: financial report :(26% of total additions; Romania: +65MW; Italy:+40MW; France: +8MW), higher average, loadfactors (+1pp to 24%) and higher average sellingprices (+12% year-on-year to €107/MWh) – 2012EBITDA includes EUR 32 million gain related tothe allocation of PPA in several companies; (2)Spain (+EUR 61 million, including hedging results),reflecting 110MW of new capacity (25% of totaladded), higher average load factors (+1pp to 27%)and higher average selling prices (+6% yearon-yearto €88/MWh); and (2) the United Statesmarket (+EUR 47 million), reflecting +EUR 24million from Forex (8% year-on-year appreciationof the USD versus the EUR ), +215MW of capacity(49% of total additions), a steady 33% averageload factor and an increase of the average sellingprice (+3% year-on-year to USD47/MWh).In United States of America, installed capacityrose 215MW, to 3,637MW in 2012. Output underPPA contracts went up 10% year-on-year,reflecting the contribution of PPAs signed overprevious periods (359MW of merchant capacity:184MW which PPA started in January 2012 and175MW which PPA started in June 2012). Averageselling price (excluding revenues from PTCs) forenergy sold through PPA/Hedged increased 2%year-on-year to USD52/MWh, reflecting the priceescalators annual updates. Average selling pricefor merchant wind farms improved 3% year-onyearto USD31/MWh, reflecting some recoveryin the last few months, but still at very low prices.Overall, average selling price in US increased 3%year-on-year to USD47/MWh in 2012. Note thatin fourth quarter 2012, <strong>EDP</strong> Renováveis concludedthe sale of a 49% equity stake in a 599MW windfarms’ portfolio to Borealis for USD230 million(EUR 176 million). Average load factor remainedstable at 33% in 2012.In Spain, in 2012, <strong>EDP</strong> Renováveis expanded itsportfolio in Spain by 110MW reaching 2.3GW ofinstalled capacity. Average load factor improved1pp year-on-year to 27% in 2012, while electricitygenerated went up by 11% year-on-year to 5.1TWhin 2012. Average selling price for capacityunder the transitory regime reached €88/MWh(excluding hedging results), down 3% year-onyearon lower average achieved pool prices(-6% year-on-year), while average selling pricefor capacity under RD661/2007 was €83/MWh,up 7% year-on-year. Note that in 2012, 88% of thegeneration (4.5TWh) was sold without exposureto market prices, through fixed tariffs (2.3TWh),hedges (2.0TWh) or fixed floor mechanism(0.1TWh), while only 12% (0.6TWh) were sold atmarket prices plus €38.3/MWh premium. Overall,average selling price in Spain, including hedgingresults, rose 6% year-on-year to €88/MWh,following better hedging prices (€52/MWh versus€44/MWh), the strategic decision of choosing thefixed tariff option under RD 661/2007, inflationindexation and lower production sold at marketprices (-26% year-on-year).In Portugal, <strong>EDP</strong> Renováveis has 615MW of windcapacity remunerated under the ‘old tariff regime’,with tariffs set for 15 years and indexed to both CPIand annual operating hours. In September 2012,an extension to this tariff scheme was agreed,under which <strong>EDP</strong> Renováveis will annually investEUR 3.6 million between 2013 and 2020 for anadditional 7 years of a new framework with capand floor selling prices of €98/MWh and €74/MWh,respectively, to be applied from the 16th year ofoperation of the wind farm. In 2012, average loadfactor was stable at 27%, while wind productionincreased 4% year-on-year to 1.4TWh in 2012.Average tariff rose 3% year-on-year to €102/MWh, reflecting inflation indexation, voltage dipsremuneration and the adjustment by working hoursindexation. Still in Portugal, ENEOP consortium<strong>EDP</strong> - <strong>Annual</strong> <strong>Report</strong> 2012(equity consolidated), licensed to build 1,200MWof wind capacity (480MW attributable to <strong>EDP</strong>Renováveis) had an installed capacity of 974MW(390MW attributable to <strong>EDP</strong> Renováveis). Note thatin December 2012, <strong>EDP</strong> Renováveis executed itsfirst minority stake transaction with CTG, sellinga 49% equity stake, and 25% of the shareholdersloans, in its 615MW of wind capacity in operationand in 29MW ready-to-build (all in Portugal), forEUR 359m (cash-in expected in the first half of2013).In European markets out of Iberia, <strong>EDP</strong>Renováveis installed 113MW over the last 12months (including the first 40MW in Italy),increasing its capacity to 951MW as of December2012. Output rose 30% year-on-year to 1.7TWhin 2012, reflecting the new capacity brought onstream, while average load factor improved 