ENERGY SECTOR INQUIRY – ANNEXES (First phase - Gas)
329
ANNEX A
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Gas)
330
Pipeline
Technical
capacity
mcm / day
Route Transit pipeline route
SPP 315.9 E-W Velke Kapusany – Lanzhot & Baumgarten
Transgas 180.5 E-W Lanzhot – Olbernhau & Waidhaus
TAG 95.3 E-W Baumgarten – Tarvisio
JAGAL 80.1 E-W Mallnow – Rückersdorf
Ex Hilvarenbeek 67.7 N-S –
JAMAL-Europa 67.2 E-W Kondratki – Mallnow
MEGAL Nord 57.1 E-W Waidhaus – Medelsheim
IUK FF 54.8 N-S Zeebrugge – Bacton
En Taisniere 50.4 N-S –
NETRA 1 50.4 N-S Dornum – Wardenburg
En Dunkerque 49.1 N-S –
NETG 44.5 N-S Zevenaar – Bergisch Gladbach
Ex Bocholtz 43.9 N-S –
TENP 40.5 N-S Bocholtz – Wallbach
TROLL 40.5 N-S Zeebrugge – Taisnières
METG 40.1 N-S Bergisch Gladbach – Lampertheim
STEGAL West 36.0 E-W Rückersdorf – Reckrod
VTN/RTR FF 30.2 N-S Eynatten – Zeebrugge / Zelzate
Slochteren 27.5 N-S Hilvarenbeek – Blaregnies
Ex 's Gravenvoeren 27.1 N-S –
BEB OTR 1 20.0 N-S Emden – Wardenburg
STEGAL East 20.0 E-W Olbernhau to Rückersdorf
Ex Oltingue 19.7 N-S –
BEB OTR 8 19.3 N-S Oude Statenzijl – Ganderkesee
En OSZ RG 18.6 N-S –
WAG 18.5 E-W Baumgarten – Oberkappel
En Emden EPT 18.2 N-S –
SEGEO 17.9 N-S 's Gravenvoeren – Blaregnies
En Emden NPT 13.1 N-S –
MEGAL Sud FF 11.1 E-W Oberkappel – Schwandorf
RWE OTR 3 10.9 N-S Emsbüren – Hünxe
BEB OTR 3 9.6 N-S Oude Statenzijl – Achim
BEB OTR 5 6.9 N-S Quarnstedt – Heidenau
BEB OTR 10 6.7 N-S Ganderkesee – Drohne
DEUDAN 6.6 N-S Ellund – Quarnstedt
RWE OTR 2 3.7 N-S Bunder Tief – Emsbüren
BEB OTR 7 2.6 N-S Bunde – Emsbüren
RWE OTR 1 1.6 N-S Emden – Bunder Tief
Source: Energy Sector Inquiry 2005/2006.
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
331
ANNEX B
Geographic markets for electricity
1) As regards geographic markets for electricity, despite efforts by the Community to integrate
further the different territorial markets in the EU, the Commission has usually found that
the geographic market is most of the time national442
, but that it may sometimes be
smaller443
or larger444
. Relevant elements which support the existence of a smaller or larger
market include in particular system designs, the existence and frequency of congestion at
points in the grid, the existence of prices correlation (see table g) and price differentials,
and the differing nature of supply and demand on both sides of such congestion points (in
particular the existence of an operator that is indispensable to meet demand445
). This is a
preliminary analysis of situations where it has been alleged that geographic markets are
smaller or larger than national.
A1. Cases of geographic markets smaller than national
2) Data provided by TSOs regarding congestion inside their networks indicates at this stage
that only the networks of the Italian TSO and the Austrian TSO experience internal
congestion points.. We are thus in a position to consider possible geographic markets
smaller that Member States only in these cases and in cases where network and market
designs already foresee it. This is at present the case in Italy and Nord Pool (Denmark and
Norway). Thus, the most congested links in Italy and the Nord Pool area have been
identified, as well as the most frequent “aggregations of zones” in both systems. Also, a
correlation study has been performed of prices between zones and in the case of Nord Pool,
the prices of the Contract for Differences (CfD) of the different zones have been studied446
.
The data gathered over the period 2004-2005 indicated four smaller geographic markets in
Italy (Macro-zone North447
, Macro zone Centre-South448
, Macro-Sicily449
, and Sardinia). It
also suggests that, in the Nord Pool area, three (West Denmark, East Denmark and South
Norway) areas can be considered as separate geographic markets.
3) More precisely, in the case of Italy450
, this segmentation corresponds to the links which are
by far the most congested ones and aggregates the zones whose prices are almost perfectly
correlated. The Macro zone Centre-South constitutes a special case in that respect. It does
not occur on its own a large part of the time and is sometimes part of a wider aggregation of
442
See i.a. cases COMP/M.3440 EDP/ENI/GDP, COMP/M.3696 E.ON/MOL.
443
See case COMP/M.3729 Edf/AEM/Edison.
444
See cases COMP/M.3268 Sydkraft Graninge and COMP/M.2847 Verbund/Energie Allianz.
445
An operator is theoretically indispensable to meet demand if total demand (D) in the area is larger than the sum of the
capacity (SC) of the other generators in the area and of the import capacity (IC) of the area. Given the little flexibility
of demand and provided that the capacity of this operator is not much larger than (D-SC-IC), such an operator would
be a hypothetical monopolist. Please consult the results of the chapter C.c.III in that respect.
446
fD in Nord Pool commit the seller of the CfD to pay the net difference between the price of the zone and the
“average price of Nord Pool” at the time of “delivery” of those contracts: the price of those contracts reflect thus to a
certain extent the average price difference between the zones expected by market participants.
447
This includes the Zone Nord as well as four smaller zones (Ene, Enw, Turbigo and Monfalcone)).
448
This includes the Zones Centro Nord, Piombino, Centro Sud, Sud, Rossano, Brindisi, and Calabria.
449
This includes the zones Sicilia, Priolo and Calabria.
450
This result is coherent with the approach taken by the Italian Energy Authority (Autorità per l’Energia Elettrica e il
Gas, “AEEG”) and the Italian Competition Authority (Autorità Garante della Concorrenza nel Mercato, “AGCM”)
in a Joint Report published on 9 February 2005 (the “Joint Report”). The Joint Report “Indagine consoscitiva sullo
stato della liberalizzazione del settore dell’energia elettrica” is available on the website of AEEG
http://www.autorita.energia.it/elettricita/index.htm as well as on the website of AGCM,
http://www.agcm.it/index.htm
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
332
zones (often including the North zone). However, the Macro zone Centre-South is
characterised by the existence of an operator who is indispensable to cover the demand
most of the time451
: the analysis will thus be carried out on the level of that macro zone.
The result would of course be subject to revisions if the changes in configuration (e.g.
