Corporate PresentationJanuary 2013

100% 100% 100%100% 100% 100%51% 100% 51% 20%

Light Energia

S.A.

Light Serviços de Eletricidade

S.A.

Light Esco Prestação de Serviços S.A.

Lightcom Comercializadorade Energia S.A.

Itaocara Energia

Ltda.

Light Soluções emEletricidade

Ltda.

InstitutoLight

LightgerS.A.

AxxiomSoluções

TecnológicasS.A.

CR Zongshen E-Power

Fabricadora de Veículos Ltda.

Renova Energia S.A.

Light S.A.(Holding)

25.5%

AmazôniaEnergia

S.A.

EBL Cia de

Eficiência Energética

S.A

Distribution Generation Commercialization and Service System Electric Vehicles

Institutional

Light Holdings

Norte Energia S.A.

2

Central Eólica

Fontainha Ltda.

Central Eólica

São Judas Tadeu Ltda.

100% 100%21.99% 33%9.77%

Guanhães Energia S.A.

100%51%

33

IntegratedNet Revenues 2011 – R$ Billion

DistributionEnergy Consumption in Concession Area (2011) - GWh1

Generation Private-owned CompaniesInstalled Hydro-generation Capacity (MW) – 2011

Rankings

Souce: Companies reportsNote: 1 – Captive market + free clients

2 – It doesn’t consider the consumption of CSN and CSA

Among the largest players in Brazil

CPFL Cemig Eletropaulo Neoenergia Copel LightCemig CPFL Neoenergia Copel Light Energias do Brasil

54.590

50.404

45.101

29.13925.593

22.932

15.8

12.8

9.8

7.8

6.25.4

Tractebel AES Tiete Duke Energy CPFL Energias do Brasil

Light

6.908

2.6542.241 2.210

1.828

866

2

CEMIG RME LEPSA BNDESPAR MARKET

FIP LUCE

PARATI

CEMIGFIP REDENTOR

REDENTORENERGIA

26.06% 13.03% 13.03% 13.46% 34.41%

100%

75% 25%

13.03% 13.03%100%

96.80%

6.41%19.23%

BTGPACTUAL

SANTANDER

VOTORANTIM

BANCO DO BRASIL

28.57%

5.50%

28.57%

5.50%

28.57%5.50%

14.29%

2.74%

MINORITYSHAREHOLDERS

3.20% 0.42%

Free Float 47.9%

100%

25.64%*

FOREIGN NATIONAL

57.02% 42.98%

Percentage in blue: indirect stake in Light*12.61% (RME) + 13.03%(LEPSA)

Light S.A.(Holding)

Controlling Shareholders 52.1%

Shareholders Structure

11 Board members: 8 from the controlling group, 2 independents e 1 employees nominated

A qualifying quorum of 7 members to approve relevant proposals such as: M&A and dividend policy

Indirect stake in blue

4

5

Corporate Governance

General Assembly

Fiscal Council

Board of Directors

AuditorsCommittee

Governance and Sustainability

Committee

Human Resources Committee

Finances Committee

Management Committee

Chief Executive Officer

Chief HR Officer

Chief Business Officer

Corporate Management

OfficerChief Legal Officer

Chief Financial and Investor

Relations Officer

Chief Distribution Officer

Chief Energy Officer

João B. Zolini Carneiro José Humberto Castro Evandro L. Vasconcelos Andreia Ribeiro Junqueira

Fernando Antônio F.Reis Paulo Carvalho Filho Evandro L. Vasconcelos*

Paulo Roberto R. Pinto

Chief Communications

OfficerLuiz Otavio Ziza Valadares

LGSXYADR-OTC

Interim*

66

Distribution Business

• 4.0 million clients (serving 10 million people)• Energy sales (2011) – 22.932 GWh • 70% of the consumption of Rio de Janeiro state (Brazil’s 2nd GDP)

6th largest energy distribution company in Brazil (2011)

LIGHT

ELECTRICITY CONSUMPTION¹TOTAL MARKET (GWh) - Quarter

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.

