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The German Wind Resource and Norwegian Hydro – Interesting Possibilities Lars Audun Fodstad, SVP, Statkraft Energy AS,. BMU. 5th July 2010, Berlin. WITHIN RENEWABLES IN EUROPE. No. 1. RENEWABLE ENERGY. 90%. 264. POWER AND DISTRICT HEATING PLANTS. 35%. OF NORWAY’S POWER GENERATION.

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  1. The German Wind Resource and Norwegian Hydro – Interesting PossibilitiesLars Audun Fodstad, SVP, Statkraft Energy AS, BMU 5th July 2010, Berlin

  2. WITHIN RENEWABLES IN EUROPE No.1 RENEWABLE ENERGY 90% 264 POWER AND DISTRICT HEATING PLANTS 35% OF NORWAY’S POWER GENERATION ...IN MORE THAN 20COUNTRIES 3200EMPLOYEES..

  3. FROM STATKRAFT’S KEY AREAS European Flexible Generationand Market Operations • Develop and optimize hydro portfolio in Norway and Sweden, including small hydro in Norway • Evaluate European growth opportunities for flexible hydropower, including France • Build and upgrade gasfired power plants in core markets (Continent/UK) side 3

  4. THE North sea area wind power development – 2020 scenario Offshore: 40 000 MW Total onshore/offshore: 100 000 MW Creating a Wind Belt onshore/offshore from UK via France, Belgium, The Netherlands, Germany, Denmark and Southern Sweden side 4

  5. Grid and grid integration - Main challenges • Infrastructure Development • Connecting VarRES to • Load centres • Flexibility options • Storage facilities • Enabling market development • See entsoe’s TYNDP • Handling the wind production’s variability • Wind power developing from a minor to a main part of the production portfolio with dispatch priority • Creates new need for flexibility in the other parts of the electricity system side 5

  6. Transmission challenges Source: entsoe TYNDP • Bringing 40 000 MW onshore • HVAC can and will be used for relatively small capacities over shorter distances • HVDC has to be used for larger capacities and longer distances –the new VSC technology is able to operate without a grid backup • Bringing 100 000 MW to the load centres • Upgrading AC overhead lines • HVDC cable connections? • Difficult, but it has to be done side 6

  7. THE WIND PRODUCTION’S VARIABILITY

  8. FLEXIBILITY CHALLENGES Ref. TradeWind 2020 • Variations in wind power production • Europe looked upon as one bus bar • Max. 54 % of installed capacity • Min. 9 % of Installed capacity • Difference 45 % of installed capacity or 95 GW • Less than four days between top and bottom • Regional example: The Netherlands as one bus bar • Max. 93 % of installed capacity • Min. 0 % of installed capacity • Rises from 7 to 90 % of installed capacity (6 GW in 2030) in six hours (time resolution for wind data) side 8

  9. FLEXIBILITY OPTIONS • Production • Nuclear • Fossil fired, gas and coal • Reservoir based hydro • Storage • Pumped Storage • CAES • Batteries/EV • DSM/Smart Grids • Connecting and further develop the Norwegian hydro resource to deliver a significant part of the needed flexibility? side 9

  10. EUROPEAN Hydro Flexibility – SLIDE I • Reservoir based hydro power in the production mix • In general used for storage and peak power production • In Norway developed for storage and base load • Key factors for hydro as storage and peak power • Annual Energy Production, inflow TWh • Reservoir Capacity TWh • Installed Capacity MW • Hydro Energy Production, Storage Capacity and Rated Power (1998) • UCTE 86 TWh 57 TWh 49 GW • Norway 112,6 TWh 84,1 TWh 27,3 GW • NORDEL, ex.NO 76,2 TWh 38,6 TWh 19,1 GW

  11. EUROPEAN Hydro Flexibility – SLIDE II • Ratio between Annual Production/Installed Capacity, i.e. the number of hours necessary to deliver Annual Production • UCTE 1755 h • Norway 4125 h • NORDEL, ex.NO 3980 h • Ratio between Reservoir Capacity/Installed Capacity, i.e. the number of hours necessary to empty the reservoirs without any inflow • UCTE 1160 h • Norway 3080 h • NORDEL, ex.NO 2020 h

  12. NORWEGIAN HYDRO FLEXIBILITY OPTIONS – SLIDE I • Hydro • Installed capacity 28 GW • Can contribute a lot to balancing, regulation, peak and back-up production except for some hours at winter peak load • Example: The existing 1 GW connection to Denmark • Expansion possibilities in Southern Norway 7 - 8 GW • Converting from base load to peak load production by installing additional generators in the existing power stations • Pumped storage • Installed capacity 1 GW • Mainly built for seasonal pumping • Expansion possibilities in Southern Norway 15 - 20 GW • Storage capacity for continuous pumping 120 hours • Using only existing reservoirs both upstream and downstream side 12

  13. NORWEGIAN HYDRO FLEXIBILITY OPTIONS – SLIDE II Norway has alone close to 50 % of the hydro reservoir capacity in Europe To take advantage of this huge flexibility resource it is necessary to connect it to nodes in the wind belt side 13

  14. Power flow • From the wind belt to Norway • High wind generation • Insufficient transmission capacity to the load centres • Low demand • Low, zero or negative prices • From Norway via the wind belt to the load centres on the continent and UK • Low wind generation • The transmission capacity to the load centres are idle • High demand • High prices side 14

