1. Conference Call 2th Quarter 2014

2. Highlights  Energy consumption grew by 3.0% between 2Q14 and 2Q13, driven by an 8.0% consumption increase in the residential segment;  Non-technical losses/BT market in the last 12 months stood at 41.9%, 0.5 p.p. down quarter-over- quarter with a drop of 2.3 p.p. year-over-year;  Collections fee in the quarter reached 103.5%, 0.7 p.p. down year-over-year;  Allowance for doubtful accounts (PCLD) of 1.7% of revenue from energy billing in 2Q14, 0.8 p.p. down on PCLD of 2.5% recorded in 2Q13;  DEC e FEC, in the last 12 months, increase 26.21% and 16.91%, respectively, in comparation with the same period of the previous year; OPERATING  Net revenue, excluding construction revenue, grew by 1.4% year-over-year, totaling R$ 1,601.5 million;  Consolidated EBITDA in 2Q14 of R$239.3 million, 13.9% down on 2Q13;  Net income for 2Q14 totaled R$15.3 million, compared to a net income of R$58.2 million in 2Q13;  Consolidated net debt of R$5,229.6 million, 2.1% down on the same quarter last year; FINANCIAL CDE FUNDS  CDE (Energy Development Account) transfer of funds to distribution companies to settle energy purchase commitments with CCEE (Electricity Chamber of Trade);  Amount of R$224.3 million in April and May was recorded in profit or loss as cost reduction with Portion A;  Total transfer of R$1,385 million in the first half, reducing its period tariff deficit to R$250 million, which will be passed on to consumers in the next tariff adjustment through the CVA.

3. Energy Consumption Distribution – Quarter 1 Note: To preserve comparability in the market approved by Aneel in the tariff adjustment process. the billed energy of the free customer CSN has been considered back. TOTAL MARKET (GWh) ¹ Industrial captive 5.3% Free 20.3% Others captives 14.0% Commercial captive 27.6% Residential captive 32.8% 2Q12 2Q11 2Q132Q14 +3.0% 6,304 5,754 23.2ºC 23.1ºC 5,669 6,495 23.5ºC 22.7ºC +4.6%

4. Energy Consumption Distribution – Accumulated 1 Note: To preserve comparability in the market approved by Aneel in the tariff adjustment process. the billed energy of the free customer CSN has been considered back. TOTAL MARKET (GWh) ¹ Industrial captive 5.1% Free 18.6% Others captives 13.6% Commercial captive 27.6% Residential captive 35.2% +5.5% 1H12 1H11 +5.1% 1H131H14 13,145 11,934 25.7ºC 11,960 13,869 25.2ºC 25.1ºC

5. Total Market RESIDENTIAL INDUSTRIAL COMMERCIAL OTHERS TOTAL 2Q132Q14 ELECTRICITY CONSUMPTION (GWh) TOTAL MARKET – QUARTER 2Q132Q14 2Q132Q14 2Q132Q14 2Q132Q14 FREE CAPTIVE 4,954 5,176 6,304 1,349 1,319 +2.3% 893 910 942 49 54 964 +2.8% 1,962 215 224 2,017 1,428 1,085 1,041 1,385 +8.0% 1,972 2,128 -3.0% 1,748 1,793 +3.0% 342344 6,495

6. Total Market RESIDENTIAL INDUSTRIAL COMMERCIAL OTHERS TOTAL 1H131H14 ELECTRICITY CONSUMPTION (GWh) TOTAL MARKET - ACCUMULATED 1H131H14 1H131H14 1H131H14 1H131H14 FREE CAPTIVE 5,176 893 910 1,748 342344 +5.5% 10,526 11,292 13,145 2,618 2,576 13,869 +4.2% 1,806 1,880 1,909 103 109 1,990 5.7% 4,055 430 457 4,284 701705 2,787 2,086 2,010 2,715 +11.1% 4,395 4,880 -2.6% 3,625 3,827

7. Collection PCLD/Gross Revenue (Billed Sales) - Quarter COLLECTION RATE BY SEGMENT Quarter 2Q132Q14 103.5% 104.5% 105.1% 101.8% 102.9% 108.1% Total Retail Large Clients Public Sector 104.2% 97.3% 2Q12 2Q1 4 2Q13 3.4% 2.5% 1.7% -0.8 p.p.