Sardinia becoming far less separated than it used to be) are confirmed in the future452
.
a)
Link
NOR-
TUR
NOR-
MON
NOR-CN CN-PIO PIO-CS CS-SUD
SUD-
ROS
ROS-
BRN
ROS-CAL CAL- PIO-SAR
2004 1% 1% 36% 13% 0% 0% 7% 12% 17% 41% 73%
2005 0% 0% 23% 1% 4% 0% 0% 1% 8% 50% 17%
Whole period 1% 0% 30% 12% 2% 0% 4% 7% 12% 45% 46%
Frequency of congestion of the main links in Italy
Source: GME TUR=Turbigo, MON=Monfalcone, CN=CentroNord, CS=CentroSud, PIO=Piombino;
ROS=Rossano, BRN=Brindisi, CAL=Calabria, SIC=Sicily, SAR=Sardinia.
Note: All figures are rounded. Figures for 2005 correspond to the period January-August. All percentages
are rounded.
b)
NOR-CN CN-PIO PIO-CS CS-SUD SUD-ROS ROS-BRN ROS-CAL CAL-SIC PIO-SAR
Correlation of prices 0.93 0.99 1.00 1.00 0.99 1.00 0.85 .095 0.71
Correlation of prices of the main neighbouring zones in Italy
Source: GME data and COMP calculations on the period January2004-August2005.
4) In the case of Nord Pool, it is likely that West Denmark represents a separate market: it is
separated from other markets half of the time and its price is not correlated at all with the
prices of other zones453
. As regards East Denmark, it is usually not separate from other
zones but the correlation of its price with prices of other zones remains lower than the
correlation between the prices of other zones. Further, the price of the CfDs for that zone is
significantly different from the price of the CfD for other zones. Last but not least, there is
an operator which is indispensable to meet demand in that zone. Thus there are good
reasons to consider this zone as a separate market. South Norway could also be considered
as a separate market for similar reasons.
451
See the Joint Report in that respect.
452
Some comments made in the public consultation indeed note that the configurations may have been changing since
August 2005 (notably the frequency of a single price area for the whole of Italy has increased). That being said, some
other factors have not changed: in particular the existence of an operator which is indispensable to meet demand in
the different macro-zones. See the Joint Report in that respect.
453
West Denmark also cannot be considered as in the same market as Germany as the interconenctor between them is
congested most of the time. In any event, there is one main operator in West Denmark which is indispensable to meet
demand in that zone.
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
333
c)
Link WDK-SWE WDK-SNO EDK-SWE SWE-SNO SWE-NNO SNO-NNO SWE-FIN
2004 41% 41% 6% 35% 27% 44% 24%
2005 52% 52% 11% 22% 10% 28% 8%
Whole period 45% 45% 8% 30% 20% 37% 18%
Frequency of congestion of the links in Nord Pool
Source: Nord Pool. WDK= West Denmark, EDK= East Denmark, SWE=Sweden, SNO= South Norway,
NNO=North Norway.
Note: All percentages are rounded.
d)
WDK-EDK WDK-SWE WDK-SNO EDK-SWE SWE-SNO SWE-FIN SWE-NNO SNO-NNO
Correlation of prices 0.42 0.45 0.36 0.74 0.74 0.87 0.86 0.83
Correlation of prices of neighbouring zones in Nord Pool
Source: Nord Pool data and COMP calculations on the period January2004-August2005.
e)
Prices of summer season 2005 CfD for the Different Norpool zones
-20
-10
0
10
20
30
40
50
60
70
80
90
3/01/200510/01/200517/01/200524/01/200531/01/20057/02/200514/02/200521/02/200528/02/20057/03/200514/03/200521/03/200528/03/20054/04/200511/04/200518/04/200525/04/2005
NKr/MW
Denmark West
Denmark East
Finland
South Norway
Sweden
Source: Energy Sector Inquiry 2005/2006.
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
334
f)
Prices of winter season 2005 CfD for the Different Norpool zones
-10
0
10
20
30
40
50
60
70
3/01/2005
17/01/2005
31/01/2005
14/02/2005
28/02/2005
14/03/2005
28/03/2005
11/04/2005
25/04/2005
9/05/2005
23/05/2005
6/06/2005
20/06/2005
4/07/2005
18/07/2005
1/08/2005
15/08/2005
29/08/2005
12/09/2005
NKr/MW
Denmark West
Denmark East
Finland
South Norway
Sweden
Source: Energy Sector Inquiry 2005/2006.
A.2. Cases of geographic markets larger than national
5) The first case where a market is larger than national could be considered is Nord Pool
because of the existence of its integrated market design. According to the analysis above,
one could consider at most Sweden, North Norway and Finland to be part of the same
geographic market. First the correlation of prices is fairly high. Second the prices of the
Contract for Differences between the different zones in the forward markets indicate that
operators consider that there is not much risk of trading forward between the remaining
zones (except to a certain extent for North Norway). On the other hand, North Norway is
separated from Sweden for one third of the time and Finland can be separated from Sweden
during substantial amount of hours (especially during certain months separation can reach
40%). It is difficult to conclude without making a detailed calculation of residual demand in
each of the zones, which at this stage has not yet been assessed. In line with previous
Commission practice454
, the issue will be left open.
6) Some market participants have also argued that the increasing correlation of the prices of
the different markets on the continent has already led to the creation of a continental market
involving at least France, Belgium Germany, the Netherlands and Austria. First of all, it is
important to note that this correlation remains fairly low in most cases as seen below.
Second, price level differentials between spot markets and forward market products remain
substantial. Further, the chapter on market integration demonstrates that congestion remains
high on the borders between these MS and is in some cases even increasing. The same
chapter demonstrates also that the procedures to trade between MS contain important
administrative procedures that players experience as difficult (e.g. transaction costs) and
risky. Further, France and Belgium continue to have a main operator which provides most
454
See case COMP/M.3867 Vattenfall/Elsam and Energi E2.
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
335
of the generation in the market and is thus indispensable to meet demand. Thus, at this
stage it is not possible to conclude that a continental market has emerged.
g)
Exchanges ES-FR FR-IT FR-IT (Nord) FR-DE DE-NL FR-NL DE-AT
Correlation 2004 0.66 0.63 0.60 0.91 0.55 0.07 0.93
Correlation 2005 0.71 0.58 0.60 0.83 0.69 0.16 0.85
Correlation of spot prices between continental exchanges
Source: data from the exchanges and COMP calculations.
Note: The figures for 2005 correspond to the period January-September. For Italy, the first column
corresponds to the whole system price (PUN), the second column to the North Zone.
7) That being said, the data about congestion of interconnectors provided in the chapter
B.b.II.3 indicates that some borders (DE-AT, DE-CH, CZ-SK) are never or almost never
congested in both directions. This could lead to three possible cases where a geographic
market could be larger than national. First, for the case Germany-Austria, it must be noted
that while the price of the EXAA is rather well correlated to that of EEX, this correlation is
decreasing (see table A1). Further there are some congestion points inside the Austrian grid
and more importantly, the main operator in Austria generates roughly half of the generation
needed to cover consumption, so it is indispensable to meet demand. For that reason, it is
difficult to conclude that the market comprises both Member states. The size of the
incumbent operator leads to the same conclusion in the case of the Czech and Slovak
republics. As regards the possible integration of Switzerland and Germany in the same
geographic market, it is first important to note that congestion has started to occur on the
border and that an auction mechanism was put in place in early January 2006. In any event,
the absence of liberalisation and corresponding regulation of networks in Switzerland455
make the two national markets too different to be considered as part of the same relevant
market.
