
1984
1986
1988
1990
1992
1994
1996
1998
2000
2002
2004
Imports
Wind
Condensing and CHP
Nuclear
Hydro
20
TWh/a
* )
*) incl. condensing productionSurce: Nordel
Power generation in Nordic countries 2005
Total 395 TWh
0
20
40
60
80
100
120
140
160
Denmark Norway Sweden Finland
Wind
Gas
Condensing
CHP, industry
CHP, districtheatingNuclear
Hydro
21
European wide ...
0500
1,0001,5002,0002,5003,0003,500
2000 2005 2010E 2015E 2020E
TWh
900 TWh
New capacity will be needed to meet the demand growth
... and in the Nordic market
Existing/remaining capacity DemandSource: Eurprog 2005; Europe: EU25
TWh
0
100
200
300
400
500
2000 2005 2010E 2015E 2020E
80 TWh
22
Forward prices reflect the foreseeable supply-demand balance and are indicators of future electricity price
0
10
20
30
40
50
60
70
80
Source: IEA "World Energy Outlook 2006"; Elforsk "El från nya anläggningar", 2003. Adjusted to indicate nominal costs year 2011.Large variations in cost of new hydro and wind due to location and conditions
Source: Nord Pool, Fortum
Coal Gas Nuclear Hydro Wind
EUR/MWh
Fuel costsFixed costs( variation)
CO2 cost 15 €/ton
1995 -97 -99 -01 -03 -05 -07 -09 2011
EUR/MWh
0
10
20
30
40
50
60
70
80
Futures23 Nov 2006
23
Hydro remains a key driverW
ater
+ S
now
com
pare
d to
nor
mal
-50
-40
-30
-20
-10
0
10
20
30
0
10
20
30
40
50
60
70
80
Nor
dic
spot
pric
e
EUR/MWhTWh
Nordic spot price
Water + snow balance
2000 2001 2002 2003 2004 2005 2006
24
100
120
140
160
180
200
220
240[TWh]
0
10
20
30
40
50
60
70
80
90
100[EUR/MWh]
Yearly average inflow 1990-2000Water inflow 52 cum weeksHydro production 52 cum weeksWeekly System Price
2003 2004 2005 2006
Cumulative inflow below normal due to poor snow accumulation last winter plus dry summer and autumn this year
25
Norpool spot prices clearly above 2004-2005 levels
0
10
20
30
40
50
60
70
80
90
1/1 1/2 1/3 1/4 1/5 1/6 1/7 1/8 1/9 1/10 1/11 1/12
Day
Avg
Pric
e E
UR
/ M
Wh
2004 2005 2006 44,24 EUR / MWh November 22, 2006
26
NordPool year forwards
27
Nordic water reservoirs
Source: Nord Pool - Norway and Sweden reservoirs
28
Hydro power production in Norway and Sweden
0
1
2
3
4
5
6
1 5 9 13 17 21 25 29 33 37 41 45 49 53
Prod
( TW
h / w
k )
0
40
80
120
160
200
240
Cum
Pro
d ( T
Wh
)
2004 2005 2006 cum. 2004 cum. 2005 cum. 2006
29
CO2 important in short and long term
• Weather: temperature, wind and precipitation - e.g., weather in Spain affects all European CO2 and power markets
• Fuel prices: coal to gas switch (gas linked to oil, too), biomass• Kioto mechanisms in acquiring additional emission allowances:
CER-credits (Certified Emission Reductions) from CDM projects in developing countries (Clean Development Mechanism); from year 2008 ERU credits (Emission Reduction Units) from JI projects (Joint Implementation) mainly in Eastern Europe and Russia, as well as AAU allowances (Assigned Amount Units) from states being under their Kyoto caps ("hot air")
• Allocation of emission allowances for the period 2008-12: tightness to existing plants, free allowances to new plants, purchases by governments
• Possibilities to develop CO2-free energy production
30
0
10
20
30
40
50
60
70
01/05 03/05 05/05 07/05 09/05 11/05 01/06 03/06 05/06 07/06 09/06 11/06
EUR/MWh
CO2 price was driving both Nordic and German power forwardprices until May 2006
2005 2006
German price Year 2007
CO2 price Year 2007
Nordpool Price Year 2007
31
Emissions trading impacts marginal costs of generation and the European merit order
With carbon at € 20/tCO2Without carbon constraint
Source: Projected Costs of Generating Electricity, 2005 Update; OECD/IEA
32
CO2 prices for 2007 have declined clearly more than for 2008
0
5
10
15
20
25
30
35
Aug-05 Sep-05 Oct-05 Nov-05 Dec-05 Jan-06 Feb-06 Mar-06 Apr-06 May-06 Jun-06 Jul-06 Aug-06 Sep-06 Oct-06 Nov-06
EUR
/ to
n of
CO
2
CO2 price 2007, ECX CO2 price 2008, ECX
33
Phase I Phase II
- 6%
1920
1960
2000
2040
2080
2120
2160
2005 2006 2007 2008 2009 2010 2011 2012
National Allocation Plan 2005-2012
Phase IThe realised emission in 2005 was 90 Mton less than the yearly average allocation in Phase I
The market price is currently ~8 EUR
Phase IIThe guideline from European Commission is a reduction of 6% between the phases. The final allocation plan is expected to be published in December
Emission Market - tighter allocation plan in phase II
- 6%
CO2 price
Phase I Phase II
2005 2006 2007 2008 2009 2010 2011 2012
Forward
0
10
20
30
40
50
EUR
/t C
O2
34
05
101520253035
EUR
/ tC
O2
020406080
100120
GB
p / t
herm
01020304050607080
USD
/ bb
l
0102030405060708090
USD
/ t
Gas price (UK)
CO2 priceCoal price
Oil price
2004 2005 20082006 20072004 2005 20082006 2007
2004 2005 20082006 20072004 2005 20082006 2007
Fuel prices affect the CO2 price
Source: ; market prices 17 November 2006; 2006-2008 future quotations
Markets expectcoal price to stayabove 60 USD/t
Futures show a slightly decreasing trend?