1ppto 24% in 2012. Average selling price rose 12%year-on-year to €107/MWh, driven by the strongincrease of prices in Romania (+61% year-on-yearin local currency) and by its higher weight of windproduction (28% versus 18% in 2011).In France, <strong>EDP</strong> Renováveis has 314MW of capacity(+8MW year-on-year). Wind power in France issold through fixed tariffs indexed to inflationfor 15 years. In 2012, average tariff was €89/MWh (+2% year-on-year). In Belgium, our 57MWwind farm sells its power through a 5 year PPA(2014 maturity) at a fixed selling price of €112/MWh. In Italy, <strong>EDP</strong> Renováveis commissioned itsfirst 40MW of wind capacity, which will receive‘market price plus green certificate’ until 2015(green certificate price set at 0.78 x (€180/MWh -previous year average market price); after 2015,it will be absorbed into a ‘pool + premium’ scheme(premium of €180/MWh minus previous yearaverage market price).In Poland, <strong>EDP</strong> Renováveis has 190MW of installedcapacity: (i) 120MW from Margonin wind farm,which power is sold in the wholesale market andfor which <strong>EDP</strong> Renováveis has a 15 years longterm contract for the sale of the green certificates(GCs); and (ii) 70MW from Korsze wind farm,which output is sold through a 10 year PPA. In2012, average selling price was PLN427/MWh,down 5% year-on-year mostly due to lowerwholesale prices in one of the wind farms.In Romania, <strong>EDP</strong> Renováveis has 350MW ofcapacity (+65MW year-on-year), of which 39MWare solar PV. Wind production is sold at ‘marketprice plus green certificate’, which value issubject to a floor and a cap set in Euros (for 2012,floor was set at €28.2/MWh and the cap at €57.4/MWh). In 2012, average selling price was up 61%year-on-year to RON608/MWh, following theimplementation of the 2 green certificates schemeper MWh produced, in place until 2017. Note thatsolar PV energy is entitled to receive, in additionto the electricity price, 6 green certificates perMWh produced in the first 15 years of operation.In Brazil, <strong>EDP</strong> Renováveis has 84MW in operationremunerated through long term contracts (20years). In 2012, average load factor fell 4pp yearon-yearto 31%, given a change in productionmix, as a 70MW wind farm (Tramandaí) startedoperations in May 2011, during one of the bestwind resource season of the year. Average sellingprice went up 3% year-on-year to BRL 286/MWh,on inflation update.<strong>EDP</strong> Energias do Brasil’s contribution toconsolidated EBITDA declined 22% year-onyear,penalised by unfavourable forex impact(-EUR 42 million in the wake of a 7% depreciationof BRL versus EUR) and by a 15% (-BRL 245million) decline in local currency EBITDA.In local currency, EBITDA in distribution declinedby 26%, backed by increasing negative tariffdeviation. EBITDA in generation dropped by 7% in155
: financial report :local currency, due to the negative contributionfrom Pecém’s coal plant following the delay incommercial operation start-up (-BRL 104 million).In electricity distribution in Brazil, EBITDA in2012 dropped 26% year-on-year, penalised bynegative tariff deviations, justifying the -BRL 231million difference between regulated revenuesand gross profit in 2012. EBITDA was alsoaffected by: (i) negative impact from ANEEL’sdirective under which the amounts collectedfrom industrial clients for power demandabove contracted levels must be registeredas investment subsidies and not as operatingrevenues (BRL 46 million in 2011) and (ii) positiveimpact of BRL 102 million from the distributionasset revaluation due to the re-estimation ofthe compensation of distribution concessions inBandeirante and Escelsa (Escelsa’s concessionwill expire in July 2025 and Bandeirante’s inOctober 2028) on the back of the ProvisoryAct No. 579. The Provisory Act No. 579 led tothe decrease of the electricity costs mostly byreducing the sector costs, namely charges onelectricity (pass-through cost for distributors)and also generation costs related to theconcessions’ renewal conditions.Volume of electricity sold rose 3.2% year-onyear,reflecting an increase in the residential,commercial & other segments of 6%, justified bythe increase of 3.6% in the number of clients andalso of the consumption of electricity per capita.On the other hand, the industrial segment partiallycompensated by declining 4.8% due to the lowerindustrial activity in Bandeirante’s area as well asmigration of clients to the free market. Electricitydistributed rose 1.5% in 2012 penalized by lowervolumes of energy distributed to clients in thefree market.Bandeirante’s