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SECURITIES AND EXCHANGE COMMISSION
UNITED STATES
Washington, DC 20549
FORM 20-F
[ ] REGISTRATION STATEMENT PURSUANT TO SECTION 12(b) OR (g) OF THE SECURITIES
EXCHANGE ACT OF 1934
OR
[X] ANNUAL REPORT PURSUANT TO SECTION 13 or 15(d) OF THE SECURITIES EXCHANGE
ACT OF 1934 FOR THE FISCAL YEAR ENDED DECEMBER 31, 2001
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 or 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
Commission file number: 1-8768
ESPIRITO SANTO CENTRAIS ELETRICAS S.A. - ESCELSA
(Exact name of Registrant as specified in its charter)
Energy Company of Espirito Santo
(Translation of Registrant's name into English)
Federative Republic of Brazil
(Jurisdiction of incorporation or organization)
Rua Sete de Setembro, 362
Vitoria, Espirito Santo, Brazil 29015-000
(Address of principal executive offices)
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Securities registered or to be registered pursuant to Section
12(g) of the Act:
Title of each class: Name of each exchange on which registered:
10% Senior Notes due 2007 Luxembourg Stock Exchange
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Securities registered or to be registered pursuant to Section
12(b) of the Act:
None
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Securities for which there is a reporting obligation pursuant to
Section 15(d) of the Act:
None
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Indicate the number of outstanding shares of each class of capital or
common stock of Espirito Santo Centrais Eletricas S.A. - ESCELSA as of December
31, 2001.
Common Shares without par value......................4,550,833
Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports) and (2) has been subject to such
filing requirements for the past 90 days.
Yes [X] No [ ]
Indicate by check mark which financial statement item the registrant
has elected to follow.
Item 17 [ ] Item 18 [X]
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TABLE OF CONTENTS
Page
PART I
ITEM 1. IDENTITY OF DIRECTORS, SENIOR MANAGEMENT AND ADVISERS..................1
ITEM 2. OFFER STATISTICS AND EXPECTED TIMETABLE................................1
ITEM 3. KEY INFORMATION........................................................1
ITEM 4. INFORMATION ON THE COMPANY.............................................9
ITEM 5. OPERATING AND FINANCIAL REVIEW AND PROSPECTS..........................28
ITEM 6. DIRECTORS, SENIOR MANAGEMENT AND EMPLOYEES............................40
ITEM 7. MAJOR SHAREHOLDERS AND RELATED PARTY TRANSACTIONS.....................44
ITEM 8. FINANCIAL INFORMATION.................................................45
ITEM 9. THE OFFER AND LISTING.................................................48
ITEM 10. ADDITIONAL INFORMATION...............................................48
ITEM 11. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK...........56
ITEM 12. DESCRIPTION OF SECURITIES OTHER THAN EQUITY SECURITIES...............57
PART II
ITEM 1. DEFAULTS, DIVIDEND ARREARAGES AND DELINQUENCIES.......................58
ITEM 2. MATERIAL MODIFICATIONS TO THE RIGHTS OF SECURITY HOLDERS AND
USE OF PROCEEDS.......................................................58
ITEM 3. [RESERVED]............................................................58
ITEM 4. [RESERVED]............................................................58
PART III
ITEM 1. FINANCIAL STATEMENTS..................................................58
ITEM 2. FINANCIAL STATEMENTS..................................................58
ITEM 3. EXHIBITS..............................................................58
ANNEX A--GLOSSARY OF TECHNICAL TERMS.........................................A-1
INTRODUCTION
All references in this annual report to:
o "we," "our" and "us" are to Espirito Santo Centrais Eletricas
S.A.-- ESCELSA and its consolidated subsidiaries, including Empresa
Energetica do Mato Grosso do Sul S.A.-- ENERSUL;
o "ESCELSA" are to Espirito Santo Centrais Eletricas S.A.-- ESCELSA
or to our electricity generation, transmission and distribution
business in the State of Espirito Santo;
o "ENERSUL" are to Empresa Energetica de Mato Grosso do Sul S.A.--
ENERSUL or to our electricity generation and distribution business
in the State of Mato Grosso do Sul;
o "Brazilian corporate law" are to Law No. 6,404 of December 15,
1976, as amended by Law No. 9,457, of May 5, 1997 and by Law No.
