Elia System and market overview 2010

Transcription

1 Elia System and market overview 2010

2 Table of contents I. System and grid management and market data 01 I.1 Energy balance on the Elia grid in I.2 Consumption recovers in Elia control area in 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 I.9 Reliability 16 I.10 Balancing 17 II. Infrastructure 19 II.1 Length of Elia grid on 31 December 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

3 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 (in GWh) Imports Exports 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 Net injection Net consumption 2 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: Total: 85,287.4 Total: 86,311.2 Energy losses: 1,575.4 Energy balance on the Elia grid in 2009 (in GWh) Imports Exports France: France: 6,642.5 Luxembourg: Luxembourg: Netherlands: Netherlands: 3,769.3 Net Export 1,835.3 Net injection Net consumption 2 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: Total: 80,849.6 Total: 84,085.5 Energy losses: 1,400.6 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 The recovery begun in late 2009 continued throughout The values recorded in 2010 are higher, month by month, than the corresponding values for Up to and including October 2010, they were lower than the same months in 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 Figures as of 1 June Consumption on the Elia grid, including consumption supplied by local generation

4 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 indicator 3 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, GWh in 2009 and 697 GWh in 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).

5 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 Values are based on the consumption indicator (see definition above; see also 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 10,500 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 ,479 13,360 12,822 12,454 11,890 12,138 11,968 11,790 11,796 12,022 12,706 12, ,531 12,752 11,820 11,021 10,923 11,035 11,354 11,221 11,314 11,969 12,365 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

6 04 ELIA System and market overview 2010 MW 14,500 14,000 13,500 13,000 12,500 12,000 11,500 11,000 10,500 10,000 Jan Feb March April May June July Aug Sept Oct Nov Dec Synchronous peak Avg. max. temp. Avg. min. temp. Jan Feb March April May June July Aug Sept Oct Nov Dec Synchronous peak in MW 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 Avg. min. temp Monthly average temperature Jan Feb March April May June July Aug Sept Oct Nov Dec Avg. temp Avg. temp Source: Belgian Royal Meteorological Institute Rise in Gross Domestic Product per quarter in 2010 compared to same quarter in e quarter 2 nd quarter 3 rd quarter 4 th quarter Growth GDP 1.7 % 2.7 % 2.0 % 2.1 % Source: National Bank of Belgium-Belgostat

7 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 The values of these injections are based on the consumption indicator (see definition above; see also Electricity consumption is largely determined by the temperature and the season. TWh/month C Energy 2009 (TWh) Energy 2010 (TWh) Avg. temp Jan Feb March April May June July Aug Sept Oct Nov Dec -5 Avg. temp Jan Feb March April May June July Aug Sept Oct Nov Dec Energy 2010 (TWh) Energy 2009 (TWh) Avg. temp Avg. temp

8 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 Flanders 48,759 48,187 43,884 45,472 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 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 facility MW Nuclear power plants 5,934 Conventional power plants 2,619 Multifuels 763 One fuel 1,856 CCGT and gas turbines 4,387 Hydroelectric 82 Other 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.

9 07 ELIA System and market overview 2010 Breakdown of installed generation capacity in % 0.5% 16.3% 8.2% 37% Nuclear CCGT and gas turbines Conventional Hydroelectric Pump stations 27.4% Other Breakdown of generation per type of generation facility in % 9% 9.4% 55.5% Nuclear CCGT and gas turbines 24.5% Conventional 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 4,000 3,000 2,000 1,000 0 jan feb march april may june july aug sept oct nov dec Nuclear CCGT and gas turbines Conventional Hydroelectric Pump stations Other

10 08 ELIA System and market overview 2010 I.7 Imports and exports Physical energy exchanges with neighbouring countries Import and export volumes Belgium 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 electrical 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 France Imports 8, , , ,167.0 Exports 2, , , ,409.0 Netherlands Imports 5, , , ,382.7 Exports 5, , , ,313.3 Luxembourg Imports 2, , , ,845.8 Exports 1, , ,121.5 Total Imports 15, , , ,395.5 Exports 9, , , ,843.8 Net imports Net imports Net exports Net imports 6, , , 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.