Energy Consumption

Distribution

7

RESIDENTIAL33%

INDUSTRIAL 7%OTHERS15%

FREE15%

COMMERCIAL30%

3T09 3T10 3T11 3T12

+3.5%

5.2995.144

21.7ºC

22.4ºC

3Q113Q10

4.9895.486

3Q09

22.1ºC21.7º

C

+3.2%

3Q123T09 3T10 3T11 3T12

Série1

3T11 3T12 3T11 3T12 3T11 3T12 3T11 3T12 3T11 3T12

Total Market

ELECTRICITY CONSUMPTION (GWh) TOTAL MARKET – 3rd QUARTER

FREECAPTIVE

RESIDENTIAL INDUSTRIAL COMMERCIAL OTHERS TOTAL

3Q11 3Q12 3Q11 3Q12 3Q11 3Q12 3Q11 3Q12 3Q11 3Q12

+3.5%

4.5594.645

5.299

740 840

5.486

+4.6%

810 847

85445 47

894

+13.3%

1.4401.627

1.595155

180

1.807+1.7%

427 370

968

541 614

984

-4.3%

1.882 1.801

8

99

Prospects for State of Rio

Investments of R$ 211.5 billion in the State of Rio de Janeiro¹ Period 2012-2014

¹Source: Firjan (Industry Federation of Rio de Janeiro)

OilR$ 107.7 bn50.9%

TourismR$ 1.8 bn0.9% Others

R$ 1.9 bn0.9%

Olimpic FacilitiesR$ 8.6 bn4.1%

InfrastructureR$ 51.0 bn24.1%

Transformation IndustryR$ 40.5 bn19.1%

10

Rio de Janeiro

Economic activity leading to more demand

-Maracanã (ND)-Porto Maravilha (ND)-Morar Carioca (ND)-Aeroporto Tom Jobim (5MW)-Estaleiro Inhauma (ND)-Atento (2MW)-Expansão Nova América (4MW)-Expansão Norteshopping (3MW)

- Petrobras (15MW)-CSN (100MW)-Gerdau (30MW)- Usiminas (20MW)-LLX (40MW)-Base Naval(25MW)-Hotel Comfort (3MW)

-Gerdau (90MW)-Shop.CampoGde(3MW)- Rolls Royce (3MW)

-Nestlé (3MW)

-Bio Manguinhos (ND)-Hermes (3MW)-Votorantin (ND)-Ongoing (ND)-Bunge (ND)-AMBEV (2MW)-GE (6MW)-Shop. Metropolitano (10MW)

- RHI (5MW)-Lavazza (3MW)-Ajebras (5MW)

- Reluz (ND)-Embelleze (5MW)

-MRS (ND)

-AMBEV (ND)-NeoBus (10MW)

-Coquepar (42MW)-Procter & Gamble (10MW)-Alpargatas (ND)

The State of Rio de Janeiro will attract $ 250 billion as investments by 2016 ¹

¹Source: Associação Brasileira de Municípios – ABM website.

Centro Tecnológico Fundão (ND)

-Shopping Village Mall (7MW)- Edifício Tishman Speyer (5MW)- Expansão Via Parque (2MW)- Casa Granado (3.5MW)- Hospital São Lucas (4MW)- Metrô Ipanema (8MW)- Flow Serve (11MW)- Alog Data Center (12MW)

Collection

11

COLLECTION RATE12 MONTHS

COLLECTION RATE BY SEGMENTQUARTER

3Q11

3Q12

PUBLIC SECTORLARGE CLIENTSTOTAL RETAIL

97.7% 97.8%

96.3%93.0%

102.2%

99.7%

106.2% 99.8%

97.2% 98.3%

Sep/11 Sep/12Total Varejo Grandes

ClientesPoder Público

3T11 3T12

set-11 set-12set/09' set/10'

Loss prevention

12

Reflects exclusion of long term delinquent customers from the billing system, according to Resolution 414 by Aneel.

