2
Light HoldingsLight Holdings
Holding
Light Serviços de Eletricidade
S.A.
Distribution
Light Energia S.A.
Generation
Light EscoPrestação de
Serviços S.A.
Trading/Services
ItaocaraEnergia S.A.
Lightger S.A.(SHPP
Paracambi)
LighthidroS.A.(Non
Operational)
Axxiom S.A.Axxiom S.A.
Technology
EBL
LightcomComerciali-zadora de
Energia S.A.100% 100% 51% 100% 100% 51%
100%51%33%
3
RankingsRankings
IntegratedNet Revenues 2009 – R$ Billion
48,566
42,786 41,269
28,28021,492 21,286
DistributionEnergy Consumption in Concession Area (2009) - GWh1
11.710.6
7.05.6 5.4 4.6
Generation Private-owned CompaniesInstalled Hydro-generation Capacity (MW) – 2009
5,175
2,6512,237
1,737 1,688
855
Souce: Companies reportsNote: 1 – Captive market + free clients
2 – It doesn’t consider the consumption of CSN, Valesul and CSA
4
Shareholders StructureShareholders Structure
Controlling shareholder [52.1%] Free Float [47.9%]
MarketLEPSA
13.03% 13.03% 15.02% 32.88%
Dec 2010
LUCE
RME
REDENTOR
26.06%
Free Float [47.9%]
Market
26.06% 26.06% 15.02% 32.88%
SPVPARATI
>50%<50%
Controlling shareholder
[52.1%]
Final Structure
FIPREDENTOR
11 Board members: 8 from the controlling group, 2 independent and 1 employees nominated
A qualifying quorum of 7 members to approve relevant proposals such as: M&A and dividend policy.
5
Corporate GovernanceCorporate Governance
Controller discussion group
Controller discussion group
Controller groupController group MinorityMinority
General AssemblyGeneral Assembly
Fiscal CouncilFiscal Council
Board of DirectorsBoard of Directors
AuditorsCommitteeAuditors
CommitteeGovernance and
Sustainability Committee
Governance and Sustainability
Committee
Human Resources Committee
Human Resources Committee
Finances CommitteeFinances
Committee
Management Committee
Management Committee
ManagementManagement
Shareholders11 Board members: 2 independent and 1 employees nominated
2 years term
Fiscal Council
Manual of Corporate Governance
Interface
6
• 4.0 million clients (attending over 10 million people)• Energy sales (2009) – 21,492 GWh• 70% of the consumption of Rio de Janeiro state (Brazil’s 2nd GDP)
5th largest energy distribution company in Brazil5th largest energy distribution company in Brazil
Distribution BusinessDistribution Business
7
Energy ConsumptionConsumptionDistribution
ELECTRICITY CONSUMPTION ¹
(GWh)
22.2 ºC 21.7 ºC22.7 ºC
22.1 ºC
3Q103Q093Q083Q07
+3.1%
5,1444,989
+1.9% a.a.
4,9804,802
24.5 ºC 23.6 ºC24.7 ºC
24.4 ºC
9M109M099M089M07
+6.0%
16,72815,77515,67215,533
+1.6% a.a.
,
Free Customers 14.9%
Residential 34.6%
Others 15.6%
Commercial 27.0%
Industrial 8.0%
¹ Note: To preserve comparability in the market approved by ANEEL in the tariff adjustment process, the billed energy of the freecustomers Valesul, CSN and CSA were excluded in view of these customers’ planned migration to the core network.