  15. ADDITIONAL INFRASTRUCTURE - benefit • The only additional infrastructure needed is the connection between the wind belt and the Norwegian hydro resources • Benefit from interaction between wind and hydro resources • Taking care of excess wind power production otherwise lost • Delivering balancing, reserve, peak and back-up power • Reducing the need for fossil fired reserves both running and ready to start • Reducing emissions side 15

  16. Exchange with norway – example i • Import of excess wind power • 10000 MW in 1500 hours = 15 TWh • Storage in Norwegian reservoirs • 5000 MW reduced ordinary hydro production = 7,5 TWh • 5000 MW pumping, total efficiency factor 0,7 = 5,25 TWh • Export of ”Peak Power” • 10000 MW in 1275 hours = 12,75 TWh • Alternative fossil fired ”Peak Power” • Result: 12,75 TWh saved RES and reduced emissions Page 17

  17. Exchange with norway – example ii • Import of excess wind power • 10000 MW in 1000 hours = 10 TWh • Storage in Norwegian reservoirs • 5000 MW reduced ordinary hydro production = 5,0 TWh • 5000 MW pumping, total efficiency factor 0,7 = 3,5 TWh • Export of ”Peak Power” • 10000 MW in 850 hours = 8,5 TWh • Alternative fossil fired ”Peak Power” • Result: 8,5 TWh saved RES and reduced emissions Page 18

  18. EXISTING NORWEGIAN PUMPED STORAGE Hydro Developments with Pumped Storage Sira-Kvina, Duge power station, seasonal storage: 2x100 MW reversible units Head 215 m Reservoir capacity 1 400 Million m3 Tunnel length approx. 13 km Inaugurated 1978 Ulla-Førre, Saurdal power station, seasonal storage, see also following slides: 4x160 MW, two of them reversible units Head 450 m Reservoir capacity 3 105 Million m3 Inaugurated Page 19

  19. SOME POSSIBLE PROJECTS Expansion Project Tonstad power station Further Expansion Possibilities in Sira-Kvina and several other Norwegian Hydro Power Systems located in South Norway Page 20

  20. SIRA-KVINA MAIN DATA • 7 powerstations - 16 units • Total capacity 1760 MW • Annualproduction ~ 6 TWh • Reservoircapacity 5,6 TWh

  21. RESERVOIRS – POWER STATIONS All Connections Reservoirs - Power Plants are Tunnels All Power Plants are in Caverns All outlets into reservoir or sea Total Head Developed 930/900 m to the sea Sira-Kvinas anlegg Page 22

  22. WATERWAY

  23. EXPANSION PROJECT TONSTAD - SLIDE I Head 430 m Tunnel length 11 km Existing installation 4x160 MW 1x320 MW Expansion 2x480 MW reversible units Page 24

  24. EXPANSION PROJECT TONSTAD - SLIDE II

  25. SIRA-KVINA FURTHER EXPANSION Tonstad power station Additional capacity 960 MW reversible Total capacity then 2880 MW (1920 MW reversible) Solhom power station Existing capacity 200 MW Additional capacity 1000 MW reversible Page 26

  26. Exchange with norway - GERMAN REPORT • 100% erneuerbareStromversorgungbis 2050: • klimaverträglich, sicher, bezahlbar • Vorläufige Fassung vom 5. Mai 2010 Page 27

  27. “Zusammenfassung und Empfehlungen” I Die Ergebnisse der Szenarien für 2050 im Überblick – Das Potenzial an regenerativen Energiequellen reicht aus, um den Strombedarf in Deutschland und Europa vollständig zu decken. – Dabei kann Versorgungssicherheit gewährleistet werden: Zu jeder Stunde des Jahres wird die Nachfrage gedeckt. Voraussetzung ist der Aufbau der entsprechenden Erzeugungskapazitäten und die Schaffung von Möglichkeiten für den Ausgleich zeitlich schwankender Einspeisung von Strom durch entsprechende Speicherkapazitäten. Page 28

  28. “Zusammenfassung und Empfehlungen” II Die Ergebnisse der Szenarien für 2050 im Überblick – Eine vollständig nationale Selbstversorgung ist zwar darstellbar, aber keineswegs empfehlenswert. – Die Kosten der Stromversorgung können durch einen regionalen Verbund mit Dänemark und Norwegen oder einen größeren europäisch-nordafrikanischen Verbund im Vergleich zur nationalen Selbstversorgung erheblich gesenkt werden. Page 29

  29. “Zusammenfassung und Empfehlungen” III Die Ergebnisse der Szenarien für 2050 im Überblick – Eine anspruchsvolle Energiespar- und Effizienzpolitik senkt die ökonomischen und ökologischen Kosten der Versorgung mit erneuerbaren Energien. Page 30

  30. “Zusammenfassung und Empfehlungen” IV Die Ergebnisse der Szenarien für 2050 im Überblick – Der derzeitige Bestand an konventionellen Kraftwerken ist als „Brücke“ hin zu einer regenerativen Stromversorgung ausreichend. Bei einer durchschnittlichen betrieblichen Laufzeit von 35 Jahren kann der Übergang schrittweise gestaltet werden. Hierfür muss der jährliche Zubau an regenerativen Erzeugungskapazitäten bis etwa 2020 in moderatem Umfang weiter gesteigert werden. Page 31

  31. The German Wind Resource and Norwegian Hydro A PERFECT MATCH?

  32. Thank you! Lars Audun Fodstad Direct +47 24 06 74 30 Mobile +47 913 01 785 laf@statkraft.com Statkraft Energy AS Lilleakerveien 6 P.O.Box 200 Lilleaker NO-0216 Oslo, Norway www.statkraft.com

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