Elia System and market overview 2010
Table of contents I. System and grid management and market data
01
I.1 Energy balance on the Elia grid in 2010
01
I.2 Consumption recovers in Elia control area in 2010
02
I.3 Power injected into the Elia control area and temperature
03
I.4 Energy injected into the Elia control area
05
I.5 Net offtake
06
I.6 Generation
06
I.7 Imports and exports
08
I.8 Belpex day-ahead market in 2010
14
I.9 Reliability
16
I.10 Balancing
17
II. Infrastructure
19
II.1 Length of Elia grid on 31 December 2010
19
II.2 Access points
19
II.3 Commissionings
20
II.4 Nominal capacity of interconnection lines
20
III. Rational use of energy
21
III.1 Energy savings
21
III.2 Green certificates
21
01 • ELIA System and market overview 2010
I. System and grid management and market data I.1 Energy balance on the Elia grid in 2010 Energy balance on the Elia grid in 20101 (in GWh) Exports
Imports France:
3,167.0
France:
5,409.0
Luxembourg:
1,845.8
Luxembourg:
1,121.5
Netherlands:
7,382.7
Netherlands:
5,313.3
Net Import 551.7 Net injection
Net consumption2
Power stations:
76,545.2
Direct customers:
29,176.7
Local generation on Elia-net:
9,068.9
Distribution:
56,110.8
From distribution networks:
697.0
Total:
85,287.4
Total:
86,311.2
Energy losses: 1,575.4
Energy balance on the Elia grid in 2009 (in GWh) Exports
Imports France:
1 831.9
France:
6,642.5
Luxembourg:
1 867.5
Luxembourg:
909.7
Netherlands:
5 786.8
Netherlands:
3,769.3
Net Export 1,835.3 Net injection
Net consumption2
Power stations:
76,192.2
Direct customers:
25,740.4
Local generation on Elia-net:
7,214.0
Distribution:
55,109.2
From distribution networks:
679.2
Total:
80,849.6
Total:
84,085.5
Energy losses: 1,400.6
1 Figures as of 1 June 2011 2 Consumption on the Elia grid, including consumption supplied by local generation
The energy balance provides an overview of imports and exports, injections into the Elia grid in Belgium, consumption and energy losses during transmission. Net injections cover net injections from distribution networks and by power stations, pumped-storage power stations and local generation units that inject energy into the grid at a voltage of at least 30 kV. Generation units connected to a voltage lower than 30 kV are only counted if a net injection into the Elia grid is measured. A customer with local generation takes electrical energy off the grid at the same point where local generation units inject it into the grid. Consumption only covers the consumption of local generation from the Elia grid, not from grids of voltages under 30 kV. Consumption is split into two categories: Elia’s direct grid users and distribution networks. The amount of energy is expressed in gigawatt-hours (GWh). By way of example, one gigawatt-hour is the amount of power needed to light 50 million 20 W energy-efficient lamps for one hour. The consumption on the Elia grid rose 5.5 %, from 80.8 TWh in 2009 to 85.3 TWh in 2010, effectively halting the downward trend caused by the recession that began to bite in the fourth quarter of 2008. The recovery begun in late 2009 continued throughout 2010. The values recorded in 2010 are higher, month by month, than the corresponding values for 2009. Up to and including October 2010, they were lower than the same months in 2008. On the whole, consumption in 2010 was up 13.3 % on 2009 for industrial customers connected directly to the Elia grid, and up 1.8 % for industrial, business and residential customers of the distribution system operators. However, there remains a 1.1 % drop in consumption compared to 2008.
02 • ELIA System and market overview 2010
I.2. Consumption recovers in Elia control area in 2010 Consumption levels in the Elia control area, based on the Elia consumption indicator3 reached their 2010 peak at 13,845 MW between 17:45 and 18:00 on 1 December. This peak was 1.1 % lower than the absolute record set on 17 December 2007 (14,040 MW), but is 2.3 % higher than the 2009 peak (13,531 MW on 8
January 2009). Consumption was at its lowest in 2010 between 06:15 and 06:30 on 25 July, when it bottomed out at 6,278 MW, 6.4 % higher than the 2009 minimum recorded on 26 July 2009 (5,901 MW).