8) Finally, reference is made to the analysis made in chapter C.c.III, in particular as regards
residual demand and the existence of an operator that is indispensable to meet demand456
in
several Member States.
455
This means in particular that there is no regulation of networks which would allow non-discriminatory access, a
prerequisite for a true wholesale market to emerge.
456
An operator is theoretically indispensable to meet demand if total demand (D) in the area is larger than the sum of the
capacity (SC) of the other generators in the area and of the import capacity (IC) of the area. Given the little flexibility
of demand and provided that the capacity of this operator is not much larger than (D-SC-IC), such an operator would
be a hypothetical monopolist.
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
336
ANNEX C
Shares in available installed capacity and effective generation
for a selection of countries, 2004
Austria
Available installed capacity
43,2%
27,1%
2,8%
2,6%
13%
3%
8,5%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Other
undertakings
Austria
2004 Effective generation
24,2%
4,8%
2,3%
46%
15%
4,8%
2,9%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Other
undertakings
Belgium
Available installed capacity
17%
83%
Undertaking A
Other
undertakings
Belgium
2004 Effective generation
82,3%
17,7%
Undertaking A
Other
undertakings
Denmark East
Available installed capacity
85%
15%
Undertaking A
Other
undertakings
Denmark East
2004 Effective generation
76,3%
23,7%
Undertaking A
Other
undertakings
Denmark West
Available installed capacity
54%
46%
Undertaking A
Other
undertakings
Denmark West
2004 Effective generation
60,6%
39,4%
Undertaking A
Other
undertakings
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
337
France
Available installed capacity
86,7%
2,5%
8,2%0,5%
2,2%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Other
undertakings
France
2004 Effective generation
75,4%
1,5%
7,9%
7,8%
7,4%
Undertaking A
Undertaking B
VPP
Undertakings
owning drawing
rights in plants
of undertaking
A
Other
undertakings
Finland
Available installed capacity
37,4%
16,9%
16%
29,8%
Undertaking A
Undertaking B
Undertaking C
Other
undertakings
Finland
2004 Effective generation
33,7%
18,3%
21,6%
26,5% Undertaking A
Undertaking B
Undertaking C
Other
undertakings
Germany
Available installed capacity
22,6%
21,5%
5,4%
24,4%
14,5%
11,6%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Other undertakings
Germany
2004 Effective generation
28,4%
24,9%
5,2%
14,6%
14,5%
12,4%
Undertaking B
Undertaking A
Undertaking D
Undertaking C
Undertaking E
Other generators
Italy
Available installed capacity
51,4%
11,9%
3,5%
3,2%
11,1%
2,1%
1,5%
1,5%
1%
1%
7,8%
4%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Undertaking J
Undertaking K
Other
undertakings
Italy
2004 Effective generation
43,9%
16,7%
3,3%
2,1%
1,9%
1,3%
0,9%
0,9%
16,1%
1%
7,3%
4,7%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking J
Undertaking I
Undertaking K
Other
undertakings
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
338
Poland
Available installed capacity
25,4%
15,9%
6,2%
5,7%
5,5%
25,7%
6,4% 9,1%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Other
undertakings
Poland
2004 Effective generation
33,8%
13,9%
6,8%
5,5%
23%
9,8%
7,1%
Undertaking A
Undertaking B
Undertaking D
Undertaking C
Undertaking F
Undertaking E
Other
undertakings
Spain
Available installed capacity
35,6%
32,7%
3,4%
6,5%
3%
14,7%
4,1% Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Other
undertakings
Spain
2004 Effective generation
48,3%
2,6%
2,4%
2,2%
28%
10,4%
6,1% Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Other
undertakings
Sweden
Available installed capacity
42,8%
14,3%
22%
18,6%
2,4% Undertaking A
Undertaking B
Undertaking C
Undertaking D
Other
undertakings
Sweden
2004 Effective generation
47,1%
22,2%
10,7%
17,4%
2,5% Undertaking A
Undertaking B
Undertaking C
Undertaking D
Other
undertakings
The Netherlands
Available installed capacity
22,8%
20,9%
28,3%
19,1%
8,9%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Other
undertakings
The Netherlands
2004 Effective generation
26,6%
20,7%
22,9%
18,9%
10,8%
Undertaking B
Undertaking C
Undertaking A
Undertaking D
Other
undertakings
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
339
UK
Available installed capacity
14,9%
12,4%
6,5%
4,9%
4,7%
4,7%
15,5%
8%
5%
12,2%
11,2%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Undertaking J
Other
undertakings
UK
2004 Effective generation
19,7%
11,2%
7,6%
7,3%
6,6%
4,8%
3,4%
2,7%
17,2%
9,8%
9,7%
Undertaking A
Undertaking C
Undertaking D
Undertaking B
Undertaking G
Undertaking F
Undertaking E
Undertaking J
Undertaking H
Undertaking I
Other
undertakings
Source: Energy Sector Inquiry 2005/2006.
The figures on capacity (graphs on the left) are based on capacity installed and owned
within the Member State concerned: they do not include capacity owned by the same
undertaking in another Member State and do not include capacity which could be used
through the use of drawing rights in plants owned by another undertaking. The use of
drawing rights is reflected in figures about effective production (graphs on the right) only
the extent that these drawing rights and the corresponding output were identified by
market participants.
Some comments made in the public consultation argued that the graph of effective
production for Spain was not consistent with publicly available figures. The figures have
been checked again and the chart remains the same. The graph is based on the data
provided by the operators for their own production and for total production on publicly
available figures. The discrepancy may result thus from the fact that publicly reported
generation for individual generators is not equal to individual generation reported to DG
COMP.
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
340
ANNEX D
Sales and purchases shares in existing forward markets, 2004
Note: the graphs represent sellers on the left side and buyers on the right side. The same pattern/color is
not meant to represent the same operator in both graphs.
The pattern represents in each Figure the category “other undertakings”, i.e. the aggregation of
all undertakings which have not been represented individually in the Figures.
