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1
First Quarter Results2003
2
I. Overview of the Company
II. Energy Distribution Market
III. Operational Performance
IV. Financial Indicators
V. Regulatory Scenario
VI. Conclusion
3
I. Overview of the Company
II. Energy Distribution Market
III. Operational Performance
IV. Financial Indicators
V. Regulatory Scenario
4
BackgroundBackground
April 1998: Privatization of EletropauloLightgas controlled at the time – through Light – by (AES, EDF, Reliant, CSN) and BNDESpar
January 2000: BNDESPar carried out a public offering for the sale of Eletropaulo’s preferential stock
AES acquired 64% of the preferential stock for US$ 1.1 billion through AES Transgas
December/2000: CSN and Reliant sold participations in Light/Eletropaulo
February 2002: Consolidation of the restructuring process between EDF and AES
AES assumed the control of EletropauloEDF assumed the control of the administration of LightThe corporate restructuring was approved by ANEEL
June 2002: CVM approves AES ELPA to go public
November 2002: AES ELPA stock was segregated from Light’s stockAES ELPA stock is negotiated under the ticker AELP3 at BOVESPA
5
Shareholder structureShareholder structure
Other20.40%
AES50,45%
EDF19.92%
Federal Govern.9.23%
Other 20.40% Federal
Gov 9.23%
AES 70.37%
Minority
Transgás Elpa AESCemig Minority Government
100% 88,2% 11,8%
64,1%PN 77,8%ON 7,4%PN 26,4%PN 22,2%ON and 2,1% PN
(*) total shares
Shareholder structure (*) before decross
Shareholder structure(*) after decross
(*) total shares
6
Concession AreaConcession Area
The largest electrical energy distribution company in Latin America5.0 million consumers
The most attractive concession area in BrasilA solid economic basis containing a population with high income High percentage of sales to the residential sector
11,17%32.451290.465Energy (GWh/year)*
8,62%15.200.000176.315.325Population
0,05%4.5268.547.403Km2
%Eletropaulo Brazil
* Source: Eletrobrás and Eletropaulo
FY 2002
7
I. Overview of the Company
II. Energy Distibution Market
III. Operational Performance
IV. Financial Indicators
V. Regulatory Scenario
8
Consumption EvolutionConsumption Evolution
35.578 35.401
32.485 32.451
33.100
37.424
2%
-0,10%
-13,20%
5,71%
-0,50%
1998 1999 2000 2001 2002 2003(p)
GWh %
9
Consumption EvolutionConsumption Evolution
Monthly Consumption (GWh)
2.000
2.200
2.400
2.600
2.800
3.000
3.200
3.400
Janua
ry
Febru
ary
Mar
ch
April
May
June July
August
Sept
embe
r
Octob
er
Novem
ber
Decem
ber
1999 2000 2001 2002 2003
10
Consumption 1Q02 - GWh Consumption 1Q03 - GWh
Income 1Q02 Income 1Q03
ResidentialIndustrial
CommercialOthers
ResidentialIndustrial
CommercialOthers
Profile of ConsumersProfile of Consumers
30%
33%
27%
10%
32%
29%
29%
10%
38%
24%
30%
8%
39%
22%
31%
8%
11
I. Overview of the Company
II. Energy Distribution Market
III. Operating Performance
IV. Financial Indicators
V. Regulatory Scenario
12
Development of Performance IndicatorsDevelopment of Performance Indicators
FEC (times)
9,5510,70 10,88 10,70 10,74 10,76 10,21 10,19 9,52 9,20
7,518,68 8,38
1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 1Q03 (*)
DEC (hours)
18,66 18,76 18,06 16,37 16,32 17,4214,04
18,2115,94
11,44 11,128,99
11,09
1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 1Q03(*)
Pre-privatization TrendPost-Privatization Trend
TMA (minutes)
145 139 148 161187
215
158 159134
100 114 11187
1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 1Q03
Pre-Privatization Trend Post-Privatization Trend
Pre-Privatization Trend Post-Privatization Trend
AneelStandard2003 DEC:
12,57 hours
Aneel Standard2003 FEC:
8,95 times
Aneel Standard2003 TMA:130 min
(*) annualized rolling 12-month .