3 The consumption indicator pertains to the largest proportion of consumption in the control area, but not to all consumption. With the development of decentralised generation (such as wind farms and cogeneration units), which inject the energy produced into the distribution grids, the difference between actual consumption in the control area and the consumption indicator based on measurements in the Elia control area is gradually growing. Consumption at distribution level is determined in part by weather conditions. The consumption indicator is based on injections of power into the Elia grid and gives a rough idea of electricity consumption in the Elia control area. It takes as its basis net generation from power stations and local generation units injecting at a minimum voltage of 30 kV as well as the balance of imports and exports The energy needed to pump water into power-station storage reservoirs is subtracted as it is used to temporarily store energy which is then re-injected into the grid. Generating facilities connected to the distribution network, such as wind turbines, small water turbines and small cogeneration units, are only taken into account if a net injection from the distribution network is recorded on the Elia grid. Where this is not the case, injections by these facilities into networks at a voltage lower than 30 kV is entirely consumed within the networks concerned. Hence, the value of the consumption indicator is lower than total electricity consumption. Along with the increase in the number of decentralised generation units in distribution networks, a clear upward trend can be seen in net injections from the distribution networks into the Elia grid. Net injections into the Elia grid from the distribution networks rose from 39 GWh in 2006 to 194 GWh in 2008, 679.2 GWh in 2009 and 697 GWh in 2010. This upward trend is expected to continue in the future. The main reasons for different maximum power levels are changes in temperature and the intensity of economic activity in Belgium. The chart and table below show the maximum electrical power for each month and the average maximum and minimum temperatures for that month (in °C).
03 • ELIA System and market overview 2010
I.3. Power injected into the Elia control area and temperature The table and chart show the maximum electrical power (in MW) injected into the Elia control area for every month of the period
2008-2010. Values are based on the consumption indicator (see definition above; see also www.elia.be).
Power injected into the Elia control area in 2008, 2009 and 2010 (synchronous peak) MW 14,500 14,000 13,500 13,000 12,500 12,000 11,500 11,000 2008 10,500
2009 2010
10,000 Jan
Feb
March
April
May
June
July
Aug
Sept
Oct
Nov
Dec
MW
Jan
Feb
March
April
May
June
July
Aug
Sept
Oct
Nov
Dec
2008
13,479
13,360
12,822
12,454
11,890
12,138
11,968
11,790
11,796
12,022
12,706
12,875
2009
13,531
12,752
11,820
11,021
10,923
11,035
11,354
11,221
11,314
11,969
12,365
13,046
2010
13,692
13,335
12,616
11,613
11,808
11,472
11,567
11,459
11,468
12,236
13,467
13,845
Monthly power injections into the Elia control area and average temperatures in 2010 The main reasons for different maximum power levels are changes in temperature and the intensity of economic activity in Belgium. The chart and table below show the maximum electrical power for
each month and the average maximum and minimum temperatures for that month (in °C). Values are based on the consumption indicator (see definition in footnote 3; see also www.elia.be).
04 • ELIA System and market overview 2010
MW 14,500 14,000 13,500 13,000 12,500 12,000 11,500 11,000
Synchronous peak
10,500
Avg. max. temp. Avg. min. temp.
10,000 Jan
Feb
Synchronous peak in MW
March
April
May
June
July
Aug
Sept
Oct
Nov
Dec
Jan
Feb
March
April
May
June
July
Aug
Sept
Oct
Nov
Dec
13,692
13,335
12,616
11,613
11,808
11,472
11,567
11,459
11,468
12,236
13,467
13,845
Avg. max. temp.
3.70
6.30
3.70
17.40
19.10
21.30
23.60
24.90
20.40
15.10
12.10
5.30
Avg. min. temp.