11 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 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 October November December -2,000-1,500-1, ,000 1,500 GWh Exchanges with Luxembourg Exchanges with the Netherlands Exchanges with France Import and export volumes in 2009 Imports Exports January February March April May June July August September October November December -1,500-1,000-5, ,500 2,000 GWh Exchanges with Luxembourg Exchanges with the Netherlands Exchanges with France

12 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 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 October November December -3,500-3,000-2,500-2,000-1,500-1, ,000 1,500 GWh Year Month Day Intraday Not nominated

13 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 October November December -3,500-3,000-2,500-2,000-1,500-1, ,000 1,500 GWh Year Month Day Intraday Not nominated Use of transmission capacity at Belgium s north border in 2010 Imports Exports January February March April May June July August September October November December -1,500-1, ,000 1,500 GWh Year Month Day Intraday Not nominated

14 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 October November December -1,500-1, ,000 1,500 GWh Year Month Day Intraday Not nominated 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 December -100 % -80 % -60 % -40 % -20 % 0 % 20 % 40 % 60 % 80 % 100 % Percentage of hours with congestion

15 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 December -100 % -80 % -60 % -40 % -20 % 0 % 20 % 40 % 60 % 80 % 100 % Percentage of hours with congestion Congestion at the north border in 2010 Imports Exports January February March April May June July August September October November December -100 % -80 % -60 % -40 % -20 % 0 % 20 % 40 % 60 % 80 % 100 % Percentage of hours with congestion

16 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 December -100 % -80 % -60 % -40 % -20 % 0 % 20 % 40 % 60 % 80 % 100 % Percentage of hours with congestion I.8 Belpex day-ahead market in 2010 Price change on the Belpex day-ahead market in 2010 /Mwh APX Belpex EPEX Spot FR 0 Jan Feb March April May June July Aug Sept Oct Nov Dec Source: APX, Belpex, EPEX Spot EPEX Spot DE 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

17 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 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 % 31,45 % % February % % % March % 6.73 % % April % % May % % % June % % July % % 6.45 % August September October November December % % % % % % 9.53 % % % % % % % 0 % 10 % 20 % 30 % 40 % 50 % 60 % 70 % 80 % 90 % 100 % BE=NL=FR=DE BE=FR=NL, DE <> BE = FR BE = NL BE = DE Other 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.

18 16 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 customer 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 %. 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 00:01:00 00:00: Number of minutes per customer per year Average per five years Average annual frequency of interruptions per customer Frequency Annual frequency Average per five years

19 17 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: Minutes per interuption Average per five years Average Average Average Reliability Number of days Interruption Interruption Interruption Elia grid per year Time 5 Frequency 6 Duration : : % : : % : : % : : % : : % 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 Elia s request. The table and chart outline the amounts of electricity used by Elia to balance the grid each month.

20 18 ELIA System and market overview 2010 Activated volumes for balancing in 2010 Decrease injections Increase injections January February March April May June July August September October November December -60,000-40,000-20, ,000 40,000 60,000 80, ,000 MWh Secondary reserve + Secondary reserve - Generation + Generation - Tertiary reserve Contractual interruptions Inter TSO Import Inter TSO Export Month Secundary Secundary Generation + Generation - Tertiary Contractual Inter TSO Inter TSO 2010 reserve + reserve - (free offers) 8 (free offers) 8 reserve interruptions Import 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 Sept 21,855 MWh -32,613 MWh 4,570 MWh -4,507 MWh 163 MWh 0 MWh 0 MWh 1,150 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 Secondary reserve R2 Tertiary reserve R3 Interruptible customers 9 92 MW 137 MW 400 MW 261 MW 9 Average volume available

21 19 ELIA System and market overview 2010 II. Infrastructure II.1 Length of Elia grid on 31 December 2010 (in kilometres) Connections Voltage (kv) Underground 10 (km) Overhead 11 (km) Total (km) ,008 2, ,382 2, , , Total 2,775 5,608 8, Underground connections: electrical length 11 Overhead lines: route length II.2 Access points Access points on Elia grid by region Overview of access points Federal Regional Flanders Brussels Wallonia (including Sotel) Total Belgium kv kv 70 kv - 30 kv Direct customers: offtake points Direct customers: injection points 9 10 Direct customers: offtake and injection points Total direct customers Total distribution system operators Access points on Elia grid by type of customer Total Direct customers DSOs Total Belgium

22 20 ELIA System and market overview 2010 II.3 Commissionings Commissionings in 2010 Line Cable/overhead Voltage Circuit Length Type MVA Aubange - Moulaine L , km 707 AMS 2 x (1.7 km in Belgium) 442 MVA Blauwe Toren - Brugge K , km 2,000 AluPRC 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 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. 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

23 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 CO 2. 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 2,250 2,050 GC Flanders region 2,090 /Certificate 1,850 1,650 1,450 1,250 1, , Price Number Sales date

24 02 ELIA Systeem- en marktoverzicht Elia Boulevard de l Empereur 20 B-1000 Brussels Tel: Fax: Editor Jacques Vandermeiren