Belgium 2004
Shares of the main SELLERS of yearly foward products
46%
16%
13%
8%
5%
4%
3%
1%2%2%
Belgium 2004
Shares of the main BUYERS of yearly foward products
33%
30%
25%
3%1%
3%
1%
1%
1%2%
France 2004
Shares of the main SELLERS of yearly foward products
13%
12%
12%
10%
7%
6%
5%
4%
4%
3%
3%
3%
7%
3%
3%
1%
1%
1%
1%2%
2%
France 2004
Shares of the main BUYERS of yearly foward products
14%
12%
10%
10%
7%
7%
6%
6%
4%
3%
3%
2%
6%
1%1%
1%1%
1%1%
2%
2%
Germany 2004
Shares of the main SELLERS of yearly foward products
12%
10%
7%
7%
6%
5%5%3%
3%3%
3%
3%
3%
2%
2%
2%
24%
Germany 2004
Shares of the main BUYERS of yearly foward products
8%
8%
7%
7%
6%
6%
5%
4%3%3%
3%
3%
3%
3%
2%
2%
29%
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
341
Nord pool 2004
Shares of the main SELLERS of yearly foward products
15%
9%
7%
5%
5%
5%
4%4%
4%
3%
21%
3%
2%
2%
2%
2%
2%
2%
2%
2%
Nord pool 2004
Shares of the main BUYERS of yearly foward products
15%
6%
6%
5%
5%
5%
5%
4%4%
3%
30%
3%
3%
2%
2%
2%
The Netherlands 2004
Shares of the main SELLERS of yearly foward products
19%
19%
15%7%
5%
5%
5%
3%
3%
2%
9%
2%
0,3%
1%1%
2%
2%
The Netherlands 2004
Shares of the main BUYERS of yearly foward products
19%
18%
11%
8%
6%
4%
4%
4%
3%
3%
3%
9%
2%
1%
1%
2%
2%
UK April-September 2004
Shares of the main SELLERS of season foward products
13%
9%
7%
7%
6%
6%6%
5%
5%
5%
5%
4%
4%
4%
3%
11%
UK April-September 2004
Shares of the main BUYERS of season foward products
15%
8%
8%
7%
7%
6%6%
5%
5%
5%
4%
4%
4%
4%
4%
3%
6%
Source: Energy Sector Inquiry 2005/2006
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
342
ANNEX E
Evolution of sales and purchases shares in existing forward markets, 2004
Note: the graphs represent successively sellers and buyers for each market. The same pattern/colour is not
meant to represent the same operator in both graphs, but for very few exceptions.
The pattern represents in each Figure the category “other undertakings”, i.e. the aggregation of
all undertakings which have not been represented individually in the Figures.
The charts for Belgium cannot be shown given the very few operators actively trading: these charts would
reveal the strategy of those operators.
France - monthly sales of the main SELLERS of yearly forward contracts
0
5000
10000
15000
20000
25000
30000
35000
Jan-04 Feb-04 Mar-04 Apr-04 May-04 Jun-04 Jul-04 Aug-04 Sep-04 Oct-04 Nov-04 Dec-04 Jan-05 Feb-05 Mar-05 Apr-05 May-05
GWh
France -monthly purchases of the main BUYERS of yearly forward products
0
5000
10000
15000
20000
25000
30000
35000
Jan-04 Feb-04 Mar-04 Apr-04 May-04 Jun-04 Jul-04 Aug-04 Sep-04 Oct-04 Nov-04 Dec-04 Jan-05 Feb-05 Mar-05 Apr-05 May-05
GWh
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
343
Germany - monthly sales of the main SELLERS of yearly forward products
0
50000
100000
150000
200000
250000
300000
350000
400000
Jan-04 Feb-04 Mar-04 Apr-04 May-04 Jun-04 Jul-04 Aug-04 Sep-04 Oct-04 Nov-04 Dec-04 Jan-05 Feb-05 Mar-05 Apr-05 May-05
GWh
Germany - monthly purchases of the main BUYERS of yearly forward contracts
0
50000
100000
150000
200000
250000
300000
350000
400000
Jan-04 Feb-04 Mar-04 Apr-04 May-04 Jun-04 Jul-04 Aug-04 Sep-04 Oct-04 Nov-04 Dec-04 Jan-05 Feb-05 Mar-05 Apr-05 May-05
GWh
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
344
Nord pool - monthly sales of the main SELLERS of yearly forward products
0
5000
10000
15000
20000
25000
30000
35000
Jan-04 Feb-04 Mar-04 Apr-04 May-04 Jun-04 Jul-04 Aug-04 Sep-04 Oct-04 Nov-04 Dec-04 Jan-05 Feb-05 Mar-05 Apr-05 May-05
GWh
Nord pool - monthly purchases of the main BUYERS of yearly forward products
0
5000
10000
15000
20000
25000
30000
35000
Jan-04 Feb-04 Mar-04 Apr-04 May-04 Jun-04 Jul-04 Aug-04 Sep-04 Oct-04 Nov-04 Dec-04 Jan-05 Feb-05 Mar-05 Apr-05 May-05
GWh
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
345
The Netherlands - monthly sales of the main SELLERS of yearly forward products
0
10000
20000
30000
40000
50000
60000
Jan-04 Feb-04 Mar-04 Apr-04 May-04 Jun-04 Jul-04 Aug-04 Sep-04 Oct-04 Nov-04 Dec-04 Jan-05 Feb-05 Mar-05 Apr-05 May-05
GWh
The Netherlands -monthly sales of the main BUYERS of yearly forward products
0
10000
20000
30000
40000
50000
60000
Jan-04 Feb-04 Mar-04 Apr-04 May-04 Jun-04 Jul-04 Aug-04 Sep-04 Oct-04 Nov-04 Dec-04 Jan-05 Feb-05 Mar-05 Apr-05 May-05
GWh
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
346
UK - monthly sales of the main SELLERS of seasons forward products
0
10000
20000
30000
40000
50000
60000
70000
Jan-04 Feb-04 Mar-04 Apr-04 May-04 Jun-04 Jul-04 Aug-04 Sep-04 Oct-04 Nov-04 Dec-04 Jan-05 Feb-05 Mar-05 Apr-05 May-05
GWh
UK - monthly purchases of the main BUYERS of the season forward products
0
10000
20000
30000
40000
50000
60000
70000
Jan-04 Feb-04 Mar-04 Apr-04 May-04 Jun-04 Jul-04 Aug-04 Sep-04 Oct-04 Nov-04 Dec-04 Jan-05 Feb-05 Mar-05 Apr-05 May-05
GWh
Source: Energy Sector Inquiry 2005/2006.
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
347
ANNEX F
Shares of spot sales in the different power exchanges in 2004 and 2005.
Note: the same pattern/colour represents the same undertaking in both pies for a given market.