13
Background of Investments in Eletropaulo Background of Investments in Eletropaulo
Installed Capacity x Market(MVA)
10.594 10.677 10.689 10.638 10.75110.993
11.23011.737 11.903
12.28612.556
4.9365.182 5.287
5.542 5.656 5.660
5.2375.528
6.273
4.630 4.746
1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002
Nominal Capacity of the System ETD+ESD+ETSD Market (ETD+ESD+ETSD)
32000
33000
34000
35000
36000
37000
38000
1998 1999 2000 2001 2002
GW
h -
Thou
s.
0
50
100
150
200
250
300
350
400
R$
MM
Investments (Capex) Consumption - GWh
Administrative21%
Subtransmission13%
Distribution66%
Capex 2002 - R$ 180.376 Thous.
Capex 1Q03 = R$ 38 MM
14
I. Overview of the Company
II. Energy Distribution Market
III. Operational Performance
IV. Financial Indicators
V. Regulatory Scenario
15
Eletropaulo’s Market ValueEletropaulo’s Market Value
0
50
100
150
200
250
300
350
400
jan/98 abr/99 ago/00 dez/01 mar/03
Bas
is P
oint
s
Eletropaulo Brazil Risk R$/US$
RussianCrises
ArgentinaCrises
RationingStarts
WTC’sStrike
Source: Bloomberg
16
Losses with RationingLosses with Rationing
? BNDES still has to release a tranche of R$ 240 million related to rationing lossesincurred in January and February/2002
Assuming the historical growth of 3.5% estimated losses were – R$ 1,965MM
900
1.100
1.300
1.500
1.700
1.900
2.100
2.3001
Q 0
0
2 Q
00
3 Q
00
4 Q
00
1 Q
01
2 Q
01
3 Q
01
4 Tr
i 01
1 Q
02
2 Q
02
3 Q
02
4 Q
02
R$ MM
Net Revenue BNDES Loan Net Revenue w/out Rationing
?
17
Debt restructuring process in 1Q2003Debt restructuring process in 1Q2003
In July 2002 Eletropaulo started a process to restructure its debt due to problems of credit liquidity by trying to establish a balance between maturity dates of obligations and Eletropaulo’s capacity for generating cash
Approximately R$ 880 million (net of funding) was paid and R$ 1.5 billion was refinancedBetween January and April of 2003 approximately R$ 282 million was paid and R$ 371 million was renegotiated
6543
105
70
150(**)
221 (*)
jan/03 fev/03 mar/03 abr/03PAID RENEGOTIATED
(*) CP and Bladex’s Loan (was renegotiated in February – pushing back final maturity from 2005 to 2006).(**) 2nd Serie of 7th Debentures issue.
