The French feed-in tariffs to support electricity from renewable
Transcription
The French feed-in tariffs to support electricity from renewable
2nd Workshop of the International Feed-in Cooperation The French feed-in tariffs to support electricity from renewable energy sources Christophe Lesieur In charge of Energy questions French Ministry of ecology and sustainable development Dε 4 1 Summary I. II. III. IV. Presentation of the supply in France Method for the determination of tariffs Lessons from the feed-in system The new « Energy Law » Dε 4 2 Supply for electricity Dε 4 Power at the end of 2004 installed GW Net Supply at the end of 2004 In TWh 3 RES for electricity, except hydro Dε 4 Power from renewables, except hydro (Gwh/y) 4 The French Programmation Pluriannual Programmation for electric investments (2005) For France: increase from 15 % to 21 % (including large hydro: 66 TWh) - Requires a minimum increase of 40 TWh/year of new RE (excluding large hydro) - Requires a minimum of 10 GW of wind power in 2010 (versus 0.5 GW in 2004) - Wind power should contribute to 73 % of new renewable energy increase (81% of new RE power increase) Dε 4 Source: Pluriannual Programmation for electric investments (2005) 5 The French system to support electricity from renewable energy sources < 12 MW: feed-in tariffs > 12 MW: calls for tender Dε 4 6 The "Profitability Index" (PI) method • Profitability index PI = Net Present Value / Investment • Gives both kWh manufacturing cost and selling price: Tariff T = ((1 + PI)Kd + Kom) Iu / Nh + Cvu (Euro/kWh) – CRF = Capital recovery factor (based on actual discount rate = t = AWCC = Average Weighted Cost of Capital, and n): CRF= t / (1-(1+t)^-n) – Kom = O&M ratio = yearly O&M expenses / Investment (wind: Kom = 0.04) – Iu = investment cost ratio = I / P (EURO/kW) – Nh = Ey / P = kWh / kW = number of hours per year at rated power – Cvu : variable cost (fuel cost part: Cvu = Fuel Cost / (Efficiency.LHV) If PI=0, Tariff =ODC (Overall Discounted Cost), Margin = 0 • Direct link PI <==> IRR or DPBT (disc. PB time) Dε 4 CRF (IRR, n) = (1+PI).CRF (t, n) CRF (t, DPBT) = (1+PI).CRF (t, n) 7 Links PI / IRR for n = 15 years Ex: t = 6 %: 100 % PI variation from 0.15 à 0.3 : IRR vary only from 8 to 10.3 % TR I = f(TEC , t) pour n = 1 5 ans 30 t = 15 % 25 12 % 10 % TRI (%) 20 15 5 % 10 1% 0 % 5 Dε 4 0 0 0 ,1 0 ,2 0,3 0,4 0,5 0,6 0 ,7 T E C = VA N /I 8 Method (2) Universal linear model PI = f(Tariff T) • PI = aT - b = (Nh / CRF.Iu)(T - Cvu) - (1 + Kom / Kd) • where Iu = I / P, Nh = Ea / P, Kom = Dom / I, CRF = t / (1 - (1+t)exp-n) • Cvu = part of cost due to the fuel (Zero for wind/solar/hydro systems) • Com = part of the cost due to O&M costs = Kom.Iu / Nh • Ci = part of the cost due to the investment cost = CRF.Iu / Nh • From Thales of Milet: PI = {(T-Cost)/Cost} / (ci/Cost) PI Golden rule: PI > 0.3 Dε 4 Margin On Cost (MOC) /% inv. In cost PIr Cvu Com Cost -1 -(1+Kom/CRF) Ci Tr Tariff T M 9 Method (3) • Margin on cost, MOC MOC =(Price-Cost)/Cost • MOC of Fossil versus Renewable Energy Sources - Introducing Kfuel • Kfuel = cost per kWh without fuel cost / cost per kWh • Kfuel = 1,0 for Wind; 0,5 for Coal; 0,33 for CCGT • MOC =PI*Kfuel*(Kd/(Kd+Kom)) At equal kWh cost, if PI Renewables = PI Fossil, then: MOCR / MOCF > 1 / KFUELF Dε 4 A Renewable energy investment commands a higher margin to reach the same profitability than a Fossil energy investment !! 