8. Loss Prevention LOSS (12 MONTHS) % Non-technical losses/ LV Market Non-technical losses GWh Technical losses GWh Jun/13 Sep/13Mar/14 Jun/14 Dec/13 INSTALLED METERS (Thousand Units) Communities Without Communities 2010 201120132012 115 Jun/14 43.7% 5,738 2,614 8,552 44.2% 5,972 2,843 8,352 41.9% 5,953 2,629 8,815 5,905 2,647 8,582 - 2.3 p.p. 42.2% 42.4% 5,955 2,793 8,748 351 30 79 102 227 432 272 330 7 122 116 509 197 393

9. Losses Combat Actions APZ Results By June. the program coverd 505 thousand customers in 29 APZs. which ones 22 had the results calculated: -30.0 p.p

10. Net Revenue Industrial (Captive) 5.9% NET REVENUE (R$MN) Generation 7.5% Distribution 80.5%** NET REVENUE BY SEGMENT (2Q14)* Commercialization 12.0% * Eliminations not considered ** Construction revenue not considered NET REVENUE FROM DISTRIBUTION (2Q14) Commercial (Captive) 42.6% Others (Captive) 12.2% Network Use (TUSD) (Free + Concessionaires) 7.8% Residential (Captive) 31.5% Construction Revenue Revenue w/out construction revenue +3.5% 1.580 1.602 378 333 1,755 3,677 2Q14 +1.4% 1H13 3.344 3.720 +11.2% 214 176 1,816 4,098 2Q13 1H14 1,580 1,602 3,344 3,720 +11.5%

11. Operating Costs and Expenses Manageable (distribution): R$ 309 (18.8%) Generation and Commercialization: R$ 249 (15.2%) Non manageable (distribution ** ): R$ 1,084 (66.1%) * Eliminations not considered ** Construction revenue not considered DISTRIBUTION PMSO COSTS (R$MN) COSTS (R$MN)* 2Q14 COSTS (R$MN)* 1H14 Non manageable (distribution ** ): R$ 2,293 (66.0%) Generation and Commercialization: R$ 506 (14.6%) Manageable (distribution): R$ 677 (19.5%) R$ MN2Q132Q14Var.1H131H14Var. PMSO (212.0)(207.1)-2.3%(412.7)(412.3)-0.1% Provisions (66.6)(14.1)-78.8%(111.8)(79.4)-29.0% PCLD(48.4)(36.1)-25.5%(77.4)(61.4)-20.8% Contingencies(18.2)21.9-(34.4)(18.0)-47.5% Depreciation (83.8)(86.2)2.8%(164.5)(171.6)4.3% Other operational/ revenues expenses (5.7)(1.2)-79.5%(12.9)(13.3)2.6% Total (368.0)(308.5)-16.2%(701.9)(676.6)-3.6% 368 309 -16.2% 702 677 1H141H13 -3.6% 2Q142Q13

12. Tarif Deficit 12 Tarif Deficit Balance CDE Fund Total Aporte CDE -1H14 (R$ MN) Decree 8203 (jan/14) SPOT market Involuntary Exposure 1,238 Availability contracts with thermal plants299 Hydrological Risk39 A-1 Auction Contract30 A-0 Auction Contract28 TOTAL1,635 (250) (1,635) 1,385 The remaining balance of R$ 250 millions refers to the portion of items not covered by the decrees, with an emphasis on: availability contracts in January, energy contracted through the A-1 auction, a portion of the energy contracted in the A-0 auction, hydrological risk, revenue from hydrological risk deducted from the January and February transfers and from the cut in the April transfer The exposure to the spot Market and its high prices, which reflect the low levels of hydro plant reservoirs and the dispatch of thermal plants, resulted in an expressive deficit for distributors