-2.50
0.80
-2.50
7.60
9.50
12.10
14.50
13.80
11.50
7.50
7.40
0.20
April
May
June
July
Aug
Sept
Oct
Nov
Dec
Monthly average temperature
Jan
Feb
March
Avg. temp. 2010
0.10
2.50
6.70
10.30
11.20
17.40
20.50
17.00
14.20
10.60
6.10
-0.70
Avg. temp. 2009
0.70
3.60
6.70
12.50
14.40
16.50
18.70
19.40
15.80
11.30
9.70
6.90
Source: Belgian Royal Meteorological Institute
Rise in Gross Domestic Product per quarter in 2010 compared to same quarter in 2009 Growth GDP
1e quarter
2nd quarter
3rd quarter
4th quarter
1.7 %
2.7 %
2.0 %
2.1 %
Source: National Bank of Belgium-Belgostat
05 • ELIA System and market overview 2010
I.4 Energy injected into the Elia control area Monthly energy injections into the Elia control area in 2009 and 2010 The chart below shows the amount of electrical energy (in TWh) injected into the Elia control area and the average temperature in C° for every month in the period 2009-2010. The values of these
injections are based on the consumption indicator (see definition above; see also www.elia.be). Electricity consumption is largely determined by the temperature and the season.
TWh/month
C°
9
25
8 20 7 6
15
5 10 4 3
5
2
Energy 2009 (TWh) 0
Energy 2010 (TWh)
1
Avg. temp. 2009
0
Avg. temp. 2010
-5 Jan
Feb
March
April
May
Jan
June
Feb
July
March
Aug
April
Sept
Oct
May
Nov
June
Dec
July
Aug
Sept
Oct
Nov
Dec
Energy 2010 (TWh)
8.19
7.31
7.61
6.93
6.92
6.73
6.56
6.53
6.80
7.27
7.50
8.20
Energy 2009 (TWh)
7.83
7.00
7.03
6.33
6.37
6.27
6.22
6.30
6.65
7.16
7.01
7.59
Avg. temp. 2010
0.10
2.50
6.70
10.30
11.20
17.40
20.50
17.00
14.20
10.60
6.10
-0.70
Avg. temp. 2009
0.70
3.60
6.70
12.50
14.40
16.50
18.70
19.40
15.80
11.30
9.70
2.90
06 • ELIA System and market overview 2010
I.5 Net offtake The net offtake of electrical energy is the sum of the net energy taken off the grid at all access points, including the net offtake (measured at the Belgian border) of Luxembourg system operator
Sotel. The net offtake per region is based on the location of the offtake points and hence is an approximation of the real net offtake per region.
Net offtake in the Elia control area per region GWh
2007
2008
2009
2010 45,472
Flanders
48,759
48,187
43,884
Brussels
5,839
5,896
5,863
5,907
Wallonia (Sotel included)
24,000
24,420
24,044
25,010
Total Belgium
78,598
78,503
73,791
76,390
Net offtake in the Elia control area per type of customer GWh
2007
2008
2009
2010
Direct customers
21,291
20,775
18,559
20,143
Distribution networks
57,307
57,728
55,232
56,247
Total
78,598
78,503
73,791
76,390
I.6 Generation Total power per type of generation facility4 2010
MW
Nuclear power plants
5,934
Conventional power plants
2,619
Multifuels
One fuel
CCGT and gas turbines Hydroelectric Other
763 1,856 4,387 82 1,705
Cogeneration
958
Incinerators
171
Diesel engines
83
Turbojets
180
Wind turbines
313
Pump stations
1,308
Total without pump stations
14,726
Total with pump stations
16,034
4 Facilities with a CIPU contract with Elia; values based on the maximum technical capacity.
07 • ELIA System and market overview 2010
Breakdown of installed generation capacity in 2010 10.6%
8.2% 37% 0.5% Nuclear CCGT and gas turbines 16.3%
Conventional Hydroelectric Pump stations Other 27.4%
Breakdown of generation per type of generation facility in 2010 9% 1.6% 9.4%
Nuclear 55.5%
CCGT and gas turbines Conventional
24.5%
Pump stations Other, including hydroelectric
Electricity generation per type of generation facility per month in 2010 GWh 8,000 7,000 6,000 5,000
Nuclear
4,000
CCGT and gas turbines
3,000
Conventional
2,000
Hydroelectric
1,000
Pump stations Other
0 jan
feb
march
april
may
june
july
aug
sept
oct
nov
dec
08 • ELIA System and market overview 2010
I.7 Imports and exports Physical energy exchanges with neighbouring countries Import and export volumes – Belgium 2007-2010 The table provides an overview of the physical flows of electrical energy measured at Belgium’s borders each year. Physical flows do not necessarily correspond to contractual flows, as electri-
cal energy is divided up over the grid on the basis of resistance, always choosing the path of least resistance, and does not take account of the contents of commercial agreements.