10,303 of October 1, 2001;
o the "Brazilian government" are to the federal government of the
Federative Republic of Brazil;
o "real," "reais" or "R$" are to Brazilian reais, the official
currency of Brazil;
o "U.S.$," "dollars" or "U.S. dollars" are to United States dollars;
o "Concessions Law" are to certain laws and regulations adopted by
the Brazilian federal government in 1995 in order to determine the
bidding procedures for the granting of concessions in the
electricity sector, namely Law No. 8,987, of February 13, 1995, Law
No. 9,074, of July 7, 1995 and Law No. 9,427, of December 26, 1996.
o "Central Bank" are to Banco Central do Brasil, or the Brazilian
Central Bank; and
o the "notes" are to the 10% Senior Notes due 2007 issued by us.
As used in this annual report, one kilometer equals approximately
0.621 miles.
FORWARD-LOOKING STATEMENTS
This annual report contains forward-looking statements relating to our
business that are based on our current expectations, estimates and projections.
Words such as "may," "will," "continue," "believe," "expect," "intend," "plan,"
"project," "estimate," "anticipate" and similar words or expressions are used to
identify such forward-looking statements. These statements are not guarantees of
future performance and involve risks and uncertainties that are difficult to
predict. Furthermore, certain forward-looking statements are based upon
assumptions as to future events that may not prove to be accurate. Therefore,
actual outcomes and results may differ materially from those expressed or
implied in such forward-looking statements.
Neither our independent auditors nor any other independent accountants have
compiled, examined or performed any procedures with respect to the
forward-looking financial information contained herein, nor have they expressed
any opinion or any other form of assurance on such information or its
achievability, and they assume no responsibility for, and disclaim any
association with, such forward-looking financial information.
factors that could cause actual results to differ materially include, but
are not limited to:
o general economic, political and business conditions;
i
o electricity shortages;
o changes in market prices, customer preferences and competitive
conditions;
o potential disruption or interruption of our services;
o management's expectations and estimates concerning future financial
performance, financing plans and the effects of competition;
o changes in currency exchange rates;
o existing and future governmental regulation; and
o other risk factors as set forth under "Item 3D -- Key Information
-- Risk Factors."
We undertake no obligation to update publicly or revise any forward-looking
statements because of new information, future events or otherwise. In light of
these risks and uncertainties, the forward-looking information, events and
circumstances discussed in this annual report might not occur. Our actual
results and performance could differ substantially from those anticipated in our
forward-looking statements.
PRESENTATION OF FINANCIAL AND OTHER INFORMATION
At July 10, 2002, the commercial market rate for purchasing U.S. dollars
was R$2.8541 to U.S.$1.00. The commercial selling rate reported by the Central
Bank is used in this annual report rather than the noon buying rate in New York
City as reported by the Federal Reserve Bank of New York because the noon buying
rate was not consistently reported for reais during the periods shown in this
annual report. See "Item 3A -- Key Information -- Selected Financial Data --
Exchange Rates" for information regarding exchange rates applicable to the real
since 1997.
The selected consolidated financial data at December 31, 2001 and 2000 and
for each of the years then ended have been derived from the consolidated
financial statements included elsewhere in this annual report. The selected
consolidated financial data as of December 31, 1998 and 1997 have been derived
from our consolidated financial statements that are not included in this annual
report.
We publish our financial statements in Brazil in accordance with generally
accepted accounting principles in Brazil, or Brazilian GAAP, which differ in
certain significant respects from generally accepted accounting principles in
the United States, or U.S. GAAP. Note 25 to our financial statements appearing
elsewhere in this annual report describes the principal differences between
Brazilian GAAP and U.S. GAAP as they relate to us, and provides a reconciliation
to U.S. GAAP of net income and shareholders' equity.