Non Technical Losses Distribution (5.615 GWh)

1

2

1 2 1 2Risky Area Non-Risky Area

37%63%

LOSS (12 MONTHS)

jun/11 set/11 dez/11 mar/12 jun/12

Technical losses GWh

% Non-technical losses/ LV Market % Non-technical

losses / LV Market - Regulatory

Sep/11

Non-technical losses GWh

Dec/11 Jun/12Mar/12 Sep/12

42.2%

40.7%

41.2% 33.8%

5.316

2.328 2.349

5.229

7.5827.627 7.665

40.4%

2.335

5.247

43.1%

5.615

2.432

8.047

5.457

2.381

7.839

13

Loss prevention

33.8%

Technical losses GWh

% Non-technical losses/ LV Market % Non-technical

losses / LV Market - Regulatory

Non-technical losses GWh

42,5% 42,7% 42,4%42,1% 41,8% 41,6% 41,3%

40,7% 40,4%

41,2%

42,2%

43,1%

Perdas NT/BT %

Reflects exclusion of long term delinquent customers from the billing system, according to Resolution 414 by Aneel.

Sep/11 Dec/11 Jun/12Mar/12 Sep/12Sep/10 Dec/10 Jun/11Mar/11Jun/10Mar/10

42.2%40.7

%41.2

%40.4%

43.1%42.7%

42.4% 42.1

%41.8

%41.6

%41.3

%

mar/10 jun/10 set/10 dez/10 mar/11 jun/11 set/11 dez/11 mar/12 jun/12 set/12

5,316

2,328 2,349

5,229

7,5827,627 7,665

2,335

5,247 5,615

2,432

8,047

5,457

2,381

7,838

5,330

2,191 2,214

5,313

2,197

5,352 5,312

2,231

5,278

2,215

5,326

2,293

7.5497.504 7.544 7,5437.493 7,619

LOSS (12 MONTHS)

14

33.8%

Technical losses GWh

% Non-technical losses/ LV Market % Non-technical losses /

LV Market -Regulatory

Non-technical losses GWh42 ,5% 42 ,7% 42,4 %

42 ,1% 41, 8% 41,6%41,3%

40,7% 40 ,4%

4 1, 2%

42, 2%

43 ,1%

Pe rdas NT/ BT %

Reflects exclusion of long termdelinquent customers from thebilling system, according toResolution 414 by Aneel.

Sep/11 Dec/11 Jun/12Mar/12 Sep/12Sep/10 Dec/10 Jun/11Mar/11Jun/10Mar/10

42.2%40.7% 41.2%

40.4%

43.1%42.7% 42.4% 42.1% 41.8% 41.6% 41.3%

mar/10 jun/10 set/10 dez/10 mar/11 jun/11 set/11 dez/11 mar/12 jun/12 set/12

5,316

2,328 2,349

5,229

7,5827,627 7,665

2,335

5,247 5,615

2,432

8,047

5,457

2,381

7,838

5,330

2,191 2,214

5,313

2,197

5,352 5,312

2,231

5,278

2,215

5,326

2,293

7.5497.504 7.544 7,5437.493 7,619

Loss prevention

Non Technical Losses Distribution(5.615 GWh)

1

2

1 2

1 2

RiskyArea Non-RiskyArea

37%63%

LOSS (12 MONTHS)

15

New Technology Program

Technology used in regions in which conventional measures are not effective Areas that present high levels of non-technical losses

Light aims to reduce losses through investments in new technologies, integration of operational activities, increase of public awareness and institutional partnerships with interested agents.

Grid shielding projects

Actual grid Shielded grid

Control room

3 m

9 m

Low voltage

Mechanical Meter

Medium voltage

Display

Low voltage

Medium voltage

Centralized meter

2010 2011 2012

16

New Technology Program

Monitoring, reading, cutting and reconnection of customers telemetry– MCC (Measuring Center Centralized)

Prioritization in areas of high losses and aggressiveness to the network

Technology hindering inappropriate interference in networks

Meters Installed (Thousands)

(ITRON) (LANDIS GYR. CAM and ELSTER)

CENTRALIZEDINDIVIDUAL

72

38

11038

38

2010 2011 Sep /12

208

283

170

245

17

Losses (before): 26%Losses (current): 7%

New Technology Results - Individual

1818

New Technology Results - Centralized

Losses (before): 48%Losses (current): 14%

19

Area: Nova Cidade Neighborhood - Nilópolis

Zero Losses Area

FEATURES LV MV TOTAL

CLIENTS 10,083 3 10,086

NETWORK (KM.) 50 23 73

TRANSFORMER (QTY.) 107

POWER (MVA) 12,9

RESULTS 2010 2011

COLLECTION (R$ MN) 8.9 10.3NON-TECHNICAL LOSSES 41.7% ¹ 7.4% ²¹ Nov/10

² DeC/11

20

Program Gains – An example

300 kWh

100 kWh

REAL CONSUMPTION

BILLED CONSUMPTION

NEW METER INSTALLATION

200 kWhLOST ENERGY

ENERGY SAVED

100 kWh

BILLED CONSUMPTION INCREASE100 kWh

OTHER EFFECTS (BY-PRODUCTS):