GWh
2007
2008
2009
2010
France
Imports
8,331.6
7,386.3
1,831.9
3,167.0
Exports
2,322.4
2,038.6
6,642.5
5,409.0
Netherlands
Imports
5,265.8
8,118.6
5,786.8
7,382.7
Exports
5,083.7
3,004.6
3,769.3
5,313.3
Luxembourg
Imports
2,083.9
1,628.6
1,867.5
1,845.8
Exports
1,630.7
1,517.9
909.7
1,121.5
Total
Imports
15,681.3
17,133.5
9,486.2
12,395.5
Exports
9,036.8
6,561.1
11,321.5
11,843.8
Net imports
Net imports
Net exports
Net imports
6,644.5
10,572.3
1,835.3
551.7
Net electricity import balance in 2010 As regards the balance of imports and exports for the Belgian control area, 2010 saw net imports of 0.55 TWh, while 2009 had net exports of 1.83 TWh. Physical exchanges of electricity with neighbouring countries via the Elia grid totalled 24.2 TWh, a 16.3 % increase compared to the 2009 total of 20.8 TWh of
exchanges. In other words, some 14.5 % of consumption in the Elia control area in 2010 came from imports. These differences were the result of a sharp rise in imports from the Netherlands and France, while total exports rose only slightly compared to 2009.
09 • ELIA System and market overview 2010
Monthly import and export volumes in 2010 and 2009 The charts below show physical exchanges of electricity with neighbouring countries in GWh for 2010 and 2009. Negative volumes indicate imports while positive volumes indicate exports. Electricity chooses the path of least resistance, so that physical
exchanges of electricity do not necessarily correspond to international commercial exchanges. However, the grid operator must take account of the actual physical flows at Belgium’s borders.
Import and export volumes in 2010 Imports
Exports
January February March April May June July August September
Exchanges with Luxembourg
October November
Exchanges with the Netherlands
December
Exchanges with France
-2,000
-1,500
-1,000
-500
0
500
1,000
1,500
GWh
Import and export volumes in 2009 Imports
Exports
January February March April May June July August September
Exchanges with Luxembourg
October November
Exchanges with the Netherlands
December
Exchanges with France
-1,500
-1,000
-5,000
0
500
GWh
1000
1,500
2,000
10 • ELIA System and market overview 2010
Commercial energy exchanges with neighbouring countries Use of cross-border capacities Transmission capacity at borders is divided into three parts and allocated on an annual, monthly and daily basis to market parties. Market parties can use the annual and monthly capacity allocated to them by nominating it on a day-ahead basis. Allocated annual and monthly capacity which is not nominated is redistributed as additional daily capacity to the market parties. Since 2008, the principle of “netting” has also been applied to calculate the amount of available daily capacity. This involves “netting out” import and export nominations of annual and monthly capacities, thereby freeing up additional available daily capacity.
Since 2007, it has also been possible to acquire and use intraday border capacity on the day of delivery at the border between France and Belgium. This system was also introduced at the Dutch-Belgian border in May 2009. The amount of intraday capacity available is mainly determined by the level of unused daily capacity. The charts below illustrate the average nominations of annual, monthly, daily and intraday capacity each month at each border. Nominations are compared to the capacity physically available to the market (net transmission capacity, or NTC).