This annual report contains our audited consolidated financial statements
at December 31, 2001 and 2000 and for each of the three years in the period
ended December 31, 2001. On November 25, 1997, ESCELSA paid R$825.9 million to
acquire a 55.4% controlling interest (76.5% voting interest) in ENERSUL. The
results of operations of ENERSUL have been included in the consolidated results
of operations of ESCELSA since November 25, 1997. See note 11 to our financial
statements.
Our financial statements and, unless otherwise specified, all financial
information for periods ending on or before December 31, 2000 included in this
annual report have been restated to recognize certain effects of changes in the
purchasing power of the real due to inflation and expressed in constant reais of
December 31, 2000. This restatement was done using the integral restatement
method (correcao integral) required under Brazilian GAAP through December 31,
2000. See note 2 to our financial statements.
Under Brazilian GAAP and Brazilian corporate law, the Unidade Fiscal de
Referencia (the Tax Reference Unit, or UFIR) was used as the index in highly
inflationary times for inflation in the preparation of financial
ii
statements for periods through December 31, 1995. However, a Brazilian law
enacted in December 1995 abolished the prior Brazilian price-level restatement
system effective January 1, 1996 for corporate law purposes and for reporting by
public companies, although the Comissao de Valores Mobiliarios (the Brazilian
Securities Commission, or CVM) allows companies to prepare financial statements
in accordance with the constant currency method. Financial statements prepared
in constant currency were not and are not used for tax and other statutory
purposes. Since the UFIR is no longer updated, the Instituto Brasileiro de
Contabilidade (the "Brazilian Institute of Accountants") recommended that the
Indice Geral de Precos do Mercado (the General Market Price Index, or the
IGP-M), as published by Fundacao Getulio Vargas, a leading independent Brazilian
economic research organization, be used. From January 1, 1996 to December 31,
1997, 1999 and 2000, we used the IGP-M to prepare our financial statements in
constant currency.
In July 1997, the three-year cumulative inflation rate for Brazil fell
below 100%. However, for accounting purposes, the constant currency method
continued to be applied through December 31, 2000. Our management has concluded
that the effects of inflation, which was 1.8% in 1998, on our financial
statements for the year ended December 31, 1998, were not material.
On March 22, 2001, the Conselho Federal de Contabilidade -- CFC issued
Resolution No. 900, which was also approved by CVM, establishing that inflation
accounting was no longer required under Brazilian GAAP, as of January 1, 2001,
as long as cumulative inflation over a three-year period remains under 100%.
Therefore, since Brazil's cummulative inflation for the three-year period ended
December 31, 2001 has been under 100%, the financial statements for 2001 are
expressed in nominal reais. Financial statements for periods prior to December
31, 2001 are expressed in constant reais of December 31, 2000 purchasing power.
iii
PART I
ITEM 1. IDENTITY OF DIRECTORS, SENIOR MANAGEMENT AND ADVISERS
Not applicable.
ITEM 2. OFFER STATISTICS AND EXPECTED TIMETABLE
Not applicable.
ITEM 3. KEY INFORMATION
A. Selected Financial Data
We maintain our books and records in reais and prepare our financial
statements in accordance with Brazilian GAAP, which differs in certain respects
from U.S. GAAP. Note 25 to our financial statements, appearing elsewhere in this
annual report, sets forth a description of the principal differences between
Brazilian GAAP and U.S. GAAP as they relate to us, and a reconciliation to U.S.
GAAP of net income and total shareholders' equity.
On June 1, 2002, the partners and employees of Arthur Andersen S/C, the
former auditors of ESCELSA, joined Deloitte Touche Tohmatsu Brazil. The audit
reports for the financial statements as of December 31, 2000 and 2001 and for
each of the years in the three-year period ended December 31, 2001 included in
this annual report were issued by Deloitte Touche Tohmatsu. The selected
financial data as of December 31, 2001 and 2000 and for each of the three years
in the period ended December 31, 2001 have been derived from, and should be read
in conjunction with, our consolidated financial statements and the notes thereto
included in this annual report. The selected consolidated financial data at
December 31, 1999, 1998 and 1997 and for each of the two years in the period
ended December 31, 1998 have been derived from our audited consolidated
financial statements and the notes thereto audited by Arthur Andersen S/C that
are not included in this annual report. See "Presentation of Financial and Other
Information" for more information on the presentation of our financial data
The following table presents a summary of our selected financial data at
the dates and for each of the periods indicated. You should read the following
information together with our financial statements and the notes thereto
included elsewhere in this annual report and with "Item 5. Operating and
Financial Review and Prospects."
