Corporate Presentation

April 2013

Light Holdings

Light S.A. (Holding)

100% 51% 20%100% 100% 100%100% 100%51% 25.5%100%

Light Serviços de Eletricidade

S.A.

LightgerS.A.

ItaocaraEnergia

Ltda.

Amazônia Energia S.A.

Light EscoPrestação de Serviços S.A.

LightcomComercializadora

de Energia S.A.

Light Soluções em Eletricidade

Ltda.

Instituto Light

AxxiomSoluções

Tecnológicas S.A.

CR ZongshenE-Power

Fabricadora de Veículos S.A.

GuanhãesEnergia

S.A.

21.99%

Renova Energia

S.A.

Central Eólica Fontainha

Ltda.

100%

Central Eólica São Judas

Tadeu Ltda.

100% 9.77%

Norte Energia

S.A.

33%EBL Cia de Eficiência Energética

S.A.

Light Energia S.A.

Distribution Generation Commercialization and Services Institutional Systems ElectricVehicles

51%

2

Tractebel AES Tiete Duke CPFL EDP Light

Cemig CPFL Neoenergia Copel Light EDP Eletropaulo Cemig Copel CPFL Paulista

Light Celesc

RankingsAmong the largest players in Brazil

INTEGRATED²Net Revenues 2012 – R$ Billion

GENERATION PRIVATE-OWNED COMPANIES²Installed Hydro-generation Capacity (MW) – 2012

37,626

24,71422,737

21,467 20,05415,018

18.5

15.0

11.8

8.56.9

6.6

5,560

2,658 2,241 2,2192,012

877

DISTRIBUTION¹Energy Consumption in Concession Area (GWh) - 2012

1 – Source: Captive market 2 – Source: Companies reports* Considers the 9 MW of Renova’s SHPs

*3

Shareholders Structure

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%

96.81% 100%

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%

MINORITY

3.19% 0.42%

Free Float 47,9%

25.64%*

FOREIGN NATIONAL

57.78% 42.22%

Percentage in blue: indirect stake in Light

Light S.A.

(Holding)

Controller Group 52,1%

*12.61% (RME) + 13.03%(LEPSA)

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

4

Corporate Governance

General AssemblyGeneral Assembly

Fiscal CouncilFiscal Council

Board of DirectorsBoard of Directors

AuditorsCommitteeAuditors

Committee

Governance and Sustainability

Committee

Governance and Sustainability

Committee

Human Resources Committee

Human Resources Committee

Finances CommitteeFinances

CommitteeManagement Committee

Management Committee

Chief Executive Officer

Chief Executive Officer

Chief HR OfficerChief HR Officer

Chief Business Officer

Chief Business Officer

Corporate Management

Officer

Corporate Management

OfficerChief Legal OfficerChief Legal Officer

Chief Financial and Investor

Relations Officer

Chief Financial and Investor

Relations Officer

Chief Distribution Officer

Chief Distribution Officer

Chief Energy 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

Officer

Chief Communications

Officer

Luiz Otavio Ziza Valadares

LGSXYADR-OTC

Interim*

5

Distribution Business

4.1 million clients (serving 10 million people) Energy sales (2012) – 23,384 GWh 70% of the consumption of Rio de Janeiro state (Brazil’s 2nd GDP)

6th largest energy distribution company in Brazil (2011)

LIGHT

6

2009 2010 2011 2012

15,5

17,5

19,5

21,5

23,5

25,5

27,5

2009 2010 2011 2012

2009

2010

2011

2012

+2.0%

22,932

22,384

24.0ºC

24.3ºC

20112010

21,492

23,384

2009

24.5ºC25.0º

C

+2.9%

2012

1Note: 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

Energy Consumption Distribution – Year

Industrial

7%

Residencial

35%Comercial

29%

Outros Cativos

15%

Livre

14%

Industrial7%

Free14%

Others15%

Commercial29%

Residential35%

With the consumption no longer billed by the change in criteria, the total energy consumption increase in the concession area would be 3.0% over 2011.