Use of transmission capacity at Belgium’s south border in 2010 Imports
Exports
January February March April May June July August September
Year
October
Month Day
November
Intraday
December
Not nominated -3,500
-3,000
-2,500
-2,000
-1,500
-1,000
GWh
-500
0
500
1,000
1,500
11 • ELIA System and market overview 2010
Use of transmission capacity at Belgium’s south border in 2009 Imports
Exports
January February March April May June July August September
Year
October
Month Day
November
Intraday
December
Not nominated -3,500
-3,000
-2,500
-2,000
-1,500
-1,000
-500
0
500
1,000
1,500
GWh
Use of transmission capacity at Belgium’s north border in 2010 Imports
Exports
January February March April May June July August September
Year
October
Month Day
November
Intraday
December
Not nominated -1,500
-1,000
-500
0
GWh
500
1,000
1,500
12 • ELIA System and market overview 2010
Use of transmission capacity at Belgium’s north border in 2009 Imports
Exports
January February March April May June July August September
Year
October
Month Day
November
Intraday
December
Not nominated -1,500
-1,000
-500
0
500
1,000
1,500
GWh
Congestion The graphs show in percentage and in both directions the average number of hours per month with congestion on a border, as
against the total number of hours during the month. Imports are on the left, exports on the right.
Congestion at the south border in 2010 Imports
Exports
January February March April May June July August September October November Percentage of hours with congestion
December -100 %
-80 %
-60 %
-40 %
-20 %
0%
20 %
40 %
60 %
80 %
100 %
13 • ELIA System and market overview 2010
Congestion at the south border in 2009 Imports
Exports
January February March April May June July August September October November Percentage of hours with congestion
December -100 %
-80 %
-60 %
-40 %
-20 %
0%
20 %
40 %
60 %
80 %
100 %
Congestion at the north border in 2010 Imports
Exports
January February March April May June July August September October November Percentage of hours with congestion
December -100 %
-80 %
-60 %
-40 %
-20 %
0%
20 %
40 %
60 %
80 %
100 %
14 • ELIA System and market overview 2010
Congestion at the north border in 2009 Imports
Exports
January February March April May June July August September October November Percentage of hours with congestion
December -100 %
-80 %
-60 %
-40 %
-20 %
0%
20 %
40 %
60 %
80 %
100 %
I.8 Belpex day-ahead market in 2010 Price change on the Belpex day-ahead market in 2010 €/Mwh 70
60
50
40
30
20
APX Belpex
10
EPEX Spot FR EPEX Spot DE
0 Jan
Feb
March
April
May
June
July
Aug
Sept
Oct
Nov
Source: APX, Belpex, EPEX Spot
Average price on the Belpex day ahead market in 2010: 46,30 €/MWh Average price on the EPEX Spot day ahead market (France) in 2010: 47,40 €/MWh Average price on the APX day ahead market (Netherlands) in 2010: 45,38 €/MWh Average price on the EPEX Spot day ahead market (Germany) in 2010: 44,49 €/MWh
Dec
15 • ELIA System and market overview 2010
Price convergence with energy exchanges in neighbouring countries The year 2010 saw the launch on 9 November of pentalateral coupling between the Belpex, APX, EPEX Spot France and EPEX Spot Germany (including Luxembourg) day-ahead markets, combined with the ITVC (Interim Tight Volume Coupling) with the Nordic market. The effect on price convergence due tof the pentalateral coupling therefore started to be recorded as of 10 November 2010. If we look at 2010 as a whole, we note that during the year, the prices on the day-ahead markets in Belgium, France and the Netherlands were the same for 59.1 % of the time (full convergence between electricity prices in those countries). This figure is slightly below the average of 63 % achieved in the first three years of trilateral market coupling and somewhat higher than the figure for 2009, when there was complete convergence 56.8 % of the time. Prices on the Belgian and French day-ahead markets were the
same 84.9 % of the time in 2010, while prices on the Belgian and Dutch day-ahead markets were the same 72.9 % of the time. In the months prior to the launch of price coupling with Germany, we saw only sporadic, brief and purely coincidental periods of price convergence with Germany. From 10 November until the end of the year, Belgian, Dutch, French and Germany day-ahead prices were the same 55.1 % of the time. During that period, Belgian and French day-ahead prices were the same 99.7 % of the time, while Belgian and Dutch prices were the same 69.3 % of the time. Market coupling ensured optimum use of the import and export capacities at the Belgian-Dutch and Belgian-French borders, resulting in an average daily import volume of 18,099 MWh and an average export volume of 16,244 MWh.