APX - Shares of spot sales in 2004
17%
13%
12%
8%8%
6%
6%
5%
25%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Other operators
APX - Shares of spot sales in January-July 2005
20%
12%
9%
7%
7%
7%
4%
30%
4%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Other operators
EEX - Shares of spot sales in 2004
31%
9%
7%
4%4%
3%
2%
2%
2%
2%
2%
30%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Undertaking J
Undertaking K
Undertaking L
Other undertakings
EEX - Shares of spot sales in January-July 2005
15%
6%
21%
3%
8%1%
3%
6%
3%
28%
1%
1%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Undertaking J
Undertaking K
Undertaking L
Other undertakings
GME North - Shares of spot sales in 2004
26%
12%
9%
8%
23%
22%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Imports from abroad
Other undertakings
GME North - Shares of spot sales in January-August 2005
21%
10%
8%
10%
25%
26% Undertaking A
Undertaking B
Undertaking C
Undertaking D
Imports from abroad
Other undertakings
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
348
GME Sardinia - Shares of spot sales in 2004
34%
27%
23%
7%
7%
0,4%
2%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Imports form other zones
Other undertakings
GME Sardinia - Shares of spot sales in January-August 2005
34%
27%
23%
2%
7%
7%
0,4%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Imports form other zones
Other undertakings
GME Sicily - Shares of spot sales in 2004
46%
27%
10%
7%
4%
4%
1% 1%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Imports from other zones
Other undertakings
GME Sicily - Shares of spot sales in January-August 2005
45%
21%
8%
14%
3%
3%
3% 2% 1%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Imports from other zones
Other undertakings
GME Others - Shares of spot sales in 2004
38%
19%
17%
19%
1%
2%
2%
2%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Imports from abroad
Imports from other zones
Other undertakings
GME Others - Shares of spot sales in January-August 2005
34%
19%2%
1%
17%
20%
5%
2%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Imports from abroad
Imports from other zones
Other undertakings
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
349
Nord Pool East Denmark - Shares of spot sales in 2004
87%
6%
1%
6%
Undertaking A
Undertaking B
Undertaking C
Other undertakings
Nord Pool East Denmark - Shares of spot salesin Jan-Aug 2005
64%
3%
27%
6%
Undertaking A
Undertaking B
Undertaking C
Other undertakings
Nord pool West Denmark - Shares of spot sales in 2004
58%
14%
6%
5%
17%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Other undertakings
Nord Pool West Denmark -Shares of spot sales in Jan-Aug 2005
28%
46%
1%
21%
4%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Other undertakings
Nord Pool Finland - Shares of spot sales in 2004
68%
7%
6%
19%
Undertaking A
Undertaking B
Undertaking C
Other undertakings
Nord Pool Finland - Shares of spot sales in January-August 2005
66%
6%
6%
22% Undertaking A
Undertaking B
Undertaking C
Other undertakings
Nord Pool South Norway - Shares of spot sales in 2004
18%
16%
9%
8%8%
7%
5%
24%
5%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Other undertakings
Nord Pool South Norway Shares of spot sales in Jan-Aug 2005
6%
40%
5%5%
3%
7%
6%
6%
17%
5%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Other undertakings
Nord Pool Sweden - Shares of spot sales in 2004
41%
36%
16%
7%
Undertaking A
Undertaking B
Undertaking C
Other undertakings
Nord Pool Sweden - Shares of spot sales in January-August 2005
42%
34%
16%
8%
Undertaking A
Undertaking B
Undertaking C
Other undertakings
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
350
Omel - Shares of spot sales in 2004
41%
28%
9%
6%
2%
13%
1% Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Other undertakings
Omel - Shares of spot sales in January-August 2005
34%
26%
10%
6%
2%
3%
19%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Other undertakings
Powernext - Shares of spot sales in 2004
9%
8%
7%
6%
6%
5%
5%
4%4%
4%
3%
32%
3%
2%
2%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Undertaking J
Undertaking K
Undertaking L
Undertaking M
Undertaking N
Other undertakings
Powernext - Shares of spot sales in January-May 2005
9%
14%
6%
4%
13%
2%7%
5%
2%
27%
2%
4%
2%
2%
1%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Undertaking J
Undertaking K
Undertaking L
Undertaking M
Undertaking N
Other undertakings
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
351
ANNEX G
First elements of analysis of balancing markets
Figure a) show the concentration in the German balancing market segment aggregated for
the whole of Germany. The shares (in percentages) represent the volumes supplied
(MWh) by generators aggregating secondary and tertiary reserves that have been supplied
during 2003 until May 2005. To be clear, though Germany has four so-called control
areas it is reasonable to aggregate the volumes for reserves across these areas since
supplying reserve power across control areas is possible. The figure reveal that four
actors are mainly supplying reserves.
a)
Germany balancing markets
volumes supplied for increasing production
2003-2005 May
34,0%
19,7%
20%
26%
0,1%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Other
undertakings
Germany balancing markets
volumes supplied for decreasing production
2003-2005 May
28,9%
16,7%
20%
34%
0,4%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Other
undertakings
The figure b) shows the share of income that operators received from the French TSO for
balancing services (only tertiary reserves). All main actors in the balancing markets are
either owners of generation assets or have drawing rights in generation capacity of third
parties.
b)
France balancing markets
income for increasing production 2004
59,5%
14,5%
7,1%
6,8%
3,9%
1%
3,3%
3,9%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Other undertakings
France balancing markets
income for decreasing production 2004
91,1%
0,8%
0,9%1,5%
1,6%
2,2%
1,1%
0,8%
Undertaking A
Undertaking E
Undertaking F
Undertaking D
Undertaking B
Undertaking C
Undertaking H
Other
undertakings
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
352
ANNEX H
Importance of transparency on 49 individual issues,
according to market participants
Note: These figures are discussed in section B.b.II.4.3
Issues
Inform ation
indispensable,
important or useful
Inform ation not useful
Location of congestion 95,4% 4,6%
Frequency of congestion 93,2% 6,8%
Causes of congestion 92,6% 7,4%
Grid investments: impact on frequency and location of congestion 95,2% 4,8%
Planned line maintenance Location 96,1% 3,9%
Planned line maintenance Duration 96,1% 3,9%
Planned line maintenance Capacity loss (MW ) 96,1% 3,9%
Unplanned line outages Location 95,9% 4,1%
Unplanned line outages Duration 95,9% 4,1%
Unplanned line outages Capacity loss (MW ) 95,9% 4,1%
Thermal capacity 80,3% 19,7%
Net Transfer Capacity (NTC) 93,8% 6,2%
Impact of planned works on the network on NTC 92,8% 7,2%
Capacity reserved for legacy contracts 92,2% 7,8%
Capacity reserved for reserve power 92,8% 7,2%
Available Transfer Capacity (ATC) 96,1% 3,9%
Capacity requested by market actors 90,2% 9,8%
Capacity given out by TSO 92,4% 7,6%
Price per time slot 95,1% 4,9%
Total nominated capacity 93,9% 6,1%
Actual physical flows over interconnector 90,6% 9,4%
Day-ahead aggregated scheduled load 93,8% 6,2%
W eek-ahead forecasted load 95,1% 4,9%
Year-ahead forecosted load 95,8% 4,2%
Actual system load in MW /h 95,4% 4,6%
Operation margins at consumption peaks 92,3% 7,7%
Demand for balancing power 95,8% 4,2%
System balancing status (long or short) 94,7% 5,3%
Actual use of primary reserve power 85,2% 14,8%
Actual use of secondary reserve power 89,3% 10,7%
Actual use of tertiary reserve power 88,5% 11,5%
Hourly generation (KW h) by fuel type 88,1% 11,9%
Day-ahead projected hourly injections (KW h) of wind power 89,3% 10,7%
Actual hourly injections of wind power 84,6% 15,4%
Actual injections (KW h) of wind power 82,7% 17,3%
Day-ahead aggregated scheduled generation capacity by fuel type 88,0% 12,0%
W eek-ahead scheduled available generation capacity by fuel type 88,9% 11,1%
Year-ahead scheduled available generation capacity by fuel type 88,8% 11,2%
Projected new-built of generation capacity Location 94,9% 5,1%
Projected new-built of generation capacity Capacity (MW ) 98,0% 2,0%
Installed generation capacity Location 95,9% 4,1%
Installed generation capacity Capacity (MW ) 98,7% 1,3%
Projected mothballing of generation capacity 93,6% 6,4%
Projected dismantling of generation capacity 95,0% 5,0%
Projected maintenance Duration 96,6% 3,4%
Projected maintenance Capacity loss (MW ) 97,3% 2,7%
W ater levels in hydro reservoirs 94,2% 5,8%
Unplanned loss of generation capacity Duration 93,8% 6,3%
Unplanned loss of generation capacity Capacity loss (MW ) 93,7% 6,3%
Source: Energy Sector Inquiry 2005/2006.