7

2011 20122011 2012 2011 2012 2011 2012 2011 2012

Total Market

FREECAPTIVE

RESIDENTIAL INDUSTRIAL COMMERCIAL OTHERS TOTAL

2011 2012

+2.0%

19,87720,05

4

22,932

3,056 3,330

23,384

+3.0%

3,417 3,521

3,603

185 191

3,712

+9.1%

6,3106,856

6,967

657743

7,599

1,731

1,528

3,944

2,213

2,396

3,925

-3.2%

8,418 8,149

ELECTRICITY CONSUMPTION (GWh)

TOTAL MARKET – YEAR

2011 2012 2011 2012 2011 2012 2011 2012

-0.5%

8

Prospects for State of RioInvestments of R$ 211.5 billion in the State of Rio de Janeiro¹

OilR$ 107.7 bn

50.9%

TourismR$ 1.8 bn

0.9%

OthersR$ 1.9 bn

0.9%

Olimpic FacilitiesR$ 8.6 bn

4.1%

InfrastructureR$ 51.0 bn

24.1%

Transformation IndustryR$ 40.5 bn19.1%

Period 2012-2014

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

Events Schedule

Confederations Cup

World Youth Day

World Cup

Olympics

Paralympics

Jun, 15 to 30/2013

Jul, 23 to 28/2013

Jun, 12 to Jul, 13/2014

Aug, 5 to 21/2016

Sep, 7 to 18/2016

9

Economic activity leading to more demand

Rio de Janeiro

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. Campo Grande (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)

10

Total Varejo Grandes Clientes Poder Público

2011 2012

Collection rate by segment

102.5%

YEAR

97.4% 98.0%

96.4%94.3%

101.0%

98.8%

102.6%

2011 2012

Total Retail Large Clients

Public Sector

11

40695 40787 40878 40969 41061 41153 41244

Losses12 months

33.3%

Technical losses GWh

% Non-technical losses/ LV Market

% Non-technical losses / LV Market - Regulatory

Non-technical losses GWh

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/10 Dec/12

42.2%40.7

%

41.2%40.4

%

43.1%

45.4%

42.4%

42.1%

41.8%

41.6%

41.3%

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

2,5292,214

6,097

2,197

5,352 5,312

2,231

5,278

2,215

5,326

2,293

7,5498,626

7,544 7,5437,493 7,619

37% Risky Area

63% Non-Risky Area

12

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

13

2010 2011 2012

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 2012

208

341

170

303

2010 2011 2012

14

New Technology ResultsIndividual

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

15

New Technology Results

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

Centralized

16

Zero Losses AreaArea: Nova Cidade Neighborhood - Nilópolis

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 10.3

Non-technical losses 41.7%¹ 7.4%²

¹ Nov/10² Dec/11

17

Losses Reduction - Business CaseAn example

300 kWh

100 kWh

REAL CONSUMPTION

BILLED CONSUMPTION

NEW METER INSTALLATIO

N

200 kWhLOST ENERGY

ENERGY SAVED

100 kWh

BILLED CONSUMPTION INCREASE

100 kWh

OTHER EFFECTS (BY-PRODUCTS):

CAPEX GOES TO THE RAB

BAD DEBT PROVISION REDUCTION

OPERATIONAL COSTS

REDUCTION

18

Transformation of risky areas

19

Tabaj. e Cabr.

Borel e Casabranca

Transformation of risky areas

Batan

Cidade de Deus

S. Marta

Mang.e Babil.

Alemão

Formiga

Andaraí

Macacos

Salgueiro

Cantag. e Pavãoz.

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%

20

GENERATION BUSINESS

Installed Capacity868 MW

HPP Santa Branca

56 MW

HPP Ilha dos Pombos 187 MW

HPP Fontes Nova

132 MWHPP Underground

Nilo Peçanha - 380 MWHPP Pereira Passos

100 MW

SP

RJ

HPP Santa Branca

Paraiba do Sul River

HPP Ilha dos Pombos100%

100%

100%100%100%

Lajes Complex

51%

SHP Paracambi

13 MW

22

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)¹128 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

23

Generation Expansion

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.