Price convergence between the Belgian, Dutch, French and German day-ahead markets from 1 January to 31 December 2010
January February
34.81 %
31,45 %
29.17 %
March
23.36 %
25.89 %
48.21 %
36.74 %
6.73 %
54.51 %
April
19.31 %
76.94 %
May June
32.64 %
64.58 %
July
25.40 %
67.20 %
August
BE=NL=FR=DE 18.06 %
79.72 %
October
49.26 %
November
48.61 %
December
38.26 %
10 %
20 %
40 %
50 %
60 %
BE = FR BE = NL BE = DE
31.85 %
21.24 %
30 %
BE=FR=NL, DE <>
9.53 % 27.22 %
19.72 %
45.30 %
0%
6.45 %
47.04 %
50.00 %
September
18.41 %
11.96 %
68.55 %
70 %
80 %
Other 90 %
100 %
Volumes traded on Belpex The average daily volume traded on the Belpex day-ahead market in 2010 was 32,446 MWh, accounting for 13.7 % of Belgian consumption. This is somewhat higher than in 2009, when the average daily volume was 27,782 MWh or 12.4 % of consumption. In
2010, the Belpex day-ahead market set two records: 78,080 MWh was traded on 7 December 2010 (a record 27.1 % of Belgian consumption) and a record volume of 80,607 MWh was traded on 8 December.
16 â&#x20AC;˘ ELIA System and market overview 2010
I.9 Reliability Reliability indicators The Elia grid is very reliable. Reliability is measured using three statistical parameters: the average annual interruption time for each customer on the Elia grid (given in minutes per customer and per year), the average number of annual interruptions to an Elia grid
customerâ&#x20AC;&#x2122;s electricity supply (annual frequency) and the average duration (in minutes) per interruption on the Elia grid and per year. In percentage terms, the Elia grid achieves an average reliability rate of over 99.999 %.
Average annual interruption time Time (min./cust./year) 00:07:00 00:06:00 00:05:00 00:04:00 00:03:00 00:02:00
Number of minutes per customer per year Average per five years
00:01:00 00:00:00 1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
Average annual frequency of interruptions per customer Frequency 0.150 0.125 0.100 0.075 0.050 Annual frequency Average per five years
0.025 0.000 1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
17 â&#x20AC;˘ ELIA System and market overview 2010
Average interruption time per affected customer Time (hours:minutes) 1:00:00 0:55:00 0:50:00 0:45:00 0:40:00 0:35:00 0:30:00 0:25:00 0:20:00 0:15:00 0:10:00 0:05:00 0:00:00
Minutes per interuption Average per five years 1999
2000
Average Interruption Time5
2001
2002
Average Interruption Frequency6
2003
2004
Average Interruption Duration7
2005
2006
2007
Reliability Elia grid
2008
2009
2010
Number of days per year
2006
05:14
0.130
41:23
99.9990 %
365
2007
03:32
0.090
39:07
99.9993 %
365
2008
03:07
0.080
38:29
99.9994 %
366
2009
01:34
0.091
17:12
99.9997 %
365
2010
04:51
0.129
37:24
99.9991 %
365
5 Average Interruption Time is the average number of minutes of power cuts for all customers. 6 Average Interruption Frequency is the annual frequency of power interruptions per customer. A value of 0.09 indicates that on average a customer experiences a power cut every 11 years. 7 Average Interruption Duration is the average duration of a power cut experienced by a customer.
I.10 Balancing Reserve power is contracted to balance injection and offtake of electricity on the grid on an ongoing basis. This is done by increasing or reducing injections of energy or scaling down offtake among interruptible customers as required. Reserve power is broken down into primary, secondary and tertiary categories primarily on
the basis of response time and duration. Tertiary reserve power is supplied via generation as well as under contracts with interruptible customers, who are willing to shed offtake for a temporary period at Eliaâ&#x20AC;&#x2122;s request. The table and chart outline the amounts of electricity used by Elia to balance the grid each month.