CAPEX GOES TO THE RAB

BAD DEBT PROVISION REDUCTION

OPERATIONAL COSTS

REDUCTION

21

Transformation of risky areas

22

Pacified Communities

Batan

Cidade de Deus

S. Marta

Mang.e Babil.

Tabaj. e Cabr.

Alemão

Formiga

Andaraí

Macacos

Salgueiro

Cantag. e Pavãoz.

Borel e Casabranca

64.7 thousand clients inside pacified

communities with new meters and network

Santa Marta Before After

Clients 73 1.605

Losses 90% 6%

Delinquency 70% 2%

Generation Business

24

Installed Capacity

HPP Santa Branca 56 MW

HPP Ilha dos Pombos 187 MW

HPP Fontes Nova 132 MW

HPP Underground Nilo Peçanha - 380 MW

HPP Pereira Passos100 MW

SP

RJ

HPP Santa Branca

Paraiba do Sul River

HPP Ilha dos Pombos

Installed Capacity 868 MW

100%

100%

100%100%100%

Lajes Complex

51%

SHP Paracambi 13 MW

25

Re-pricing of existing energy

Contracted Energy (Regulated)² Contracted Energy (Free) HedgeAvailable Energy

2012 2013 2014 2015 2016 2017 2018 2019 2020 2021

475

122

53

340

304 282 251 243 238 228 228 228

52

206 228 259 267 272 282 282 282

25 25 25 25 25 25 25 25 25 25553 539 535 535 535 535 535 535 535 535

Energia contratada (ACR) Energia contratada (ACL) Recursos disponíveis para comercialização HedgeAverage sale price to free

market (R$/MWh)¹

128 135 148 151 155 157 157 157 157 157

Conventional Energy Balance Assured energy (MW average)

¹Database january. 2012² Average price to Regulated Market (dec/11): R$ 75/MWh

26

SP

RJ

Paraiba do Sul River

Lajes Complex

SHP LajesInstalled Capacity: 17 MWThe construction is to be started by the 2nd half of 2012. Operational Start: 2nd half of 2014; Installation License already issued.

HPP ItaocaraInstalled Capacity: 151 MWThe construction is to be started by the end of 2012.Commercial Operational Start: 2nd half of 2015. Preliminary License already issued.

Generation Expansion

RR Participações(1)

8.5%

BNDESPAR 12.1%

InfraBrasil 15.2%

Santander3.0%

FIP Caixa Ambiental

7.1%

FIP Santa Barbara

6.1%Outros;

4.0%

27(1) Share of RR Participacoes SA out of the control block

By the middle of 2011, Light signed an investment agreement of $360 million and the PPA (Power Purchased Agreement) of 400MW of installed capacity to have 25.9% stake at Renova. This year BNDESPAR is becoming a shareholder after a capital increase in Renova. Light keeps a 21.99% stake.

Light21.99%

RR Participações

21.99%

Controlling Shareholders64.6% CS

Light 32.3% CS 0% PS

RR Participações 32.3% CS0% PS

Shareholder Structure December 2012

LocationWind Farms

Inventory (SHPs)

Basic Projects (SHPs)

Auctions Performance The biggest winner in the Reserver Energy

Auction of 2009 The biggest winner in the Reserver Energy

Auction of 2010 2nd largest winner in the Auction A-3 of 2011

Company’s Portfolio 41.8 MW of SHPs in operation under the

PROINFA contract 294.4 MW of wind energy under construction to

start the operation in Jul/2012 808.3 MW of contracted wind energy to be

delivered between 2013 until 2017 Pipeline 5.8 GW under development Projects in the same area providing synergies and

scale gains

Renova

28

Renova – Contracts

* Does not considered the network basic losses.