8
Total Market
FREECAPTIVE
RESIDENTIAL INDUSTRIAL COMMERCIAL OTHERS TOTAL
9M09 9M10 9M09 9M10 9M09 9M10 9M09 9M10 9M09 9M10
ELECTRICITY CONSUMPTION (GWh)
(CAPTIVE + FREE MARKET)+6.0%
4,382 4,379
15,775
607 764
16,728
+6.9%
+3.2%
2,421 2,499
2,549
127 131
2,630
+5.9%
4,447 4,593
4,697249 379
4,972+7.2%
1,349 1,286
2,744
1,395 1,654
2,940
5,785 6,185
9
Investments scheduled
Revitalization of the Port zone
Expansion of subway system
Urbanization of slums
Depollution of the Rodrigo de Freitas Lake
Construction of the Metropolitan Arch
Expansion of Tom Jobim airport
Construction of 50,000 housing units by 2013
T5 Corridor
Rio-São Paulo bullet train²Angra 3
Via Light (Road)
Investments in optic fibers by 2016
Improvement and acquisition of new trains by Supervia
Renovation of Hotel and Marina daGlória
Expansion of hotel capacity (5 new hotels on the waterfront, 8,000 beds in ships)
Construction of COMPERJ
Expansion and modernization of REDUC
Construction of CSA
Eisa naval industry
Sudeste Port
Gerdau – Port Terminal
Coquepar
CSN – Itaguaí Logistics Platform
Construction of Barra da TijucaComplex
Construction of Deodoro Complex
Renovation and Expansion of Maracanã Stadium
InfrastructureR$ 31 billion
PrivateR$ 41 billion
OlympicsR$ 4 billion
1 Source: Firjan, Rio de Janeiro Town Hall, Light and Construction Industry Union of Rio de Janeiro.² Considering the part inside of the State of Rio de Janeiro
Total estimated investments1 of R$ 76 billion
Till the World Cup in 2014 and the Olympics in 2016
10
Collection Rate
COLLECTION RATE BY SEGMENT9 MONTHS
COLLECTION RATE12 MONTHS97.8% 98.7% 95.8%94.0% 101.3% 101.1% 105.4% 105.6%
97.2% 98.0%
Sep/09 Sep/10Total Retail Large Customers
Public Sector
9M09 9M10
11
42.5% 42.7% 42.1%
37.3%
5,149 5,313 5,330
2,191 2,197 2,214
4,958 5,352
7,5517,5497,5047,2697,005
2,1202,047
42.3% 42.4%
Sep/09 Dec/09 Mar/10 Jun/10 Sep/10
Losses
LOSSES (12 months)
NON TECHNICAL LOSSES PROFILE
Risk areas 39%
Out of risk areas 61%
Non-technical losses GWh
Techincal losses GWh
% Non-technical losses / Low voltage market
% Non-technical losses / Low voltage market -Regulatory
12
New Technology Program
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
Technology used in regions in which conventional measures are not effective
Areas that present high levels of non-technical losses
Control room
7 5 41 2 75 4 12
Actual grid Shielded grid
9 m
Low voltage
AnalogicMeter
Medium voltage
Display
Low voltageMedium
voltage
Centralized meter
3 m
13
New Technology Program
Meters Installed (as of Dec, 2010)
38,000
122,000
84,000
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
TOTAL INDIVIDUAL CENTRALIZED
14
Results of New TechnologiesResults of New Technologies
INDIVIDUAL METERING(ISM)
CENTRALIZED METERING (CSM)
BILLED CONSUMPTION GROWTH (2010/2009)CSM x Around Region
TOTAL LOSSES AT AREAS WITH ISM
Around region CSM
9.5%
22.7%
3.6%
7.9%
12.3%
29.2%
2.4%
31.7%
4.9%
16.0%
3.4%
11.7%
Apr May Jun Jul Aug Sep
22.0%
15.0%
11.0%9.0%
6.1%
Feb/08 Dec/08 Jul/09 Dec/09 Oct/10
Regions of Barra da Tijuca and Jacarepaguá Region of Realengo
16
Action in Pacified Communities
Regions with high losses and potential return
Expansion of the PPU*'s police allows different actions in the risk areas
Actions of energy efficiency in communities
*PPU : Pacification Police Units
LAMPS REFRIGERATORS
99.7 thousand 5.6 thousand
Communities billed
Light started to bill new communities in December: Babilônia, Casa Branca, Batam and Cantagalo.
17
Action in Pacified Communities
CLIENTS LOSSESDELINQUENCY
RATEBEFORE 80 90% 70%AFTER 1,671 2% 2%
BEFORE 408 56% 74%AFTER 540 1% 2%
BEFORE 2,800 52% 68%AFTER 3,700 8% 0%
BEFORE 389 73% 54%AFTER 850 TBD TBD
BEFORE 470 77% 52%AFTER 740 TBD TBD
BEFORE 0 62% 51%AFTER 500 TBD TBD
BEFORE 1,054 66% 79%AFTER 2,003 TBD TBD
COMMUNITIES
CASA BRANCA