18 â&#x20AC;˘ ELIA System and market overview 2010
Activated volumes for balancing in 2010 Decrease injections
Increase injections
January February March April May Secondary reserve +
June
Secondary reserve -
July
Generation +
August
Generation -
September
Tertiary reserve
October
Contractual interruptions
November
Inter TSO Import
December
Inter TSO Export
-60,000
-40,000
-20,000
0
20,000
40,000
60,000
80,000
100,000
MWh
Month 2010
Secundary reserve +
Secundary reserve -
Generation + (free offers) 8
Generation - (free offers) 8
Tertiary reserve
Contractual interruptions
Inter TSO Import
Inter TSO Export
Jan
37,118 MWh
-22,182 MWh
12,894 MWh
-2,295 MWh
1,915 MWh
652 MWh
975 MWh
0 MWh
Feb
28,279 MWh
-24,655 MWh
9,066 MWh
-1,416 MWh
1,366 MWh
149 MWh
0 MWh
0 MWh
March
23 ,742 MWh
-37,875 MWh
8,272 MWh
-11,245 MWh
551 MWh
0 MWh
0 MWh
2,400 MWh
April
22,873 MWh
-33,558 MWh
3,347 MWh
-10,177 MWh
0 MWh
308 MWh
0 MWh
200 MWh
May
24,715 MWh
-29,364 MWh
6,508 MWh
-3,942 MWh
446 MWh
0 MWh
0 MWh
150 MWh
June
32,240 MWh
-20,640 MWh
6,670 MWh
-557 MWh
1,938 MWh
0 MWh
1,750 MWh
0 MWh
July
40,271 MWh
-18,678 MWh
16,942 MWh
-638 MWh
5,845 MWh
372 MWh
0 MWh
0 MWh
Aug
31,003 MWh
-25,621 MWh
5,443 MWh
-2,191 MWh
812 MWh
0 MWh
750 MWh
0 MWh 1,150 MWh
Sept
21,855 MWh
-32,613 MWh
4,570 MWh
-4,507 MWh
163 MWh
0 MWh
0 MWh
Oct
27,399 MWh
-31,960 MWh
7,727 MWh
-6,060 MWh
3,366 MWh
0 MWh
0 MWh
1,175 MWh
Nov
42,085 MWh
-15,601 MWh
14,974 MWh
-238 MWh
4,923 MWh
1,235 MWh
350 MWh
1,200 MWh
Dec
46,492 MWh
-14,748 MWh
30,175 MWh
-429 MWh
5,688 MWh
2,155 MWh
975 MWh
3,050 MWh
Load-shedding in the context of the load-shedding plan and activated volumes for congestion management are not included in the activated volumes for balancing. 8 Free offers under the CIPU contract.
