1. Conference Call 1 st Quarter 2013

2. Highlights  6.9% increase in Net Revenue (without construction revenue) reaching R$ 1,883.1 million in the 1Q13;  R$ 355,1 million EBITDA in 1Q13, wich represents a 18.1% decrease, as a consequence of the higher cost with energy purchase for distribution;  R$ 78.6 million of net Income in the first quarter, a decrease of 43.8% over 1Q12. Adjusted by CVA, it reaches R$ 145.4 million, 4.8% above 1Q12.  Net Debt of R$ 4,031.4 million, with a multiple for covenants at 2,73x.  CDE transfers to the distributors to neutralize, since January/2013, the exposure to the spot market, the hydrological risk and the additional cost from thermal power plants dispatch;  R$ 428 million were recognized as a reversal of non-manageable costs (Parcel A), whereas R$ 171 million were received in April and R$ 257 million in May, regarding the 1Q13 accountings. RESULTS Decree 7,945/13  Consumption grew 3.7% compared to 1Q12, manly driven by the residential and commercial segments whch increased its consumption by 3.2% and 7.8%;  Collection rate (LTM) for the first quarter reached 101.0%, 600 bps above the 1Q12;  Non-tecnical losses for the past 12 months was of 44,9%, a reduction of 50 bps in comparison with december/2012;  In 1Q13, investments amounted R$162.7 million, been R$ 127.0 million for the distribution segment. OPERATIONAL

3. Energy Consumption Distribution – Quarter +3.7% 6,180 6,291 26.9ºC 27.0ºC 1Q12 1Q11 6,087 6,407 1Q10 27.8ºC 28.3ºC +1.8% 1Q13 1 Note: To preserve comparability in the market approved by Aneel in the tariff adjustment process, the billed energy of the free customers Valesul, CSN and CSA were excluded in view of these customers’ planned migration to the Basic Network. TOTAL MARKET (GWh) ¹ Industrial 5% Free 19% Others 13% Commercial 28% Residential 35% With the consumption no longer billed by the change in criteria, the total energy consumption increase in the concession area would be 5.3% over 1Q12.

4. Total Market RESIDENTIAL INDUSTRIAL COMMERCIAL OTHERS TOTAL 1Q121Q13 ELECTRICITY CONSUMPTION (GWh) TOTAL MARKET – QUARTER 1Q121Q13 1Q121Q13 1Q121Q13 1Q121Q13 FREE CAPTIVE +3.7% 5.379 5.572 6,180 801 835 6,407 +3.7% 882 913 932 49 53 966 +7.8% 1.748 1.877 1,939 191 214 2,091 401 359 962 561 568 927 +3.2% 2,348 2,423 -3.7% 1,748 1,877

5. Collection 97.2% COLLECTION RATE 12 MONTHS COLLECTION RATE BY SEGMENT QUARTER 95.0% 101.0% 100.2% 92.0% 99.2% 104.7% 100.6% 1Q121Q13 97.7% 99.5% Mar/12Mar/13 TotalRetailLarge ClientsPublic Sector

6. Loss Prevention INCORPORATION GWh 1Q13 1Q12 36.9 19.7 +87.3% ENERGY RECOVERY GWh 1Q13 1Q12 23.9 7.2 LOSS (12 MONTHS) 42.2% 41.2% 32.9% % Non-technical losses/ LV Market Non-technical losses GWh Technical losses GWh % Non-technical losses / LV Market - Regulatory 5,457 2,381 7,665 7,838 44.9% +231.9% Mar/13Jun/12Mar/12 2,349 5,316 43.1% 6,007 2,577 8,584 Sep/12 5,615 2,432 8,047 Dec/12 45.4% 6,029 2,618 8,647

7. Losses Control Initiatives Results until March/13 Average losses reduction: 23.0 p.p. Average Collection increase: 14.5 p.p. Average losses reduction : 49.5 p.p. Average Collection increase : 80.4 p.p. Favelas Zero Losses Area (APZ)

8. Net Revenue Industrial 5.5% NET REVENUE (R$MN) Generation 7.1% Distribution 84.0%** NET REVENUE BY SEGMENT (1Q13)* Commercialization 8.6% * Eliminations not considered ** Construction revenue not considered NET REVENUE FROM DISTRIBUTION (1Q13) Commercial 29.7% Others (Captive) 11.7% Network Use (TUSD) (Free + Concessionaires) 8.0% Residential 45.1% Construction Revenue Revenue w/out construction revenue +7.5 1,898.7 2,040.0 1Q131Q12 157,3 1,761.3 1,883.1 137,4 +6,9%

9. Operating Costs and Expenses Manageable (distribution): R$ 317.1 (17.8%) Generation and Commercialization: R$ 203.5 (11.4%) Non manageable (distribution): R$ 1,261.2 (70.8%) * Eliminations not considered ** Construction revenue not considered DISTRIBUTION MANAGEABLE COSTS (R$MN) COSTS (R$MN)* 1Q13 333.1 317.1 -4.8% 1Q13 1Q12 R$ MN1Q121Q13Var. PMSO167.6184.09.7% Provisions86.545.2-47.7% PCLD61.629.0210.2% Contingencies24.916.2554.9% Depreciation75.780.66.5% Other operational/ revenues expenses 3.27.3127.3% Total333.1317.1-4.8%

10. EBITDA CONSOLIDATED EBITDA (R$MN) EBITDA BY SEGMENT* 1Q13 Generation 33.4% (EBITDA Margin: 82.1%) Commercialization 2.8% (EBITDA Margin: 5.6%) Distribution 63.8% (EBITDA Margin: 13.5%) *Eliminations not considered 355.1 433.4 -18.1% 1Q121Q13