Oil futures at a highlevel
In combination of high coal
price and low gas price the coal to gas switch is
preferable
35
Summary on power price drivers
• Main prices drivers are supply/demand balance, hydrological situation and prices for CO2 allowances
• In the Nordic area year 2006 hydrological balance has turned into deficit due low inflows resulting in higher prices than previouscouple of years
• During 2006 prices for emission allowances have dropped to lowest levels since early 2005 when the market opened. The emissions allowance market faces a discontinuity point when the Kyoto period starts in the beginning of 2008. Negotiations on Post-Kyoto are ongoing
36
Contents
• The functioning of the Nordic power market• Main drivers for Nordic power price• Integration to other European markets
37
Today, physical constraints in transmission divide Europe into price regions – "regional markets"
Nordic
UK
IberiaCore Central
Europe
Italy
South-EastEurope
Centrel
High congestion from Central Europe to
Nordic, UK and Iberia
NL/BE
High congestion from Core Central Europe to BENELUX.
Integration of BENELUX to Core Central Europe is first in
line to proceed.
High to medium congestion from Centraland South-East Europe
to Central Europe
Medium to high congestion from Central
Europe to Italy and particularly within Italy
Baltics
Sources: Nord Pool, EEX, Powernext, EXAA, OMEL,GME, POLPX, Reuters
50
52
50
52
63
59
53
75
30
29
46
47
47
57
52
55
58
28
0 20 40 60 80
Nord Pool
Germany
France
Austria
UK
TheNetherlands
Spain
Italy
Poland
EUR/MWh
2006 (1-10) 2005
Average wholesale electricity prices 2005 and 2006, EUR /MWh
38
European integration continues - Market coupling between Denmark and Germany
PRESS RELEASE 16/2006, (Lysaker, 02 November 2006) Market coupling between Denmark and GermanyThe European Energy Exchange AG, Nord Pool Spot AS, Energinet.dk, Vattenfall Europe Transmission GmbH and E.ON NetzGmbH have adopted a Memorandum of Understanding concerning market coupling.The companies agree that the integration of wholesale electricity markets requires a more efficient utilization of existing interconnectors. During the next three months an implicit auction concept shall be developed. The aim is to introduce an implicit auction, i.e. the joint allocation of energy and capacity, for the daily cross-border capacity allocation for both interconnectors between Denmark and Germany (i.e. the connection between E.ON Netz and Jutland as well as the KONTEK interconnector).
39
Nordic market is becoming more integratedinto Europe
• NorNed (Norway - The Netherlands) by2008
• Estlink (Estonia - Finland) by 2007• Nordel priority projects enhance Nordic
power market integration– Snitt4, Sweden. Technical solutions under
investigation. In operation 2011– FennoSkan 2 (800MW), decided. Operation 2010– Nea-Järpströmmen (200MW), decided. Operation
2009– Skagerrak (600MW). To be investigated further– Store Baelt (600MW). Applications before year-end
2006 (operational ~2010)
• In 2005, Nord Pool introduced a spot market area "KONTEK" to facilitate market coupling on the Kontek cable
2750 1500
1300
300
5060
900
2200
900
1200
600
1000200
125
600
10001600
2500
3500
1700
1500800
500
70
1040
1600
550600
1200
3800
700
350
600
+100
100+ 200
1000
600
600
+200
1000
550
+300
+800
1000
PresentUnder construction
DiscussedPlanned
Nordel priorityprojects
630 (490)+90
2050
40
Summary on integration to other European markets
• Integration of the Nordic market to other European markets continues via new grid investments and improved congestion management
• The Emissions Trading System also contributes to the integration
• European level market liberalisation and integration continues.Almost all Member States are opening the national markets next year. Security of European energy supply is high on agenda and nuclear is brought back as feasible solution
41