ENERGY SECTOR INQUIRY – ANNEXES (First phase - Electricity)
353
ANNEX I
Load factors of power plants of the main generators in Germany
Calculation on all hours of the year
Load factors 2000 on all hours in the year - Plants of four main operators in Germany
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
1288 12336 17411 20184 30890 40469 46459 51485 56025 62936 66646 71505
Cumulated capacity (MW)
Loadfactor
0
20
40
60
80
100
120
140
Marginalcost(€/MWh)
Load factor 2000 on all hours Marginal cost 2000
Load factors 2004 on all hours in the year- Plants of four main operators in Germany
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
1284 12960 18198 20051 33759 43285 49703 56081 60101 65032 69810 72610
Cumulated capacity (MW)
Loadfactor
0
20
40
60
80
100
120
140
Marginalcost(€/MWh)
Load factor 2004 on all hours Marginal cost 2004
Load factors 2005 on all hours in the year- Plants of four main operators in Germany
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
52 12960 18198 20051 32417 41959 49064 54134 60778 64708 69855 72820
Cumulated capacity (MW)
Loadfactor
0
20
40
60
80
100
120
140
Marginalcost(€/MWh)
Load factor 2005 on all hours Marginal cost 2005
Source: Energy Sector Inquiry 2005/2006.
ENERGY SECTOR INQUIRY – ANNEXES (Second phase – Public consultation)
354
ANNEX J
Statistics on the results of the public consultation (Electricity)
Respondents representing the views
related to the position of:
Incumbents Non-
incumbents
Consumers National
authorities
Power
exchanges
Independent
traders
TSOs and
DSOs
Others Total number
of comments
Number of all respondents in each
category 14 6 4 7 3 4 6 1 45
Comments on:
Regulatory framework 9 3 2 1 1 3 1 0 20
Functioning of wholesale markets 7 2 4 3 1 2 1 0 20
Concentration in generation 7 4 3 4 0 0 1 0 19
Concentration in trade 6 2 1 3 0 1 0 0 13
Price setting 6 2 3 3 1 1 0 0 16
Withdrawals of capacity 0 0 3 2 1 0 0 0 6
Other issues relating to concentration 3 0 0 2 0 1 0 0 6
Vertical integration between generation
and retail activities 7 5 2 2 0 3 0 0 19
Vertical integration between supply and
network activities 8 3 3 3 0 2 1 0 20
Current institutional setting and market
design 8 2 2 2 0 3 3 1 21
Investments in new cross-border
infrastructure 10 2 3 2 1 2 2 0 22
Allocation of existing cross-border
capacity 8 2 3 2 3 2 3 0 23
Transparency 13 5 2 3 2 3 4 0 32
External factors possibly explaining
price increases 5 3 3 1 1 1 0 0 14
Regulated supply tariffs and special
support schemes 9 4 1 2 1 1 1 0 19
Competition law remedies 1 2 4 3 0 0 1 0 11
Regulatory remedies 6 2 3 2 2 2 2 0 19
Structural remedies 5 2 4 4 0 1 1 0 17
Source: Energy Sector Inquiry 2005/2006.
ENERGY SECTOR INQUIRY – ANNEXES (Second phase – Gas)
355
ANNEX K
Destination
Country
Country of
origin
Belgium Algeria SNTM-Hyproc Sonatrach Suez LNG 126 1980 26
Messigaz Sonatrach Gaz de France 50 1971 42
SNTM-Hyproc Sonatrach Gaz de France 126 1981 32
Dreyfus/Gaz de France Sonatrach Gaz de France 129 1977 36
Messigaz Sonatrach Gaz de France 40 1974 39
ENI Sonatrach Gaz de France 41 1970 43
Nigeria Bonny Gas Transport Nigeria LNG Gaz de France 137 2002 17
Oman Oman Gas/MOL Oman Gas 137 2001 21
Total capacity by
destination country=661
Greece Algeria BW Gas Sonatrach DEPA 30 1974 36
ENI Sonatrach ENI 41 1969 48
ENI Sonatrach ENI 65 1996 21
ENI Sonatrach ENI 65 2005 23
Peninsular LNG RasGas II 138 2004 25
A. P. Moller RasGas II 138 2004 25
Peninsular LNG Qatar RasGas II 138 2005 25
Peninsular LNG Qatar RasGas II 145 2005 26
Peninsular LNG Qatar RasGas II 145 2005 26
A. P. Moller Qatar RasGas II 145 2006 25
Total capacity by
destination country=1020
Distrigas Sonatrach Suez LNG 131 1978 37
Auxiliar Maritima Sonatrach Enagas 40 1970 37
Elcano Sonatrach Enagas 138 2003 4
BG International Sonatrach Enagas 72 1969 52
Knutsen/Marpetrol Engas Union Fenosa 139 2004 26
Teekay LNG Partners Engas Repsol/YPF 138 2005 30
Teekay LNG Partners Engas Union Fenosa 141 2004 30
Chemikalien
Seetransport
Sirte Oil Enagas 36 1975 29
Chemikalien
Seetransport
Sirte Oil Enagas 36 1975 29
Taiwan Marine Sirte Oil Enagas 26 1965 39
Nigeria Bonny Gas Transport Nigeria LNG Enagas 137 2002 17
Oman Gas/MOL Oman Gas Shell 149 2004 3
Oman Gas/MOL Oman Gas Qalhat LNG 147 2005 21
Shell Shipping Oman Gas Iberdrola 127 1978 29
J4 Consortium QatarGas 135 2004 20
Golar LNG QatarGas British Gas 126 1977 42
Golar LNG Atlantic LNG British Gas 138 2003 31
Hoegh LNG Atlantic LNG Enagas 88 1973 47
Teekay LNG Partners Atlantic LNG Enagas 138 2003 21
Knutsen/Marpetrol Atlantic LNG Repsol/YPF 138 2004 20
BG International Atlantic LNG Enagas 72 1969 52
n.a. BP Shipping Engas 138 2002
BP Shipping Engas 138 2003
Total capacity by
destination country=2565
Bonny Gas Transport Nigeria LNG Enagas/GdF/BOTAS 122 1976 43
Bonny Gas Transport Nigeria LNG Enagas/GdF/BOTAS 122 1977 42
Bonny Gas Transport Nigeria LNG Enagas/GdF/BOTAS 133 1981 38
Bonny Gas Transport Nigeria LNG Enagas/GdF/BOTAS 133 1984 35
Bonny Gas Transport Nigeria LNG Enagas/GdF/BOTAS 127 1980 39
Bonny Gas Transport Nigeria LNG Enagas/GdF/BOTAS 127 1980 39
Bonny Gas Transport Nigeria LNG Enagas/GdF/BOTAS 127 1978 45
Total capacity by
destination country=890
Bonny Gas Transport Nigeria LNG 141 2004
Bonny Gas Transport Nigeria LNG 141 2005
Bonny Gas Transport Nigeria LNG 141 2005
Bonny Gas Transport Nigeria LNG 141 2006
Kristen Navigation Qatar Ras Gas II 145 2005 25
Kristen Navigation Qatar Ras Gas II 145 2005 25
BW Gas Nigeria LNG Various 146 2004 22
BW Gas Nigeria LNG Various 145 2005 21
BW Gas Nigeria LNG Various 141 2005 21
Bonny Gas Transport Nigeria LNG 138 2003 16
BW Gas Nigeria LNG Various 146 2006 21
Egypt Mitsui OSK Line Idku BP 138 2005 3
Algeria Nippon Gas Sonatrach Various 145 2004 26
BW Gas Sonatrach 138 2004 26
SNTM-Hyproc Sonatrach 41 1971 42
Total Capacity= 7322
LNG tankers currently serving the EU market (by destination country)
Qatar
Shipowner Exporter
Algeria
Qatar
Algeria
Egypt
Libya
Charterer
Oman
Delivery
Contract
length
Primary Trade Route
Capacity (cu.m. x1000)
France
Italy
Spain
Algeria
Europe
(various
countries)
Trinidad
Nigeria
Nigeria
Algeria
Spain/France
/Turkey
Source: Ernst & Young's elaboration of Maritime Business Strategies' data.