At and for the Year Ended December 31,
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2001 2000 1999 1998 1997
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(in thousands of reais, except per share amounts)
Statement of Operations Data:
Operating revenues:
Electricity sales to final consumers... 1,617,617 1,313,126 1,237,819 1,224,356 773,167
Electricity sales to distributors...... 83,519 42,723 39,072 22,834 24,351
Other revenues......................... 29,646 32,944 22,149 30,640 13,318
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Total................................ 1,730,782 1,388,793 1,299,040 1,277,830 810,836
Value-added taxes on sales................ (345,297) (330,229) (308,558) (298,039) (175,472)
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Net operating revenues(1)................. 1,385,485 1,058,564 990,482 979,791 635,364
Operating expenses:
Electricity purchased for resale....... (675,189) (500,139) (501,102) (424,195) (274,324)
Depreciation and amortization.......... (149,138) (140,906) (129,353) (126,337) (52,642)
Personnel.............................. (108,271) (115,014) (130,265) (138,454) (87,226)
Regulatory charges..................... (95,852) (98,233) (63,947) (58,984) (37,725)
Materials.............................. (20,964) (17,364) (22,102) (14,639) (9,726)
Third-party services................... (53,640) (55,834) (54,091) (49,490) (34,201)
Other expenses......................... (82,510) (24,061) (56,230) (38,842) (36,738)
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Total................................ (1,185,564) (951,551) (957,090) (850,941) (532,582)
Operating income (loss)................... 199,921 107,013 33,392 128,849 102,782
Financial income (expense) (2)............ (235,831) (23,499) (119,345) (90,865) 53,688
Non-operating expense, net................ (24,384) (13,325) (14,339) (18,202) (7,590)
Income tax and social contribution........ (11,012) (14,228) 69,503 118,577 (45,751)
At and for the Year Ended December 31,
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2001 2000 1999 1998 1997
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(in thousands of reais, except per share amounts)
Minority participation in (income) losses. (10,794) (3,314) 13,509 (47,013) 1,310
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Net income (loss)......................... (60,076) 52,647 (17,280) 91,346 104,439
============= ========== ========== ========== =========
Net income (loss) per share(3)............ (13.20) (11.57) (3.80) 20.07 22.95
As restated As restated As restated
Income (loss) before extraordinary item
under U.S. GAAP........................ (142,097) 12,181 (47,621) 9,483 74,727
Extraordinary item, net of tax effect
of R$5,085 in 1999 (R$11,511 in
1998) under U.S. GAAP................ - - 10,325 23,371 -
Net income (loss) under U.S. GAAP......... (142,097) 12,181 (37,296) 32,854 74,727
Basic and diluted earnings (loss) per share
under U.S. GAAP(3)..................... (31.22) 2.68 (8.20) 7.22 16.42
Approximate income (loss) per share under
U.S. GAAP before extraordinary item
per share.............................. (31.22) 2.68 (10.46) 2.09 16.42
Extraordinary item per share.............. - - 2.26 5.13 -
Balance Sheet Data:
Current Assets............................ 731,597 586,659 595,728 776,724 1,158,909
Property, plant and equipment (net)....... 2,293,555 2,270,049 2,247,062 2,154,186 1,706,633
Total assets.............................. 4,239,188 3,704,899 3,668,146 3,664,660 3,137,218
Total debt................................ 1,744,878 1,421,585 1,459,083 1,357,078 1,273,622
Shareholders' equity...................... 1,093,825 1,171,979 1,168,472 1,289,865 1,224,213
Shares outstanding at year end............ 4,550,833 4,550,833 4,550,833 4,550,833 4,550,833
Estimated shareholders' equity under
U.S. GAAP (As restated)................ 923,903 1,059,313 1,047,132 1,156,522 1,145,683
Dividends per share under Brazilian GAAP.. - - - 9.25 5.89
Dividends per share in U.S.$ under
Brazilian GAAP(4)...................... - U.S.$1.45 - U.S.$5.79 U.S.$4.00
Dividends per share under U.S.