Contract Sites Term(years) Index

Operation

Startup (Estimat

ed)

Installed

Capacity

(MW)

Average Load Factor

(%)

Estimated Energy

(MW average)

CAPEX/MW install

ed (R$ MN)

LoanTariff(R$/MW)

SHPP 3 20 IGPM

In operation

since 2008

41.8 61.3 24.2 4.901 BNB Contracted 182.06

LER 2009 14 20 IPCA

In operation

since Jul 2012

293.6 50.8 148.9 (*) 3.996 BNDES Contracted 160.65

LER 2010 6 20 IPCA Sep – 2013 162.0 52.7 86.8 (*) 3.878 BNDES

Eligibility 130.76

Y-3 2011 919 years and 10 months

IPCA Mar - 2014 212.8 50.5 108.1 (*) 3.245 BNDES

Eligibility 100.91

Y-5 2012 1 20 IPCA Jan – 2017 22.4 - - - - 90.07

PPA Light 1 10 (E) 20 IPCA Sep - 2015 200.0 50.5(E) 100 (E) 3.245 - -

PPA Light 2 10 (E) 20 IPCA Sep - 2016 200.0 50.5 (E) 100 (E) 3.245 - -

29

Belo Monte Overview

51.0% CS 0.0% PS

49.0% CS100.0% PS

Amazônia Energia Participações S.A

Norte Energia S.A (Belo Monte)

9.77%

74.5% of total stock 25.5% of total stock

Technical data on the concession: Concession period – 35 years End of concession – August 25, 2045

Technical data on the project: Installed capacity - 11.233 MW

– Main engine room – 11.000 MW

– Auxiliary engine room – 233 MW Assured Energy (Average MW) – 4.571 MW Reservoir – 516 Km² Flooded area/generation ratio of 0.05 Km²/MW 5.000 families affected Estimated project cost (April 2010) – R$ 25.8 billion

Other Informations: Amazônia Energia will own 9.77% of the enterprise.

– Construction works estimated to take 9 years.

– Transaction does not affect Light ‘s dividend flow BNDES loan ensures leverage at low cost on favorable terms.

– Tender 30 years, fixed installments. 85% of items financiable. PSI line. Amazônia Energia’s equity in the project estimated at R$ 150 million (Apr.

2010), to be disbursed over 6 years. Expansion of generation portfolio:

– Increases Light’s total generation portfolio by 280 MW Terms for sale of electricity generated already set.

− Regulated Market: 70%; Free Market: 20%; Self-producers: 10%.

Public sector

49,98%Others privates30,25%

Amazônia Energia9,77%

Self prod.10,00%

Norte Energia S.A. – Shareholders Profile

30

Guanhães

TOTAL CAPEXR$ Million

PCH Dores de

Guanhães Senhora do

Pôrto Jacaré Fortuna II TotalInstalled Capacity (MW) 14 12 9 9 44Assured Energy(MWaverage) 8 6.77 5.15 5.11 25.03

ANEEL Authorization 11/22/2002 10/08/2002 10/29/2002 12/21/2001

Operation - Start up Dec/13 Dec/13 Feb/14 Oct/13

Authorization Term 30 years (with renewal for 20 years)

269.2

60.2

57.8

151.2

Equity

Debt

Light Energia

Cemig GT

BNDES

Installed Capacity

(+) SHP Paracambi

(+) Renova current capacity

(+) Lajes (+) Itaocara (+) Renova (+) Belo Monte

(+) Guanhães

Capacity After

Expansion

Expansão da Geração (MW)

Installed Capacity (MW)

Installed Capacity

Capacity After Expansion

Investments in Renova. Belo Monte and Guanhães. in line with our strategy of growing in the generation business

¹ Considering 51% stake² Considering 21.9% stake³ Considering 2.5% stake

New Generation Projects

31

+ 59.3%

(+) Belo Monte³

SHPParacambi¹

SHPLajes¹

HPPItaocara¹ (+) Guanhães¹ (+) Renova²

1.500

13 74* 977

171

280

855

(+) Renova²Current

Capacity

* 9 MW SHP + 65 MW Wind Farm (since jul/12)

942

22

Results

2T11 2T12 1S11 1S12

33

Net Revenue

NET REVENUE (R$MM)