SP

RJ

Paraiba do Sul River

Lajes Complex

24

Renova

(1) Share of RR Participações 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

Location

Wind 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

RR Participações21.99%

Light21.99%

RR Participações (1) 8.5%

BNDESPAR12.1%

InfraBrasil15.2%

Santander3.0%

FIP Caixa Ambiental7.1%

FIP Santa Barbara6.1% Others

4.0%

25

Renova - Contracts

Contract SitesTerm

(years)Index

Operation Startup

(Estimated)

Installed

Capacity

(MW)

Average Load

Factor (%)

Estimated Energy (MW

average)

CAPEX

/MW installe

d (R$ MN)

LoanTariff(R$/MW)

SHPP 3 20 IGPM

In operation

since 2008

41.8 61.3 24.2 4.901BNB

Contracted182.06

LER 2009 14 20 IPCA

In operation

since Jul 2012

293.6 50.8 148.9 (*) 3.996BNDES

Contracted160.65

LER 2010 6 20 IPCASep – 2013

162.0 52.7 86.8 (*) 3.878BNDES Eligibility

130.76

Y-3 2011 919 years and 10 months

IPCAMar - 2014

212.8 50.5 108.1 (*) 3.245BNDES Eligibility

100.91

Y-5 2012 1 20 IPCAJan – 2017

22.4 - - - - 90.07

PPA Light 1 10 (E) 20 IPCASep - 2015

200.0 50.5(E) 100 (E) 3.245 - -

PPA Light 2 10 (E) 20 IPCASep - 2016

200.0 50.5 (E) 100 (E) 3.245 - -

26

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%.

Norte Energia S.A. – Shareholders Profile

Public sector49.98%

Others privates30.25%

Amazônia Energia9.77%

Self Prod.10.00%

27

1

GuanhãesTOTAL CAPEX

R$ Million

PCH Dores de

Guanhães Senhora do

Porto Jacaré Fortuna II Total

Installed Capacity (MW)

14 12 9 9 44

Assured 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

28

Capacidade Light

Energia

(+) PCH Paracambi

(+) Renova Capacidade Atual

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

(+) Guanhães

Capacidade após

expansão

Expansão da Geração (MW)

New Generation Projects

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% stake

² Considering 21.9% stake

³ Considering 2.5% stake

+ 59.8%

(+) Belo Monte³

(+) SHPParacambi¹

(+) SHPLajes¹

(+) HPPItaocara¹ (+) Guanhães¹ (+) Renova²

1,505

1374* 9 77

175

280

855

(+) Renova²Current

Capacity

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

942

22

29

RESULTS

Net Revenue

Industrial 6.8%

NET REVENUE (R$MN)

Generation 6.3% Distribution

89.6%**

NET REVENUE BY SEGMENT (2012)*

Commercialization 4.1%

* Eliminations not considered

** Construction revenue not considered

NET REVENUE FROM DISTRIBUTION (2012)

Commercial 30.1%

Others (Captive) 12.6%

Network Use (TUSD)(Free + Concessionaires) 9.4%

Residential 41.1%

Construction RevenueRevenue w/out construction revenue

4T11 4T12 2011 2012

+19.2

1,815.1

2,162.9

4Q124Q11

199.3

1,577.3

1,963.6

237.8

+9.6%

20122011

6,150.1

6,943.8

669.3794.7

6,944.8

7,613.1

24.5%

12.9%

31

4T11 4T12 2011 2012

Operating Costs and Expenses

Manageable (distribution): R$ 1,103.4(18.5%)

Generation and Commercialization: R$

445.1(7.5%)

Non manageable (distribution): R$ 4,410.8(74.0%)

* Eliminations not considered

** Construction revenue not considered

DISTRIBUTION MANAGEABLE COSTS (R$MN)COSTS (R$MN)*2012

279.7

149.1

-46.7%

4Q124Q11 20122011

1,258.9 1,103.4

-12.4%

R$ MN 4Q11 4Q12 Var. 2011 2012 Var.