Contracted reserve power in 2010 Primary reserve R1
92 MW
Secondary reserve R2
137 MW
Tertiary reserve R3
400 MW
Interruptible customers 9
9 Average volume available
261 MW
19 â&#x20AC;˘ ELIA System and market overview 2010
II. Infrastructure II.1 Length of Elia grid on 31 December 2010 (in kilometres) Connections Voltage (kV)
Underground10 (km) Overhead11 (km)
Total (km)
380
-
891
220
-
297
891 297
150
427
2,008
2,435
70
280
2,382
2,662
36
1,927
8
1,935
30
141
22
163
Total
2,775
5,608
8,383
10 Underground connections: electrical length 11 Overhead lines: route length
II.2 Access points Overview of access points
Access points on Elia grid by region
2006
2007
2008
2009
2010
Federal
Regional
380 kV - 150 kV
70 kV - 30 kV
Direct customers: offtake points
46
139
Direct customers: injection points
9
10
Direct customers: offtake and injection points
37
55
Total direct customers
92
204
Total distribution system operators
0
510
Total
92
714
Flanders
411
410
413
414
416
Brussels
55
55
55
56
56
Wallonia (including Sotel)
316
318
328
329
334
Total Belgium
782
783
796
799
806
Access points on Elia grid by type of customer
2006
2007
2008
2009
2010
Direct customers
281
281
290
290
296
DSOs
501
502
506
509
510
Total Belgium
782
783
796
799
806
20 • ELIA System and market overview 2010
II.3 Commissionings Commissionings in 2010 Line
Cable/overhead
Voltage
Circuit
Aubange - Moulaine L
220.00 2,00
Blauwe Toren - Brugge
150.00
K
1,00
Length
Type
13.3 km 707 AMS (1.7 km in Belgium) 7.5 km
2,000 AluPRC
MVA 2x 442 MVA 300 MVA
II.4 Nominal capacity of interconnection lines The nominal capacity of an international high-voltage line is determined by its voltage and type of cable. However, the extent to which this capacity can actually be used depends on the energy flows within the grids as well as on the safety margins the transmission system operators have to apply to ensure security of
Line
Voltage
Type
MVA
North border Van Eyck – Maasbracht
380 kV
2x593 AMS-AC
1,350
Meerhout – Maasbracht
380 kV
2x620 AMS
1,420
Zandvliet – Borsele
380 kV
3x460 AMS
1,650
Zandvliet – Geertruidenberg
380 kV
3x460 AMS
1,650
South border Achêne – Lonny
380 kV
2x 570 AMS
1,350
Avelgem – Avelin
380 kV
2x 705 AMSzz
1,550
Avelgem – Mastaing
380 kV
2x 593 AMS-AC
1,350
Monceau – Chooz
220 kV
707 Alac
405
Aubange – Moulaine
220 kV
2 x 570 AMS
800
supply, factoring in unavailability as a result of works and potential incidents. Therefore, the available border capacity is never equal to the sum of the nominal capacities of the individual interconnection lines.
21 • ELIA System and market overview 2010
III. Rational use of energy III.1Energy savings Promoting rational use of energy by our customers As part of its public-service obligations in Flanders, Elia implements an action plan each year to promote rational use of energy (RUE) amongst its industrial customers. In this connection, Elia provides its customers with the resources required to make recurrent savings of 2.5 % on their primary energy consumption for each MWh supplied, in the case of facilities connected at between 36 kV and 70 kV.
The objective set for 2010 was savings of 45.2 GWh of electric power, while savings of 27 GWh have been made. A total of 30 projects were launched and our customers undertook to invest in some 52 energy-saving projects. Thanks to the initiatives Elia has taken amongst its industrial customers, cumulative energy savings since 2003 stood at 453 GWh at the end of December 2010, i.e. some 147,250 tonnes of CO2.
III.2 Green certificates The Belgian federal and regional governments have developed support mechanisms in order to boost investments in electricity generation from renewable energy sources. One of these consists of the green certificates system, issued to generators of renewables by the regulator as an acknowledgement of the “green” origin of power. These certificates can be purchased by the market players (suppliers) or sold to Elia. Suppliers must each year present a certain number of green certificates to the
regulator. The required number is based on their power sales. Transmission system operator Elia has a legal obligation to purchase the certificates offered at a minimum price. Elia returns these certificates to the market via Belpex. The balance between the price at which Elia purchases the certificates and the price at which they are sold on Belpex is covered by a levy on the transmission tariffs.
Price and volumes of green certificates Number
€/Certificate
GC Flanders region
2,250
2,090
2,050 1,850 1,650 1,450 1,250 1,050
118.74
850
672
650 450 250 50
117.52 110.76
313
258 17-02-06
981
117.47
25-10-06
02-02-07
663
112 109.13 421
125.00
970
120.00 115,00
112
110.00 105.00
363 97
20-10-10 29-02-08 12-03-09 10-12-09 28-09-07 24-10-08 Sales date
100.00 95.00
Price
90.00 Number
02 • ELIA Systeem- en marktoverzicht 2010
www.elia.be
Elia Boulevard de l’Empereur 20 B-1000 Brussels Tel: +32 2 546 70 11 Fax: +32 2 546 70 10
Editor Jacques Vandermeiren