GAAP(5)................................ - - 9.25 5.89 9.53
Other Financial Data and Ratios:
Capital expenditures...................... 181,065 180,919 214,388 229,913 112,216
Operating margin (%)(6)................... 14.43 10.11 3.37 13.15 16.18
Net cash provided by (used in):
Operating activities................... 54,398 171,051 4,517 193,149 206,893
Investing activities................... (179,284) (131,494) 2,939 (118,646) (997,792)
Financing activities................... 121,777 (42,326) (8,248) (375,899) 1,282,399
Operating Data:
Electricity sold (Gwh)
Industrial............................. 3,669 3,979 3,530 3,400 2,837
Residential............................ 2,055 2,363 2,308 2,301 1,405
Commercial............................. 1,303 1,403 1,286 1,243 768
Others............................... 1,757 1,871 1,858 1,796 1,047
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Total.................................. 8,784 9,616 8,982 8,740 6,057
Number of customers (thousands)........ 1,495 1,406 1,344 1,284 1,231
Total energy losses (in percentages)....... 11.1% 11.5% 11.6% 11.0% 9.3%
Transformer capacity (MVA)................. 4,092 4,016 3,893 3,482 2,198
Transmission lines (in kilometers)......... 10,094 9,981 9,751 9,645 2,955
Distribution lines (in kilometers)......... 88,585 83,691 81,690 79,562 32,445
Number of employees........................ 2,466 2,551 2,628 2,645 1,592
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(1) Net operating revenues represent operating revenues after value-added taxes
on sales. See "Item 5. Operating and Financial Review and Prospects--
Operating Results."
2
(2) Financial income (expense) represents income earned on investments, net of
interest expense. From 1994 until July 1997, we had less than R$2 million
of indebtedness outstanding at any time and the correspondent expense has
not been material.
(3) Earnings (loss) per share are computed under Brazilian GAAP based on the
shares outstanding at the end of each year. Under U.S. GAAP, earnings
(loss) per share is calculated based on weighted average shares
outstanding. As there were no changes in shares outstanding during the
years ended December 31, 2001, 2000, 1999, 1998 and 1997, the weighted
average shares outstanding was the same as year-end amounts.
(4) Translated from nominal reais into U.S. dollars at the commercial selling
rates in effect on the dates that distributions were declared during that
period.
(5) Dividends are recognized under Brazilian GAAP in the year to which the
income relates, although the shareholders have not yet approved them and
have the right to change the amounts. Under U.S. GAAP, dividends are
recorded when the shareholders have approved the dividend amount.
(6) Operating margin represents operating income divided by net operating
revenues.
Exchange Rates
There are two principal foreign exchange markets in Brazil:
o the commercial rate exchange market; and
o the floating rate exchange market.
Most trade and financial foreign exchange transactions, including
transactions relating to the payment of interests with respect to the notes, are
carried out on the commercial market at the applicable commercial market rate.
Purchase of foreign currencies in the commercial market may be carried out only
through a Brazilian bank authorized to buy and sell currency in that market. In
both markets, rates are freely negotiated but may be strongly influenced by
intervention by the Brazilian Central Bank, or the Central Bank.
Between March 1995 and January 1999, the Central Bank permitted the gradual
devaluation of the real against the U.S. dollar pursuant to an exchange rate
policy that established a band within which the real/U.S. dollar exchange rate
could fluctuate.
Responding to pressure on the real, on January 13, 1999, the Central Bank
widened the foreign exchange band. Because the pressure did not ease, on January
15, 1999, the Central Bank allowed the real to float. Since January 1, 1999 and
through December 31, 2000, the real depreciated by 61.8% against the U.S.
dollar, and, as of December 31, 2000, the commercial market rate for purchasing
U.S. dollars was R$1.9554 to U.S.$1.00. In the year ended December 31, 2001, the
real depreciated by 18.7% against the U.S. dollar. As of July 10, 2002, the
commercial market rate for purchasing U.S. dollars was R$2.8541 to U.S.$1.00. We
cannot assure you that the real will not appreciate or devalue substantially in
the near future. See "Item 5A. Operating and Financial Review and Prospects --
Operating Results -- Overview -- Brazilian Economic Environment."