PMSO 149.6 176.0 17.6% 646.8 692.0 7.0%

Provisions 56,8 250.2 340.8% 299.4 473.1 58.0%

PCLD 35.3 109.4 210.2% 251.3 282.6 12.5%

Contingencies 21.5 140.8 554.9% 48.1 190.5 296.0%

Depreciation 72.3 80.4 11.1% 306.8 293.3 -4.4%

Other operational/revenues expenses

1.0 (357.5) - 6.0 (355.0) -

Total 279.7 149.1 -46.7% 1,258.9 1,103.4 -12.4% 32

4T12

EBITDA

CONSOLIDATED EBITDA (R$MN) EBITDA BY SEGMENT*2012

Generation 23.0% (EBITDA Margin: 76.4%)

Commercialization 1.9%

(EBITDA Margin: 9.5%)

Distribution 75.2%(EBITDA Margin: 17.4%)

*Eliminations not considered

Distribuição ;

1.127,4; 75,59%

Geração; 336,4; 22,55%

Comercialização;

27,8; 1,86%

4T11 4T12 2011 2012

483.9323.6

+49.5%

4Q11 4Q12 2011 2012

1,456.2

1,237.8

+17.7%

33

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 -

2T12

EBITDA

871,3251,238

794

(706) (75)

3811,456

325 1,782

EBITDA – 2011 / 2012(R$ MN)

+ 34.5%

+ 17.7%

(175)

EBITDA2011

EBITDA2012

Net Revenu

e

Non-Managable

Costs

Managable Costs

(PMSO)

Provisions

Regulatory Assets and Liabilities

Regulatory Assets and Liabilities

Adjusted EBITDA

2011

Adjusted EBITDA

2012

Other operational/

revenues

34

LL Ajustado - 2011

Ativos e passivos

Regulatórios

2011 EBITDA Resultado Financeiro

Impostos Outros 2012 Ativos e passivos

Regulatórios

LL Ajustado - 2012

Lucro Líquido e Lucro Líquido Ajustado 2011/2012 - R$ Milhões

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 -

2T12

Net Income

ADJUESTED NET INCOME 2011 / 2012 (R$ MN)

+ 24.0%

399 58342

218

(85)(57)

6 424

215 639

+ 59.9%

2011 2012EBITDA

Financial Result

Taxes OthersRegulatory Assets and Liabilities

Regulatory Assets and Liabilities

Adjusted Net Income

2011

Adjusted Net Income

2012

35

Dividends

2007 2008 2009 2010 2011 2012

100% 100%

76.3% 81.0%

100.0%

86.5%

50%

Minimum Dividend PolicyPayout

1S08 2S08 1S09 2S09 1S10 2S10 1S11 2S11 1S12 2S12 1S13

203

351408

187

432363 351

118182 170

92

8787

4.2%

8.2%9.9%

1.7%

8.1% 8.1%6.1%

3.4% 3.3%5.4%

2.4%

Dividend Yeld*Dividends

*Based on the closing price the day before the announcement.

Interest on Equity

257

182205

351363

432

187

408351

203

92

*Based on Net Income of the year. before IFRS adjustments

*

36

2008 2009 2010 2011 2012

Indebtedness leverage

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

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

2012

2.9

4,273

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

37

set/12 dez/12

20092010

Custo Real

Custo Real

2009 2010 2011 2012

Custo Nominal Custo Real

2013 2014 2015 2016 Após 2017

Indebtedness

3T09 3T10 9M09 9M10

Average Term: 4,2 years

AMORTIZATION SCHEDULE* (R$ MN)

Nominal Cost Real Cost

Dec/12Dec/11

3,383.24,273.1

NET DEBT

2.7 2.9

*ConsideringHedge

* Principal only

COST OF DEBT

US$/Euro 0.8%

CDI/Selic 72.1%

TJLP 25.1%

2011201020092007 2008 2009 set/10

Custo Real Custo Nominal

2.24%

8.21%

5.30%

9.84%

4.87%

11.08%

4.25%

11.03%

2012

Net Debt / EBITDAOthers 2.0%

481671 784 886

1,796

2009 2010 2011 2012

Custo Nominal Custo Real

2009 2010 2011 2012

Custo Nominal Custo Real

2009 2010 2011 2012

Custo Nominal Custo Real

2013 2014 2015 2016 After2017

2011

The pre payment of R$ 375 million in October reduced the cost of debt and extended the amortization schedule