(R$ MM)
18
1Q2003 Debt1Q2003 Debt
In 2002 hedge contracts were not renewed due to lack of credit linesAs part of the debt restructuring process 66% of Dollar debt was converted into ReaisIn 1Q2003, Eletropaulo maintained 45% of its total debt in DollarsEletropaulo regained access to hedge lines
total hedge in March 2003 - US$ 110 million14,2% of total Dollar debt is hedged
54%
46% R$
US$
45%
55%
(*) The amounts were exchanged by Ptax in the end of each month:Dec/ 2002 – 3,533March/ 2003 – 3,353
R$
US$
9% w/ hedge 14,2% w/ hedge
Consolidated debt - 12/31/2002(R$ 5.91 billion, of which R$ 2.7 billion
were in US$)*
Consolidated debt – 03/31/2003(R$ 5.8 billion, of which R$ 2.6 billion
were in US$)*
19
68%
32%
Short Term Long Term
Indebtness - Short Term x Long TermIndebtness - Short Term x Long Term
short term debt does not reflect the actual schedule for payments maturing because it includes debts with breach of contractual obligations (financial covenants) and cross-default.The amount of consolidated debt re-classified as Short Term with schedule of amortizations unaltered is R$ 1,922 million.By schedule of payment maturities, about 40% of total debt will mature in the short term
12/31/2002 03/31/2003
73%
27%
Short Term Long Term
20
Due Dates of Principal Payments in 2003Due Dates of Principal Payments in 2003
Note: the maturity of principal payments of dollar debts as 03/31/2002 were converted by the exchange rate (US$/R$ = 3,3531)
The company intends to proceed with its strategy of adapting the due dates of its debt to its generation of cash by lengthening the payment terms of its loans
8 8 9 9 9 9 9 10 10
92 89
143
1 3 5
225
5
199
91
60
35
50 49
35
228
37 37
abr/03 mai/03 jun/03 jul/03 ago/03 set/03 out/03 nov/03 dez/03
US$ R$ BNDES
Syndicated Loan(US$ 25MM)
Debentures(R$ 55MM)
Syndicated Loan(US$ 25MM)
143
92 91 89
CommercialPaper (US$ 7,7MM) and
Syndicated Loan(US$ 25MM)
225Bank LoanDeustche
Bank
(US$ 60MM)
228
SyndicatedLoan JP
Morgan (R$ 160MM)
199
Commercial Paper(US$ 49MM)
21
Results – 1Q2003 (R$ MM)Results – 1Q2003 (R$ MM)
4o tri 02 1o tri 03
1.542,8 1.409,1 -8,7%
(1.662,2) (1.255,9) -24%
EBITDA (119,3) 153,2 +228%
66,2 (13,9) -222%
(281,7) 70,5 +213%
(106,0) - 347%
(339,4) 14,2 +104%
Main Reasons for 1Q2003 Profit:� Decrease in Provisions� Real Revaluation
Monetary Variation in Local Currency – besides debt cost in Reais
Drop in consumption due to seasonal effects
Provision for Actuarial Liabilities with CESP Foundation– CVM 371 – It is no longer accounted as Extraordinary Item, but as Personnel Expense
(*) Consolidated Figures
Drop in: � Electric power purchase expense due to the reduction by 25% of Initial Contracts, � Other Operational Expenses due to provisions occurred in 4Q02, that did not repeat in 1Q03
NET INCOME
OPERATING EXPENSES
FINANCIAL INCOME(EXPENSES)*
RESULTS BEFORE TAXES ANDOTHER ITEMS
OTHER ITEMS NET OF TAXES
NET PROFIT (LOSSES)
22
EBITDA AdjustedEBITDA Adjusted
R$ 153,2 MMEBITDA
(with CVM 371 effects)
R$ 123,6 MM
R$ 276,8 MMR$ 276,8 MM
EBITDA (WITHOUT THE EFFECT
OF PROVISIONS)
Provision for Actuarial Liabilities with CESP Foundation – CVM 371
R$ -119,3 MMEBITDA
(taking into account Provisions)
R$ 155,7 MM
R$ 273,5 MMR$ 273,5 MM
EBITDA (WITHOUT THE
EFFECT OF PROVISIONS)
Provisions for Labor and Cetemec Contingencies
R$ 148,3 MMProvision for the debt of São
Paulo City Hall
R$ 88,8 MM Provision for Doubtful Debt
4th Quarter 2002 1st Quarter 2003
23
I. Overview of the Company
II. Energy Distribution Market
III. Operational Performance
IV. Financial Indicators
V. Regulatory Scenario
24
Tariff ResetTariff Reset
Privatization Reset
Annual Readjustment (X Factor = zero in first four years)
Annual Readjustment (X factor = 0)
0 1 2 3 4 5 6 7 8 9 10Year
Principle of maintainance of the economic-financial equilibrium of the concession through:
Annual Readjustment: according to the pre-established formula of the ConcessionContract
Periodic Reset: every four years after privatization, without a pre-establishedmethodology in the Concession Contract
Extraordinary Resets: When significant changes to cost base of concessions occur, altering economic-financial equilibrium
Currency devaluation in June 1999
Tariff Readjustment Index = VPA + VPB * (IGPM +/- X)Revenues
Reset
25
Mechanism for Tariff ResetMechanism for Tariff Reset
* CVA – Compensation Account for Variations of Values of Parcel A’s items
Distributors have tariffs readjusted annually to pass through non-manageable costs (Parcel A) and update manageable costs (Parcel B) based on IGP-M.