10 Method (4) • The « zero fuel cost RETs paradox » (wind, hydro, solar, geothermal based power plants) : - (MOCwind / MOCfossil) = (cost / non fuel cost part)fossil - MOC wind = 2 times MOC coal = 3 times MOC nat. gas ! - Minimum 10 % MOC from coal plants ==> PI = 0,3 •Implies minimum PI value of 0.3 for wind projects (project IRR = 10% for t = 6 % and n = 15 years) Wind: 120 Dε 4 Coal: 110 Nat.gas: Different selling prices for the same profitability (PI = 0.3) 106 100 Fuel cost part Non-Fuel cost part Same kWh cost 11 Example 1: comparing coal & CHP from biomass Differences: costs: 1.7 c€/kWh Tariffs 2,6 c€ (+50%) Efficient Tariffs 6,8 c€ versus 4,2 (+62%) Tariffs Chp G: 8.7 to 10.2 c€ DK: bonus 1.3 to 4.6 cE/kWhe Sp: 3 cE/kWhe Différentiel d e rentab ilité c entrales à c harb o n et c o génératio n ex-b io m as s e (p aille, DK, 1999, 6 M we) TEC = VAN/ I 1,0 0,5 C harb o n Dε 4 C o gen p aille 0,0 0,03 0,04 0,05 0,06 0,07 0,08 T Ve (Euro /kW he) 12 Example 2: “Advanced tariffs” for Wind Power Taking into account return of experience and context: - Competitive calls for tenders • Not enough efficient for new French Wind Energy goals: 10 GW • Feb. 2000 French electric law: the only solution for projects > 12 MW - Green certificates: not proven, not sufficient for 5 to 11 GW - “Fixed Tariffs”: past and ongoing successes (Dk, G, Sp...) Basis: fair profitability for private investors: - Minimum profitability for strong market growth, including on low quality sites largely available (from Nh = 2 000 h/y) - No undue profits on high quality sites: tariffs adapted to potential energy yields - Simple system, easy to define, to control and to adapt - Not state aid: charging the cost on all electricity consumers Dε 4 13 Principles for Tariffs Definition and Calculation Two successive tariffs levels (F: only for P < 12 MW): T1 fixed for all projects from years 1 to 5 (= German idea !) T2 variable for projects from years 6 to 15 (diff. From Ger.) T1 and T2 define a constant “equivalent tariff”, Teq Ref. Nhmin : PI=PImin => Teqmax=T2max =>T1= T2max Ref. Nhmax : PI = PImax > PImin => T2min For a specific project (P < 12 MW): Nh from average values years 1 to 5 T2: linear calculation Teq from (T1, T2, t) Tariffs PI from Teq, Nh, Iu Reference values: T1 Teq Iu=1067 EURO/kW Kom = 4%, t=6.5% Dε 4 T2 5 15 Years 14 Results: June 8th 2001 Arrêté, 2001 Tariffs 2001 Rates(Mainland France, P < 1500 MW ) Reference values for 2001 tariffs T1 Mainland France, projects < 12 MW cEURO / kWh T1 T2 Teq 8,38 8,38 8,38 8,38 3,05 5,41 Corsica & Overseas Depart. projects <12 MW P (MW) P (MW) Nh: <1500 >1500 Nhmin: 2050 cEURO / kWh T1 T2 Teq 9,15 9,15 9,15 Nhint: Nhmax: 9,15 9,15 2400 3300 Hypothesis for Teq: Real discount rate t = 6.5% n = 15 years Dε 4 7,47 4,57 8,21 6,59 6 5,41 5,95 5 4 3,05 3 2 1 0 3600 3300 3400 3600 7,02 3200 Nhmax: 8,38 7 3000 7,02 2800 5,95 2600 8,38 2400 2400 2200 2600 8,38 8 2000 Nhint: Teq 9 1800 P (MW) >1500 1900 cEUR / kWh . P (MW) Nh: <1500 Nhmin: 2000 T2 Nh (hours/year at rated power) 15 Results: June 8th 2001 Arrêté, 2001 Tariffs Dε 4 Filière arrêtés (*) Durée des contrats Biomass 16 avril 2002 15 years 4,9 c€/kWh (32,1 cF/kWh) + prime à l’efficacité énergétique comprise entre 0 et de 1,2 c€/kWh (7,8 cF/kWh) Methanisation 16 avril 2002 15 years 4,6 c€/kWh (30,2 cF/kWh) + prime à l’efficacité énergétique comprise entre 0 et 1,2 c€/kWh (7,8 cF/kWh) Geothermie 13 mars 2002 15 years 7,62 c€/kWh (50 cF/kWh) + prime à l’efficacité énergétique comprise entre 0 et 0,3 c€/kWh (2 cF/kWh) PV 13 mars 2002 20 years 15,25 c€/kWh en France continentale et 30,5 en Corse et