NET REVENUE BY SEGMENT (3Q12)*

NET REVENUE FROM DISTRIBUTION (3Q12)

Commercial 30.1%

Industrial 7.6%

Others (Captive) 13.1%

Network Use (TUSD) 10.3%(Free + Concessionaires)

Residential 38.9%

Construction RevenueRevenue w/out construction revenue

+5.5%

1.657.1

1.748.0

3Q123Q11

170.3

1.426.5

1.577.7

230.6

+6.2%

9M129M11

4.572.8

4.980.2

470.0556.9

5.129.7

5.450.2

10.6%

8.9%

Generation 6.8%

Distribution 87.9%**

Comercialization 5.3%

* Eliminations not considered** Construction revenue not considered

Operating Costs and Expenses

34

Manageable (distribution): R$ 300.2(21.0%)

Generation and Commercialization: R$ 127.4(8.9%)

Non manageable (distribution): R$ 1.003.1(70.1%)

* Eliminations not considered

DISTRIBUTION MANAGEABLE COSTS (R$MN)

COSTS (R$MN)*3Q12

Não gerenciáveis;

1.053,0; 71,18%Gerenciáveis; 321,8; 21,75%

Geração e Comercialização; 104,5; 7,07%

2T12

R$ MN 3Q11 3Q12 Var % 9M11 9M12 Var %

PMSO 149.0 178.5 19.8% 496.9 516.0 3.8%

Provisions 83.0 52.3 -36.9% 242.6 222.9 -8.1%

PCLD 72.2 39.3 -45.5% 216.0 173.2 -19.8%

Contingencies 10.8 13.0 20.4% 26.6 49.7 87.1%

Depreciation 80.6 69.3 -14.0% 234.5 212.9 -9.2%

Total 312.5 300.2 -4.0% 974.0 951.8 -2.3%

2T11 2T12 1S11 1S12

312.5 300.2

-4.0%

3Q123Q11 9M129M11

974.0 951.8

-2.3%

EBITDA

35

CONSOLIDATED EBITDA (R$MN) EBITDA BY SEGMENT*3Q12

Generation 29.5%

(EBITDA Margin: 72.1%)

Commercialization 2.6% (EBITDA Margin: 8.1%)

Distribution 67.9%

(EBITDA Margin: 12.9%)

*Eliminations not considered

Distribuição ; 166,2; 63,68%

Geração; 87,2; 33,41%

Comercialização; 7,6; 2,91%

2T12

2T11 2T12 1S11 1S12

269.5239.8

+12.4%

3Q11 3Q12 9M11 9M12

959.1915.5

+4.8%

36

EBITDA – 9M11/9M12(R$ MN)

EBITDA

EBITDA Ajustado -

2T11

Ativos e Passivos

Regulatórios

EBITDA -2T11

Receita Líquida

Custos Não Gerenciáveis

Custos Gerenciáveis

(PMSO)

Provisões EBITDA -2T12

Ativos e Passivos

Regulatórios

EBITDA Ajustado -

2T12EBITDA 9M11

EBITDA 9M12

Net Revenu

e

Non-Managable

Costs

Managable Costs

(PMSO)

Provisions

Regulatory Assets and Liabilities

Adjusted EBITDA 9M11

Adjusted EBITDA 9M12

+18.9%

+4.8%

Regulatory Assets and Liabilities

971 916 959

1.154

55

407

(350) (34)

20194

LL Ajustado -9M12

Ativos e passivos

Regulatórios

9M11 EBITDA Resultado Financeiro

I mpostos Outros 9M12 Ativos e passivos

Regulatórios

LL Ajustado -9M12

Lucro Líquido - 1S11/ 1S12 R$ Milhões

Net Income

37

NET INCOME – 9M11/9M12(R$ MN)

9M11 9M12EBITDA

Financial Result

Taxes Others

Adjusted Net Income9M11

Regulatory

Assets and

Liabilities

Regulatory

Assets and

Liabilities

Adjusted Net Income9M12

246 36 210

44

(34)

11 33 264

128 392

+59.2%

+25.7%

2007 2008 2009 2010 2011 9M12

Payout

Dividend Yield

2008 2009 2010 2011 2012

38

PAYOUT AND DIVIDEND POLICY

Dividends (R$ MN) Dividend Yield*

DIVIDENDS AND DIVIDEND YIELD

• Based on the closing price of the day before the announcement • Based on Net Income of the year. before IFRS adjustments

Interest on Equity (R$ MN)

100% 100%

76.3%

2007 2008 2009*

Payout

50%

2010

81.0%

Dividend Policy

2011

100%

Note: Profit Reserve existing in the Balance of 12/31/2011: R$ 163 million.