regulatory review for the period2011-15, was approved in October 2012 byANEEL. The gross Regulated Asset Base wasset at BRL 3,000 million and the net RAB atBRL 1,545 million, both 27% above the figuresin the previous regulatory period. It was alsodefined a 7.29% increase in Bandeirante’s tarifffor the period from October 2012 to October2013 already including the regulatory reviewimpact. The financial adjustment resulting fromthe tariff freezing between October 2011 andOctober 2012, including the non-application ofthe new regulatory methodology, which amountsto BRL 78 million will be returned by Bandeiranteto tariffs in three annual installments with thefirst one included in this tariff readjustment andthe remaining in the following two annual tariffreadjustments. Regarding Escelsa, in August 2012ANEEL set a 14.29% tariff increase for the periodfrom August 2012 to August 2013 on the back ofthe annual tariff readjustment process. Escelsa’snew regulatory period will start in August 2013.EBITDA in our electricity generation activitiesin Brazil went down 7% since the inflationupdate on PPA’s selling price was more thancompensated by the negative contribution fromPécem’s coal plant (-BRL 104 million in 2012)due to the delay of the start of its commercialoperation. The negative impact from hydro plantsenergy purchase in fourth quarter 2012 promptedby the extreme dry weather was offset by theenergy sold in the spot market in first half 2012.Electricity volumes sold increased 13% yearon-yearreflecting the increase of the installedcapacity. Average selling price increased 6%year-on-year in 2012 supported by the updateof prices to inflation. Almost all <strong>EDP</strong> Brasil’sinstalled capacity is contracted under PPA longterm contracts.In December 2012, <strong>EDP</strong> Brasil was awardeda PPA for Cachoeira Caldeirão hydro plant,a 219MW project with an average 129.7 MWcontracted for a 30-year period at a price ofBRL 95.31/MWh. The hydro plant PPA startsin January 2017 and the project will have anexpected investment of BRL 1.1 billion andestimated leverage of 60%.The trading and supply activity in Brazilis carried out by our <strong>EDP</strong> Comercializadorasubsidiary in the free market essentially througha service of energy sourcing to large industrialclients without incurring in material energymarket risk. In 2012, gross profit in supplydeclined BRL 19 million as the 14% increase ofvolumes were more than compensated by lowerunit margins due to higher costs of energypurchased.<strong>EDP</strong> Group’s net controllable operating costs(supply and services, personnel costs, costs withsocial benefits and other operating costs (net))rose 7.1% (+EUR 119 million), to EUR 1,800 millionin 2012, driven by a EUR 64 million increasein operating costs and a EUR 55 million rise inother net operating costs. Operating costs roseby 4%, to EUR 1,600 million backed by: (i) +3%in Iberia, prompted by higher costs related toclients’switching to the free market, as part ofthe liberalisation process, and by an increase ofrestructuring costs, (ii) +13% at <strong>EDP</strong> Renováveisbacked by larger scale of operations and Foreximpact (USD appreciation); and (iii) a 1% fall inBrazil supported by favourable forex impact.Financial results totalled -EUR 705 millionin 2012, mainly driven by a 7% rise in averagenet debt coupled with lower average cost of debt(-10bp to 4.0%); lower impairment on our financialstake at BCP (EUR 58 million in 2011 and EUR5 million in 2012) and lower provisions due toa litigation process with a client in Brazil(EUR 22 million in 2011).Consolidated capex totalled EUR 2,011 millionin 2012, standing 7% below 2011. Expansion capexwas 6% lower year-on-year, backed by lowerexpansion in wind & solar (-27% year-on-year)and higher capex in liberalised activities (newhydro in Portugal) and Brazil (new hydro andcoal capacity). Maintenance capex was 8% loweryear-on-year, at EUR 692m mostly reflectingthe completion of DeNOx facilities at our Sinescoal plant in 2011. In 2012, hydro & wind capacityabsorbed 88% of expansion capex.5.1.3. CAPEX – <strong>EDP</strong> GROUPEUR Million 2012 2011 ∆ % ∆ Abs.Long-Term Contracted Generation Iberia 44.1 58.9 -25% -15Liberalised Activities Iberia 524.2 465.4 13% +59Regulated Networks Iberia 403.6 404.8 -0% -1Wind Power 606.5 828.7 -27% -222Brazil 388.4 341.2 14% +47Other 43.8 61.7 -29% -18<strong>EDP</strong> Group 2,010.7 2,160.6 -7% -150Expansion Capex 1,318,6 1,408.2 -6% -90Maintenance Capex 691.9 752.4 -8% -60156A World Full Of Energy
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