38

2008 2009 2010 2011 2012

Investments

2008 2009 2010 2011 9M11 9M12

CAPEX (R$ MN) CAPEX BREAKDOWN (R$ MN)

2012

201020092008

563.8546.7

928.6

700.6

2011 2012

796.8

Generation Projects

1.9

Quality Improveme

nt122.7

Generation Maintenanc

e23.7

Others206.8

Develop. of Distribution System

215.7

Losses Combat199.8

Investments in Electric Assets (Distribution)

694.1

102.7

453.8

92.9

446.9

116.9

518.8

181.8774.8

153.8

Commerc./Energy

Eficiency26.1

Desenvolv. do Sistema de Distribuição $ 215,7

Combate às Perdas $ 199,8

Melhoria da qualidade $ 122,7

Outros $ 206,8

Manutenção de geração $ 23,7

Novos projetos de geração $ 1,9 Comercialização /Eficiência Energética $ 26,1

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Why invest in Light?

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 ProgramNew network and meters in the pacified favelasSmart metering development“Zero Losses Area” Program

Energy Losses

Reduction

Investment in Renova. Belo Monte and Guanhães (total of 477 MW)SHP Lajes under construction.HPP Itaocara

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 sixth year.

Best-in-Class Corporate

Governance

Sound Dividend Policy: minimum 50% of net income;

Average payout since 2007: 91%

Dividend track Record

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Regulatory Framework

The Provisional Measure 579 was enacted on September 11, 2012 and thereafter converted into Law

12,783 providing for electric power concessions, reduction of sector charges and reasonable tariffs which

although these have not directly affected Light, as its concessions will expire only in 2026, resulted in the

following developments:

on January 24, 2013, Resolution issued by Aneel approved an average reduction of 19.63% in Light

SESA’s tariffs. For residential consumers (low voltage), the reduction was 18.10%. The measure will

have no impact on the company’s result or cash flow since it reflects an equal reduction in costs.

on the same date, the distribution of power plants energy quotas was ratified, which had their

concession renewed:

(i) but lower to the distribution companies’ contracting needs, thus, causing an involuntary

exposure, and only for Light it accounted for average 156 MW; and

(ii) made distribution companies to start sharing the hydrological risks, which before was only

supported by generation companies

As of October 2012, an adverse hydrological situation was characterized in Brazil’s electricity sector, the

basis of which is mainly hydric, enforcing the System National Operator to dispatch all the thermal power

plants available in the system, thus significantly rising the costs of distribution companies by increasing

fuel expenditures in availability agreements, increasing System Service Charges due to energy security and

acquisitions on the spot market in order to answer that involuntary exposure.

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On March 8, 2013, the federal government issued the Decree 7,945 preventing the coverage of non-

manageable costs related to thermal plant dispatch, involuntary exposure and hydrological risk not covered

by the 2013 tariff, as follows:

Eletrobrás will transfer the resources of Energetic Development Accout (CDE) directly to the

concessionaires on the same dates and to the same accounts as the respective monthly transfers of

the Electricity Trading Chamber (CCEE) financial guarantees.

Aneel will publish the monthly dispatches with the amounts to be transferred by Eletrobrás via the

CDE (energy development account).

System Service Charge (ESS) – The monthly transfer will be determined by the difference

between the amounts settled in the CCEE and the tariff coverage defined in the last

adjustment.

Involuntary Exposure associated with the quotas – The monthly CDE transfer will cover

the difference between the difference settlement price (PLD) and the acquisition 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.

The remaining energy purchase and ESS costs not covered by the decree, including fuel costs of

availability contracts not included on tariffs, will continue going towards the formation of the regulatory

assets and liabilities (CVA) to be determined in Light’s November/13 Tariff Revision.

The Public Hearing opened for regulating decree proposes a transfer rate until 3% of the balance of CVA,

the rest will be payed "in cash" from CDE funds.

Regulatory Framework

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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.

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Contacts

João Batista Zolini CarneiroCFO and IRO

Gustavo WerneckIR Manager

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

www.light.com.br/ri

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