BATAM
CANTAGALO
SANTA MARTACHAPÉU
MANGUEIRA
CIDADE DE DEUS
BABILÔNIA
18
Tariff Review - Aneel´s Proposal for 3rd cycleRegulatory WACC
Equity 42.84% 40.00%Debt 57.16% 60.00%
Risk Free Rate 5.32% 4.96%Equity Risk Premium 6.09% 5.78%Beta 0.772 0.650Country Risk 4.91% 4.42%FX risk 1.78% eliminatedUS inflation 2.60% 2.48%Nominal Cost of Equity 16.71% 13.14%Real Cost of Equity 13.75% 10.40%
Credit Risk 2.96% 2.12%Nominal Cost of Debt 14.97% 11.50%Real Cost of Debt 12.06% 8.80%Weighted Average CostNominal WACC after tax 12.81% 9.81%Real WACC after tax 9.95% 7.15%Pre‐tax Regulatory Return 15.07% 10.84%
2nd Tariff Revision
3rd Tariff (Aneel's Proposal)
Capital Structure
Cost of Equity
Cost of Debt
Regulatory returns for distribution andtransmission
9.95%9.28%
11.26%
7.24% 7.15%
Distribution2003 (1st
Cycle)
Distribution2007 (2nd
Cycle)
Distribution2011 (3rd
Cycle)
Transmission2005 (1st
Cycle)
Transmission2009 (2nd
Cycle)
19
Tariff Review - Aneel´s Proposal for 3rd cycle
Main periodic tariff review dates
Last Revision Next Revision
Coelce 22‐Apr‐07 22‐Apr‐11Eletropaulo 04‐jul‐07 4‐Jul‐11EDB ‐ Bandeirante 23‐Oct‐07 23‐Oct‐11CPFL ‐ Piratininga 23‐Oct‐07 23‐Oct‐11
CPFL ‐ Jaguariuna 3‐Feb‐08 3‐Feb‐12CPFL ‐ Santa Cruz 3‐Feb‐08 3‐Feb‐12Copel 24‐jun‐08 24‐Jun‐12Celesc 7‐Aug‐08 7‐Aug‐12
Cemig 8‐Apr‐08 8‐Apr‐13CPFL ‐ Paulista 8‐Apr‐08 8‐Apr‐13CPFL ‐ RGE 19‐Apr‐08 19‐Apr‐13EDB ‐ Escelsa 7‐Aug‐10 7‐Aug‐13Equatorial ‐ Cemar 26‐Aug‐09 28‐Aug‐13Light 07‐nov‐08 7‐Nov‐13
2013
2012
2011Light
EBITDA by segment - 2013
Generationand Trading
30%
Distribution70%
20
Generation BusinessGeneration Business
Installed capacity 855 MWInstalled capacity 855 MWInstalled capacity 855 MW
• 855 MW of installed capacity• 5 power plants and 2 pump stations• 537 MW average of assured capacity
• 855 MW of installed capacity• 5 power plants and 2 pump stations• 537 MW average of assured capacity
21
Installed Capacity
HPP Santa Branca56 MW
HPP Ilha dos Pombos187 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 Capacity855 MW
100% 100%
100%100%100%
LajesComplex
22
Re-pricing of existing energy
GENERATION Assured energy: 537MW average
2008-2012
27
2013
27
2014
27
510
146
234
130
276
234
Contracted Energy
Uncontracted Energy
New Contracts
Hedge
23
Strategy of growing in generation
Installed Capacity Expansion
Commitment to invest jointly in new generation projectsPotential new projects already analyzed by CEMIG
Light is constantly looking for new opportunities in renewable energy
Small Hydro Power PlantsHydro Power PlantsBiomassWind energy
Assets with potential for improvement and further expansionAssets belonging to investors that do not have a long-term commitment to Brazil
Greenfields
Acquisition ofExistingAssets
Joint Venturewith CEMIG
1,282
855 13 9
306
99
+50%
Generationcapacity
SHPPParacambi¹
SHPPLajes¹
HPPItaocara¹
NewProjets
Future Generation
capacity
Growth Opportunities
¹ Corresponds to 51% Light’s stake in each project.
24
SHPP Paracambi
PROJECT HISTORICAL
ConstructionBeginning
Construction Status45% done
OperationalStart
Oct/2009 Nov/2011Nov/2010
24
26
Net Revenues
NET REVENUE GROWTH (R$ MN) NET REVENUE BY SEGMENT (9M10)*
+4.3% a.a.
2009
5,432
20082007
5,3874,992 +12.7%
3,9304,429
9M109M09
Generation 5.1%
Distribution 91.9%
Commercialization 3.0%
*Eliminations not considered
DISTRIBUTION NET REVENUE (9M10)
( Free Customers + Concessionaires)
Commercial 25.5%
Industrial 7.6%
Others (Captive) 12.6% Network Usage (TUSD) 6.3%
Residential 44.1%
26
27
Operating Costs and Expenses
COSTS (R$MM)*9M10
MANAGEABLE DISTRIBUTION COSTS (R$ MN)
2006
1,561 -30.1%
2009
1,143994
1,090
2007 2008 9M09 9M10
791786
+0.7%
Manageable (distribution): R$ 791.0(21.1%)
Generation andCommercialization : R$ 199.7(5.3%)
Non – Manageable (distribution): R$ 2,760.2(73.6%)
R$ MN 3Q09 3Q10 Var. 9M09 9M10 Var.