2008 2009 2010 2011 2012

554 595

795

556

87

12.4% 11.6%9.5%

16.2%

8.7%

469

87

Dividends

439

9M12

97.2%

2008 2009 2010 2011 2012

352

2007 2008 2009 2010 2011 9M12

Payout

2008 2009 2010 2011 mar/12

39

Indebtedness leverage

¹ Net debt = total debt (excludes pension fund liabilities) – cash

Net Debt¹ (R$ MM) and Net Debt / EBITDA

Net Debt Net Debt/ EBITDA

InvestmentGrade(brA)

1.580

2008

1.637

2009

1.947

2010

1.1 1.2 1.2

2011

3.383

2.7

Rating(brA + )

Rating(Aa2.br)

Rating(AA-(bra))

Dec/11

Sep/12

2.8

2008 2009 2010 2011 2012

DL/EBITDA

3.622

Indebtedness

40

Average Term: 3.7 years

AMORTIZATION SCHEDULE* (R$ MN)

Nominal CostReal Cost

NET DEBT

2007 2008 2009 set/10

Custo Real Custo Nominal

2007 2008 2009 set/10

Custo Real Custo Nominal

* Principal only

COST OF DEBT

2009 2010 2011 jun/12

Custo Nominal Custo Real

2011201020092007 2008 2009 set/10

Custo Real Custo Nominal

3.09%

8.54%

5.30%

9.84%

4.87%

11.08%

4.51%

11.01%

Sep/12

jan/11 jan/123T09 3T10 9M09 9M10

Net Debt / EBITDA

3.143.53.621.6

2.5 2.8

Sep/12Sep/11 2012 2013 2014 2015 2016 Após 20162012 2013 2014 2015 2016 After 2016

198

582832

754855

1.477

2012 2013 2014 2015 2016 Após 2016

1T12

* Considering Hedge

CDI/Selic 74.2%

TJLP 23.5%

Others 2.0%

US$/Euro 0.4%*

Investments

41

CAPEX BREAKDOWN (R$MN)9M12

CAPEX (R$MN)

2008 2009 2010 2011 9M11 9M12

Investments in Electric Assets (Distribution)

+32.5%

20102009

563.8546.7

928.6

700.6

2011 9M129M11

527.8592.7

-10.9%

507.6

85.1

482.0

45.8

453.8

92.9

446.9

116.9

518.8

181.8 758.7

169.9

2008 Losses Combat156.4

Quality Improveme

nt97.9

Develop. of Distribution System

200.7

Others59.6

Generation Maintenanc

e11.5Generation

Projects1.7

4242

Major upcoming events Integration of favelas Pro-business environment New plants investments Expansion of the existing

ones Market growth

Economic Transformation

in the Concession Area

Progress in the Technology Program

New network and meters in the pacified favelas

Smart metering development “Zero Losses Area” Program

Energy Losses

Reduction

Investment in Renova. Belo Monte and Guanhães (total of 548 MW)

SHP Paracambi Operational Start

SHP Lajes under construction.

Growth in the Generation Business

New PPAs starting in 2013 and 2014

Revenues increase with no aditional costs.

Very active trading subsidiary

Repricing of Existing Energy

Listed in “Novo Mercado” of Bovespa;

Board Committees very active

Included in the Sustainability Index (ISE) of Bovespa for the fifth year.

Best-in-Class Corporate

Governance

Sound Dividend Policy: minimum 50% of net income;

Average payout over last five years: 91%

Dividend track Record

Why Invest in Light?

43

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.

Important Notice

44

Contacts

João Batista Zolini CarneiroCFO and IRO

Gustavo WerneckIR Manager

+ 55 21 2211 2560gustavo.souza@light.com.br

www.light.com.br/ri