ENERGY SECTOR INQUIRY – ANNEXES (Second phase – Gas)
356
Destination
Country
Country of
origin
Gaz de France Engas Gaz de France 154 31-Oct-06 19
GdF/NYK Line Engas Gaz de France 154 2007 20
Total capacity by
destination country=307
Gaz de France Sonatrach Gaz de France 74 31-Dec-06 7
Knutsen OAS Repsol 138 30-Jun-08
Oman Oman Gas/MOL Oman Gas Qalhat LNG 147 31-Jul-06 20
Total capacity by
destination country=359
ProNav Ship Mgmt. Qatar Qatargas II 210 31-Oct-07 25
ProNav Ship Mgmt. Qatar Qatargas II 210 31-Oct-07 25
ProNav Ship Mgmt. Qatar Qatargas II 210 31-Jan-08 25
ProNav Ship Mgmt. Qatar Qatargas II 210 31-Jan-08 25
Overseas Shipholding Qatar Qatargas II 216 31-Oct-07 25
Overseas Shipholding Qatar Qatargas II 216 31-Jan-08 24
Overseas Shipholding Qatar Qatargas II 216 31-Aug-07 25
Overseas Shipholding Qatar Qatargas II 216 31-Jan-08 24
Total capacity by
destination country=1705
Med. LNG Tpt. Corp. Sonatrach 76 30-Jun-07 25
Med. LNG Tpt. Corp. Sonatrach 76 30-Jun-09 24
Total capacity by
destination country=151
Maran Gas Maritime Qatar Ras Gas II 146 31-Jul-06 24
Teekay LNG Qatar Ras Gas II 152 31-Oct-06 25
Teekay LNG Qatar Ras Gas II 152 31-Jan-07 25
Teekay LNG Qatar Ras Gas II 152 Apr-07 25
Maran Gas Maritime Qatar Ras Gas II 146 31-May-07 23
BW Gas Nigeria LNG Various 148 Feb-07 20
BW Gas Nigeria LNG Various 148 Mar-07 20
BW Gas Nigeria LNG Various 148 Mar-08 19
BW Gas Nigeria LNG Various 148 15-Jun-08 20
BP Shipping Available 155 31-Aug-08
Total capacity by
destination country=1494
Total ship capacity= 4017
LNG tankers planned to serve the EU market (by destination country)
Europe
Qatar
Nigeria
UK
Mediterranean
Countries
Algeria
Qatar
Primary Trade Route
Egypt
France
Spain
Algeria
Contract
length
DeliveryShipowner Exporter Importer
Capacity
(cu.m. x1000)
Source: Ernst & Young's elaboration of Maritime Business Strategies' data.
ENERGY SECTOR INQUIRY – ANNEXES (Second phase – Gas)
357
ANNEX L
Cost of a spot unloading of 1 TWh with an emission on the transmission
network of 30 days
Italy
Per unit (MWh) 1 TWh
Charge per unload 17.477,79 € 17.477,79 €
Unit Commodity charge (1) 0,1315 € 128.870,00 €
(2) 0,0159 € 15.582,00 €
Unit Capacity charge (3) 0,29 € 290.000,00 €
Gas Consumption (reference : 20
€/MWh)
2,0% 400.000,00 €
Total 851.929,79 €
(1) : 0,036556 €/GJ ; 1 GJ = 0,278 MWh
(2) : 0,004424 €/GJ ; 1GJ = 0,278 MWh
(3) : 1,97 €/liquid m3 ; 1 liquid m3 equivalent to 600 gas m3 ; 1 gas m3 = 11,3 kWh
Belgium (new tariff)
1 TWh
Charge per unload included in slot included in slot
Charge per slot 750.443,00 € 750.443,00 €
Unit charge per additional
emission / kWh/h/year
1,95 € 2.706.600,00 €
Gas Consumption (reference: 20
€/MWh)
1,3% 260.000,00 €
Total 3.717.043,00 €
A slot includes unloading, storage and regasification capacity for 10,35 days
We suppose that the emission is constant during 30 days, i.e. 1388 MWh/h
France
Per unit
(MWh)
1 TWh
Charge per unload
30.000,00
€
30.000,00 €
Unit Commodity charge 0,57 € 570.000,00 €
Charge for reception service 0,03 € 30.000,00 €
Gas Consumption (reference: 20
€/MWh)
0,5% 100.000,00 €
Total 730.000,00 €
Source: Commission elaboration of IEFE and national regulators data.
ENERGY SECTOR INQUIRY – ANNEXES (Second phase – Gas)
358
Cost of a spot unloading of 1 TWh with an emission on the transmission
network of 8 or 10 days
Italy
Per unit (MWh) 1 TWh
Charge per unload 17.477,79 € 17.477,79 €
Unit Commodity charge (1) 0,1315 € 128.870,00 €
(2) 0,0159 € 15.582,00 €
Unit Capacity charge (3) 0,29 € 290.000,00 €
Gas Consumption (reference : 20
€/MWh)
2,0% 400.000,00 €
Total 851.929,79 €
Guarantee
33% of the
value of the
volume of gas
6.666.666,67 €
(1) : 0,036556 €/GJ ; 1 GJ = 0,278 MWh
(2) : 0,004424 €/GJ ; 1GJ = 0,278 MWh
(3) : 1,97 €/liquid m3 ; 1 liquid m3 equivalent to 600 gas m3 ; 1 gas m3 = 11,3 kWh
Belgium (new tariff)
1 TWh
Charge per slot 750.443,00 € 750.443,00 €
Gas Consumption (reference: 20
€/MWh)
1,3% 260.000,00 €
Total 1.010.443,00 €
Guarantee
100 % of the
average monthly
invoice
1.010.443,00 €
A slot includes unloading, storage and regasification capacity for 10 days
ENERGY SECTOR INQUIRY – ANNEXES (Second phase – Gas)
359
A slot includes unloading of cargoes, 5 days of free storage, regasification rights and loading of LNG trucks
(1) : 0,086873 €/m3/day
(2): It is recovered one year later. It is lost in case of infrautilization of the capacity. There is no need for bail in case the TPA contract duration < 1 year. In consequence,
cargo
Source: Commission elaboration of IEFE and national regulators data.