11. EBITDA EBITDA 1Q12 EBITDA 1Q13 Net Revenue Non- Manageable Costs Manageable Costs (PMSO) Provisions Regulatory Assets and Liabilities Adjusted EBITDA 1Q12 Adjusted EBITDA 1Q13 EBITDA – 1Q12 / 1Q13 (R$ MN) Other operational/ revenues (2) 433 122 (175) (19) (7) (1) 101 456 + 5.8% - 18.1% 42 355 431 Equity Pick-up

12. Net Income 1Q12 1Q13 EBITDAFinancial Result TaxesOthers ADJUESTED NET INCOME 1Q12 / 1Q13 (R$ MN) Regulatory Assets and Liabilities Adjusted Net Income 1Q12 Adjusted Net Income 1Q13 139 (1) 140 (78) (9) 30 (4) 79 67 145 - 43.8% + 4.8%

13. Indebtedness Average Term: 4.7 years AMORTIZATION SCHEDULE* (R$ MN) Nominal Cost Real Cost NET DEBT Without Pension Fund *ConsideringHedge * Principal only COST OF DEBT 2012 2011 2010 Mar/13 Net Debt / EBITDA Mar/13Dec/12 2.24% 8.21% 4.87% 11.08% 4.25% 11.03% 7.73% 1.07% US$/Euro 16.2% CDI/Selic 57.5% TJLP 24.3% Others 2.0% 357 792 759 982 616 394 176 42 194 3,991.9 1 4,031.4 2.83 2.73 1 Reclassified to reflect the deconsolidation results of jointly controlled companies.

14. Investments CAPEX (R$ MN) CAPEX BREAKDOWN (R$ MN) 1Q13 Generation Projects 26.9 Quality Improvement 13.4 Generation Maintenance 3.1 Others 17.2 Develop. of Distribution System 51.6 Losses Combat 44.7 Investments in Electric Assets (Distribution) Commerc./ Energy Eficiency 26.1 2010 2009 563.8 928.6 700.6 2011 2012 796.8 694.1 102.7 446.9 116.9 518.8 181.8 774.8 153.8 1Q13 1Q12 131.2 127.0 11.7 35.8 142.9 162.7 +13.9%

15. On March 8, 2013, the federal government issued the Decree 7,945 preventing the coverage of part of the non-manageable costs not covered by the 2013 tariff, through the resources transferred from the Energetic Development Accout (CDE) for the following costs:  System Service Charge (ESS) – The monthly transfer will be determined by the amounts settled in the CCEE.  Involuntary Exposure associated with the quotas – The monthly CDE transfer will cover the difference between the difference settlement price (PLD) and the tariff of the repositioning amount recognized in Light’s last tariff adjustment.  Hydrological Risk - The net monthly amount settled in the CCEE will be transferred directly via the CDE. It is worth mentioning that the amounts approved for Light reflect the methodology approved by Aneel on May 6 th, 2013. Regulatory Framework CDE transfer 1Q13 without Decree 1Q13 1Q12 362.2 144.9 267.1 371.0 225.7 291.9 70.4 144.9 267.1 371.0 225.7 27.2 122.8 235.4 362.1 70.7 1,370.9 1,079.9 818.2 ENERGY PURCHASE (R$ MN) Availability Contracts Other Auctions Norte Fluminense Itaipu Spot CDE transfer 1Q13 Without Decree 1Q13 1Q12 ESSTransport Other Charges 215.3 52.8 46.1 79.0 52.8 46.1 23.5 130.9 49.5 136.3 314.2 177.9 203.9 CHARGES AND TRANSPORT (R$ MN) + 31.9% -12.8%

16. 2013 Tariff Review Schedule DateEvent July 11 Aneel forwards first proposal (without remuneration and depreciation) to the concessionary and to the consumers representatives August 01Internet presentation of the Tariff Review Porposal prepared by Aneel From Jul/28 to Aug/16Regulatory Asset Base fiscalization September 05Public Hearing October 03Aneel forwards new proposal consolidated to the concessionary and to the consumers representatives October 24Aneel Board Meeting November 07Periodic Tariff Review Date

17. Important Notice This presentation may include declarations that represent forward-looking statements according to Brazilian regulations and international movable values. These declarations are based on certain assumptions and analyses made by the Company in accordance with its experience, the economic environment, market conditions and future events expected, many of which are out of the Company’s control. Important factors that can lead to significant differences between the real results and the future declarations of expectations on events or business-oriented results include the Company’s strategy, the Brazilian and international economic conditions, technology, financial strategy, developments of the public service industry, hydrological conditions, conditions of the financial market, uncertainty regarding the results of its future operations, plain, goals, expectations and intentions, among others. Because of these factors, the Company’s actual results may significantly differ from those indicated or implicit in the declarations of expectations on events or future results. The information and opinions herein do not have to be understood as recommendation to potential investors, and no investment decision must be based on the veracity, the updated or completeness of this information or opinions. None of the Company’s assessors or parts related to them or its representatives will have any responsibility for any losses that can elapse from the use or the contents of this presentation. This material includes declarations on future events submitted to risks and uncertainties, which are based on current expectations and projections on future events and trends that can affect the Company’s businesses. These declarations include projections of economic growth and demand and supply of energy, in addition to information on competitive position, regulatory environment, potential growth opportunities and other subjects. Various factors can adversely affect the estimates and assumptions on which these declarations are based on.

18. Contacts João Batista Zolini Carneiro CFO and IRO Luiz Felipe Negreiros de Sá Superintendent of Finance and Investor Relations +55 21 2211 2814 felipe.sa@light.com.br felipe.sa@light.com.br Gustavo Werneck IR Manager + 55 21 2211 2560 gustavo.souza@light.com.br gustavo.souza@light.com.br www.light.com.br/ri www.facebook.com/lightritwitter.com/LightRI