PMSO 119.9 146.4 22.1% 358.3 423.7 18.3%
Provisions 67.0 21.8 -67.5% 217.6 151.1 -30.5%
PDD 57.9 66.7 15.2% 184.3 205.5 11.5%
Contingencies 9.1 (44.9) - 33.3 (54.3) -
Depreciation 70.1 73.5 4.9% 210.1 216.2 2.9%
Total 257.0 241.7 -5.9% 785.9 791.0 0.6%
*Eliminations not considered
27
28
EBITDA
22.8% 21.9%
27.9%
21.9%21.6%
20071 2008 2009
1,138 1,1881,504
9M109M09
969848
Generation 16.9%(EBITDA Margin:
71.5%)
Commercialization 1.9% (EBITDA Margin: 13.6%)
Distribution 81.2%(EBITDA Margin:
19.2%)
EBITDA (R$ Million) and EBITDA Margin EBITDA BY ACTIVITY*9M10
*Eliminations not considered
EBITDA EBITDA Margin
¹ Pro forma: does not consider profit sharing costs
28
29
Net Income
NET INCOME (R$ MN)
1,074
605
9M09 9M102009
974
357 350
2007 2008
223
418479
-2.0%
non-recurring effects
29
30
Dividends
16.2%PAYOUT AND DIVIDEND POLICY
2007 2008 2009
518559
595
8.3%12.3% 11.6%
2010
795
100% 100%
76.3%
2007 2008 2009
50%
Payout Dividend PolicyDividends (R$ MN) DividendYield*
* Based on the closing price of the previous day to the announcement
30
31
Indebtedness leverage
Net Debt¹ (R$ MM) and Net Debt / EBITDA
Rating(brA - )
InvestmentGrade(brA)
Rating(brA + )
Rating(Aa2.br)
2006
3.4
2,540
20072
1,580
2008
1.1
1,637
1.4
2009
1.3
1,664
1,462
Set/10
1.3
Net Debt Net Debt/ EBITDA
¹ Net debt = total debt (excludes pension fund liabilities) – cash² EBITDA Pro Forma, not considering costs of profit sharing costs
31
32
Indebtedness
Amortization Schedule* Sep/10 (R$ MN)NET DEBT
Duration: 3.2 years
45
495414
481
596
122 267
Nominal CostReal Cost
Sep/102007 20092008
Jun/10 Sep/10
1,6641,805
1.4 1.3
2010 2011 2012 2013 2014 2015 After 2015
US$/Euro 1.8%*
CDI/Selic75.0%
TJLP 23.2%
*Considering HedgeC
6.32%
11.32%
7.39%
12.17%
7.62%
13.97%
5.30%
9.84%
* Only principalDebt Cost Evolution
32
33
Capital Expenditures
INVESTMENTS (R$MN) INVESTMENTS (R$MN)9M10
9M109M09
352.8437.0
+23.9%
200920082007
563.8546.7
354.7
706.0
2010E
DistributionDevelopment
SystemR$ 194.1
Losses Combat R$ 75.6
Quality Improvements
R$ 66.0
New projects of generation
R$ 60.0
Generation Maintenance
R$ 17.4
Others
R$ 23.7
33
34
Contacts
João Batista Zolini CarneiroCFO and IRO
Renato RochaHead of Planning and IR
+ 55 21 2211 [email protected]
Gustavo WerneckIR Manager
+ 55 21 2211 [email protected]
www.light.com.br/ri
36
Tariff Breakdown
DISTRIBUTION TARIFF BREAKDOWN
Sector Charges 9.5%
,
Taxes 31.8%
Transmission 4.8%Distribution 23.1%
Energy Purchase 30.9%
Taxes and sector charges represent 46.1% of the tariff. Only 23.1% covers distribution expenses.
37
Distribution Companies
AMPLA
State-owned Companies
Private-owned Companies
Source:
64 companies:24 private owned (37%)
21 privatized (33%)
19 state owned (30%)
38
Final Tariff Review - Losses
2003 2008PRELIMINARY
1
2008DEFINITIVE1
15.95%
19.15% 19.09%
Regulatory Losses Trend
nov/08 –out/09
5.61% 5.61% 5.61% 5.61% 5.61%
nov/09 –out/10
nov/10 –out/11
nov/11 –out/12
nov/12 –out/13
Technical Losses / Grid Load(%)
nov/08 –out/09
nov/09 –out/10
nov/10 –out/11
nov/11 –out/12
nov/12 –out/13
38.98% 37.19% 35.40% 33.61% 31.82%
Non Technical Losses / Low Voltage Market (%)
Total Losses / Grid Load (%)
Energy Balance (GWh) 9M10 9M09 Var.%= Grid Load 26.048 24.237 7,5%
- Energy transported to utilities 2.345 1.921 22,1%- Energy transported to free customers 3.717 3.033 22,5%
= Own Load 19.986 19.283 3,6%- Captive market consumption 14.564 14.004 4,0%
Low Voltage Market 9.446 8.886 6,3%Medium Voltage Market 5.118 5.118 0,0%
- Losses + Non Billed Energy 5.422 5.279 2,7%
1- Preliminary announced on November 3, 2008 / 2008 definitive was approved in October 13, 2009
39
Important NoticeImportant 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.