For France, the calculation is not possible for less than 30 days, since GdF proposes only a
constant emission during 30 days for a spot cargo. Nevertheless, it is technically possible to
decrease the number of days of emission by using the secondary market on the point of
exchange of LNG.
ENERGY SECTOR INQUIRY – ANNEXES (Second phase – Electricity)
360
ANNEX M
This annex shows additional charts on market shares in balancing markets.
France: balancing marketsvolumessupplied for increasing
production 2003 - 2005 May
5,6%
1,7%
2,9%
4,2%
74,0%
1%
8,0%2,8%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Undertaking J
Undertaking K
Undertaking L
Undertaking M
Undertaking N
Undertaking O
Undertaking P
Undertaking Q
Undertaking RMarket shares less then 0.01 % are not indicated.
France: balancing marketsvolumessupplied for decreasing
production 2003 - 2005 May
1,2% 0,7%
0,4%
92,5%
0,6%
1,1%
0,5%
2,9%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Undertaking J
Undertaking K
Undertaking L
Undertaking M
Undertaking N
Undertaking O
Undertaking P
Undertaking Q
Undertaking RMarket shares less then 0.01 % are not indicated.
Germany: balancing marketsvolumessupplied for increasing
production 2003 - 2005 May
25,9%
34,0%
20,2%
19,7%
0,1%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Other undertakings
Germany: balancing marketsvolumessupplied for decreasing
production 2003 - 2005 May
0,4%
16,6%
19,9%
28,8%
33,9%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Other undertakings
Finland: balancing marketsvolumessupplied for increasing
production 2003 - 2005 May (exl. secondary)
84,0%
0,5%
0,01%
13,5%
0,4%
1,6%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Finland: balancing marketsvolumes supplied for decreasing
production 2003 - 2005 May (exl. secondary)
0,2%
50,0%
1,2%0,1%
0,2%
35,7%
1,9%
10,6%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Italy: balancing marketsvolumessupplied for increasing
production 2003 - 2005 May(exl. secondary)
0,00%
1,2%
0,06%
4,2%
0,11%
88,8%
0,3%
0,02%
5,0%
0,3% 0,01%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Undertaking J
Market shares smaller than
0.01 % are not indicated.
Italy: balancing marketsvolumessupplied for decreasing
production 2003 - 2005 May(exl. secondary)
0,03%
1,3%
0,01%
7,9%
0,04%
81,9%
0,8%
0,01%
6,6%
0,9%
0,03%
Undertaking
A
Undertaking
B
Undertaking
C
Undertaking
D
Undertaking
E
Undertaking
F
Undertaking
G
Undertaking
H
Undertaking I
Undertaking J
Market shares smaller than
0.01 % are not indicated.
Netherlands: balancing marketsvolumessupplied for increasing
production 2003 - 2005 May
1,1%
0,1%
93,3%
1,4%
2,1% Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Netherlands: balancing marketsvolumessupplied for
decreasing production 2003 - 2005 May
15,4%
29,4%
20,7%
34,3%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
ENERGY SECTOR INQUIRY – ANNEXES (Second phase – Electricity)
361
Poland: balancing marketsvolumessupplied for increasing
production 2003 - 2005 May
13,2%
4,0%
1,1%
19,3%
4,8%
12,6%
6,3%
12,3%
19,0%
0,1%
6,3%
1,0%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Undertaking J
Undertaking K
Undertaking L
Poland: balancing marketsvolumessupplied for decreasing
production 2003 - 2005 May
9,6%
21,2%
4,0%
6,2%
1,1%
1,8%
28,9%
2,3%
7,0%
6,6%
0,4%
11,0%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Undertaking J
Undertaking K
Undertaking L
Spain: balancing marketsvolumessupplied for increasing
production 2003 - 2005 May
3,3%
32,0%
0,4%
0,1%
6,2%
0,6%
1,0%
1,0%
0,9%
35,1%
0,0%
0,2% 0,1%
13,1%
6,0%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Undertaking J
Undertaking K
Undertaking L
Undertaking M
Undertaking N
Undertaking O
Spain: balancing marketsvolumessupplied for decreasing
production 2003 - 2005 May
3,3%
5,4%
10,3%
0,1%2,0%
0,1%
28,1%
3,6%
0,5%
4,7%
0,4%
6,1%
0,2%
1,7%
33,6%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Undertaking H
Undertaking I
Undertaking J
Undertaking K
Undertaking L
Undertaking M
Undertaking N
Undertaking O
Sweden: balancing marketsvolumes supplied for increasing
production 2003 - 2005 May
3,3%2,5%
24,0%
44,9%
25,2%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Sweden: balancing marketsvolumessupplied for decreasing
production 2003 - 2005 May
3,2%1,3%
23,0%
54,2%
18,4%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Slovenia: balancing markets volumes supplied for
increasing production 2003 - 2005 May
13,3%
77,6%
6,3%
2,2%0,7%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Slovenia: balancing marketsvolumessupplied for decreasing
production 2003 - 2005 May
18,8%
76,0%
5,2%
Undertaking A
Undertaking B
Undertaking C
Slovakia: balancing marketsvolumes supplied for increasing
production 2003 - 2005 May
2,7%
2,1%
0,6%
2,4%
88,4%
3,7%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
Slovakia: balancing marketsvolumessupplied for decreasing
production 2003 - 2005 May
22,5%
1,2%
3,8%
69,4%
3,1%
Undertaking A
Undertaking B
Undertaking C
Undertaking D
Undertaking E
Undertaking F
Undertaking G
yy
Source: Energy Sector Inquiry 2005/2006
Note: though Germany has four so-called control areas it is reasonable to aggregate the volumes for reserves
across these areas since supplying reserve power across control areas id possible. The figure reveals that
four actors are mainly supplying reserves.
ENERGY SECTOR INQUIRY – ANNEXES (Second phase – Electricity)
362
ANNEX N
This annex shows the merit curves in different markets.
Source: Energy Sector Inquiry 2005/2006.
Note: For these two graphs, since there is one operator representing most of the curve, figures on the
vertical axis are rounded.
ENERGY SECTOR INQUIRY – ANNEXES (Second phase – Electricity)
363
Source: Energy Sector Inquiry 2005/2006.