Dom (1F/kWh et 2F/kWh) Animal wastes 13 mars 2002 15 years 4,5 à 5 c€/kWh (29,5 à 32,8 cF/kWh) énergétique comprise entre 0 et 0,3 c€/kWh Small installations 13 mars 2002 15 years 7,87 à 9,60 c€/kWh (51,6 à 63 cF/kWh)issu du tarif « bleu » aux clients domestiques Biogaz 3 octobr e 2001 15 years 4,5 à 5,72 c€/kWh (29,5 à 37,5 cF/kWh)selon la puissance + prime à l’efficacité énergétique comprise entre 0 et 0,3 c€/kWh (2 cF/kWh) Domestic waste 2 octobr e 2001 15 years 4,5 à 5 c€/kWh (29,5 à 32,8 cF/kWh) + prime à l’efficacité énergétique comprise entre 0 et 0,3 c€/kWh (2 cF/kWh) CHP 31 juillet 2001 12 years 6,1 à 9,15 c€/kWh (40 et 60 cF/kWh) environ en fonction du prix du gaz, de la durée de fonctionnement et de la puissance Small hydraulic 25 juin 2001 20 years 5,49 à 6,1 c€/kWh (36 à 40 cF/kWh) selon la puissance + prime comprise entre 0 et 1,52 c€/kWh (10 cF/kWh)en hiver selon régularité de la production Wind on-shore 8 juin 2001 15 years 8,38 c€/kWh (55 cF/kWh) pendant 5 ans, puis 3,05 à 8,38 c€/kWh (20 à 55 cF/kWh) pendant 10 ans selon les sites Fourchette de tarifs pour les nouvelles installations (métropole) 16 Source: DGEMP-Dideme. Februar 2005. Lessons from French Tariffs Dε 4 Price ranges (average to maximum support) for direct support of wind onshore in EU-15 Member States (average tariffs are indicative) compared to the long-term marginal generation costs (minimum to average costs). Support schemes are normalised to 15 years. Average effectiveness indicator Wind on-shore 17 Lessons from French Tariffs Dε 4 Effectiveness indicator for wind onshore electricity in the period 1998-2004. The relevant policy schemes during this period are shown in different colour codes. 18 Lessons from French Tariffs Administrative barriers Æ Large number of authorities involved and lack of coordination between them Æ Long lead times needed to obtain necessary permits Æ RES insufficiently taken into account in spatial planning 12 MW threshold Æ Many projects were cut “sheating” on Nh on years 1-5 was profitable! Æ Some installations was volontary stopped during the first years Dε 4 19 The energy Law (13th july 2005) FEED- IN TARIFF = APC + BONUS • APC = avoided private costs 2. Bonus = contribution to the 4 objectives of the energy law: The energy Law suppress the threshold of 12 MW Dε 4 20 The energy Law (13th july 2005) 1. Avoided private costs = avoided investment costs + avoided exploitation costs We must take into account: • structure of the supply: - In what measure wind energy (or solar energy) susbstitute to nuclear plant, gaz plant? What are the possible cost of gaz in mid term? Intermittence and lack of predictability: - Dε 4 In what measure wind energy (or solar energy)permit to avoid investments in installation supplying the peak period- load? Æ Cost of intermittence = [2 €/MWh – 4 €/MWh] 21 The energy Law (13th july 2005) Bonus = contribution to the 4 objectives of the energy law: - Independance External costs of Energy Low costs of energy ExternE - NEEDS Environnement Social cohesion and energy for all We must quantify these elements! Dε 4 22 Conclusions • Defining a fair and efficient tariff system is possible - Taking into account other “success stories” (Dk, G, Sp) - Within a deregulated electricity market ("advanced tariffs") • The Profitability Index Method gives: - A rational basis for minimum values of profitability - Simple formulas to define, monitor, adapt the tariff system • Lessons from France - Administrative barriers - threshold of 12 MW Dε 4 23