13. EBITDA EBITDA BY SEGMENT (R$ MN) Generation and Commercialization Distribution 56.0% 244 -12.5% 279 45.8% 54.2% 37.4% 62.6% 2Q13 2Q14 1H13 1H14 63.3% 36.7% 44.7% +9.9% 636 55.3% 699 Consolidated EBITDA (R$ MN) 2Q142Q13Var.1H141H13Var. Distribution132.3174.5 -24.2% 387.1402.6 -3.9% EBITDA Margin (%) 9.2%12.5%-3.3 p.p.12.2%13.5%-1.3 p.p. Generation88.0100.1 -12.1% 270.8219.4 23.4% EBITDA Margin (%) 66.0%75.9%-9.9 p.p.78.6%79.1%-0.6 p.p. Commercialization23.94.4 449.3% 41.514.3 190.6% EBITDA Margin (%) 11.1%2.8%8.3 p.p.9.2%4.6%4.6 p.p. Others and eliminations (4.9) (1.1) 360.2%(7.1) (3.3) 118.9% Total 239.3277.9-13.9%633.1692.39.3% EBITDA Margins (%) 14.9%17.6%-2.7 p.p.18.9%18.6%-0.3 p.p.

14. EBITDA EBITDA 2Q13 EBITDA 2Q14 Net Revenue Non- Manageable Costs Manageable Costs (PMSO) Provisions Regulatory Assets and Liabilities Adjusted EBITDA 2Q13 Adjusted EBITDA 2Q14 Adjusted EBITDA – 2Q13 / 2Q14 (R$ MN) Other operacional revenues Equity Pikup - 9.4% - 13.9% 397 278 (110) (2) (4) 239 360 119 22 3 52 120

15. EBITDA EBITDA 1H13 EBITDA 1H14 Net Revenue Non- Manageable Costs Manageable Costs (PMSO) Provisions Regulatory Assets and Liabilities Adjusted EBITDA 1H13 Adjusted EBITDA 1H14 Adjusted EBITDA – 1H13 / 1H14 (R$ MN) Other operacional revenues Equity Pikup - 6.9% +9.3% 854 220 633 376 (328) (10)(6) 32 (6) 692 102 794

16. Net Income 2Q13 2Q14 EBITDAFinancial Result TaxesDepreciation ADJUSTED NET INCOME 2Q13 / 2Q14 (R$ MN) Regulatory Assets and Liabilities Adjusted Net Income 2Q13 Adjusted Net Income 2Q14 58 95 - 73.8% -30.8% 137 (39) (16) (3) 15 79 15 79

17. Net Income 1H13 1H14 EBITDAFinancial Result TaxesDepreciation ADJUSTED NET INCOME 1H13 / 1H14 (R$ MN) Regulatory Assets and Liabilities Adjusted Net Income 1H13 Adjusted Net Income 1H14 (16) (3) + 43.1% - 6.8% 282 145 137 59 44 (36) (8) 196 67 263

18. Indebtedness Average Term: 3.9 years AMORTIZATION SCHEDULE* (R$ MN) Nominal Cost Real Cost NET DEBT *ConsideringHedge * Principal only COST OF DEBT 2012 2011 2Q14 2013 Net Debt / EBITDA 2.24% 8.21% 3.87% 10.49% 4.25% 11.03% 9.68% 3.55% TJLP 13.3% CDI 74.5% IPCA 11.0% Others 3.7% U$/Euro -2.7% 408 781 1,031 832 1,166 717 729 476 573 Jun/13 2.90 2.99 Jun/14Mar/14 2.62

19. Investments CAPEX (R$ MN) CAPEX BREAKDOWN (R$ MN) 1H14 Generation 8.4 Administration 12.2 Others 5.0 Develop. of Distribution System 207.5 Losses Combat 119.7 Investments in Electric Assets (Distribution) Commerc./ Energy Eficiency 5.0 519 2010 701 2011 2012 797 694 103 519 182 775 154 713 132 845 +9.5% 2013 327 1H13 1H14 54 26 273 332 358 929

20. 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.

21. Contacts João Batista Zolini Carneiro CFO and IRO Gustavo Werneck Superintendent of Finance and Investor Relations +55 21 2211 2560 gustavo.souza@light.com.br gustavo.souza@light.com.br Mariana da Silva Rocha IR Manager + 55 21 2211 2814 mariana.rocha@light.com.br mariana.rocha@light.com.br ri.light.com.br www.facebook.com/lightritwitter.com/LightRI