CVA* was created in 2001 to allow pass through of changes in costs of Parcel A that occurred between tariff readjustments
Measure MME/MF 116/03, of the 4th of April 2003 postponed, for 12 months, the compensation of the balance of CVA and this will be compensated over 24 months starting in July 2004
Required Income =Required Income ==
Parcel A Parcel B
Manageable costs
Exchange variation – energy fromItaipuCCCCosts with transmission gridPurchased EnergyCost of monitoring Return onReturn on
CapitalCapital
DepreciationDepreciation
O & MO & M
26
Eletropaulo’s Tariff Readjustment (1999 – 2002)Eletropaulo’s Tariff Readjustment (1999 – 2002)
0%2%4%6%8%
10%12%14%16%18%
1999 2000 2001 2002Parcela B Parcela A IGPM IPCA
27
Tariff Reset DynamicsTariff Reset Dynamics
ReturnReturn
DepreciationDepreciation
O & MO & M
Parcel B
BaseBase
Required Income
Parcel AParcel A
MWhx
Tariff
MWhx
Tariff
Verified Income
x
Periodic Reset % = Required RevenuesVerified Revenues
WACC(Pre-Tax)
WACC(Pre-Tax)
28
Tariff Reset EletropauloTariff Reset Eletropaulo
Schedule of Eletropaulo’s Tariff Reset (2003):26th May – Technical Note – Preliminary Number = 9.62%18Th June – Public Hearing – already held4th July – Tariff Reset Implementation – Final Number = 11,35%
10.95% (Tariff Reset)0.4% (collateral costs for energy purchase and some rationing costs incurred by EP during the rationing period)
The main factors that were not considered were:Rate Base calculation – Aneel is considering a preliminary level, which is a percentage of fixed assets adjusted by inflation – subject to Public Hearing to be scheduledFCESP – The actuarial cost with Cesp Foundation is not being considering by AneelTest YearAllowance for bed debts
29
Regulatory PerspectivesRegulatory Perspectives
X
TARIFF
INFLATION
Tariff Reset 2003
Basis of Remuneration
WACCDoes not mirror the actual cost of capital
X FactorNot compatible with
Subjective RC* criteria
Deferral of CVA Affects leverage andcredit limit
(*) Reference Company
Does not recoverinvestments made
30
I. General Overview of the Company
II. Energy Distribution Market
III. Operating Performance
IV. Financial Indicators
V. Regulatory Scenario
VI. Conclusion
31
Eletropaulo Eletropaulo
Eletropaulo is the largest energy distribution company in Latin America
Its concession area includes the Brazilian population with the highest purchasing power
Since privatization Eletropaulo has presented significant improvements in operating performance indicators, which resulted in better services for the population within its concession area
Rationing caused losses of R$ 1,965 million, only partially compensated by the Sector’s General Agreement
Rationing and closure of financial markets led to maturity concentration in the short term, the impossibility to renew hedges, and hence, the need to restructure Eletropaulo’s debt, extending maturity terms and converting Dollar debts into Reais
The greatest challenges that Eletropaulo faces at this time relate to regulatory issues, due to the Government’s intervention aimed at reducing the inflationary effect of tariff resets
Solid and feasible company that seeks to match the maturities of its loans with its cash generation and mitigate the effects of the instability
of the regulatory scenario
32
First Quarter Results2003