The following table shows the commercial selling rate for U.S. dollars for
the periods and dates indicated:
Exchange Rate of Reais per U.S.$1.00
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Year Ended December 31, Low High Average(1) Period-end
- ----------------------- --- ---- ---------- ----------
1997....................................... 1.0395 1.1164 1.0787 1.1164
1998....................................... 1.1165 1.2087 1.1611 1.2087
1999....................................... 1.2078 2.1647 1.8158 1.7890
2000....................................... 1.7721 1.9847 1.8295 1.9554
2001....................................... 1.9357 2.8007 2.3442 2.3204
Month Ended Low High
- ----------- --- ----
January 31, 2002............................................................. 2.2932 2.4384
February 28, 2002............................................................ 2.3827 2.4691
March 31, 2002............................................................... 2.3236 2.3641
April 30, 2002............................................................... 2.2709 2.3689
May 31, 2002................................................................. 2.3625 2.5296
June 30, 2002................................................................ 2.5220 2.8593
July (through July 10), 2002 2.8481 2.9141
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Source: Central Bank.
(1) Represents the daily average exchange rate during each of the relevant
periods.
3
B. Capitalization and Indebtedness
Not Applicable.
C. Reasons for the Offer and Use Proceeds
Not Applicable.
D. Risk Factors
You should consider carefully all the information set forth herein and, in
particular, the special factors applicable to an investment in Brazil and to an
investment in us. In general, investing in the securities of issuers in emerging
market countries such as Brazil involves a higher degree of risk than investing
in the securities of U.S. issuers.
Risk Relating to Our Notes and Us
The tariffs that we charge for sales of electricity to final customers are
determined pursuant to the concession contracts and controlled by ANEEL;
our concession contract does not specify the factors on which price cap
reviews are based, future tariffs may adversely affect our operating
revenues and our ability to make interest or principal payments on the
notes.
We are, like all utility companies in Brazil, subject to extensive
regulation of our tariffs. The tariffs that we charge for electricity to final
customers are determined pursuant to a concession contract dated July 17, 1995,
or the ESCELSA concession contract, between ESCELSA and the Departamento
Nacional de Aguas e Energia Eletrica (the National Department of Waters and
Electric Energy, or DNAEE), which was succeeded by Agencia Nacional de Energia
Eletrica (the National Agency of Electric Power, or ANEEL), and the concession
contract dated December 4, 1997 between ENERSUL and ANEEL, or the ENERSUL
concession contract.
The ESCELSA concession contract establishes a price cap tariff mechanism
with three types of adjustments. ESCELSA may periodically apply for the first
type of adjustment (reajuste), which takes into account the effects of inflation
on ESCELSA's tariffs in order to maintain ESCELSA's economic and financial
equilibrium. The second type of adjustment (revisao extraordinaria) permits
ESCELSA to request revisions to its tariff rates from time to time, generally to
pass through significant changes in its cost structure that it does not control,
particularly (i) the cost of electricity it purchases, (ii) charges for the use
of transmission and distribution facilities and (iii) any taxes that are
created, altered or extinguished, except for taxes which are levied on income,
that affect ESCELSA's economic and financial equilibrium. In addition, ANEEL has
the right, every three years, to adjust ESCELSA's price cap (revisao periodica).
ESCELSA's concession contract does not specify the factors on which the price
cap review will be based.
Since the privatization of ESCELSA, most of the other distribution
companies, including ENERSUL, have been given new concession contracts with
tariff provisions. Under these concession contracts, the annual adjustment was
determined by a tariff adjustment formula. This formula is adjusted annually.
Although ESCELSA's concession contract does not contain the refinement of
the subsequent concession contracts, ANEEL has adjusted ESCELSA's tariffs in a
manner consistent with the terms of these later concession contracts, and for
2002 and 2003, ANEEL will apply the same tariff adjustment formula contained in
the concession contracts of the more recently privatized companies, as per
ANEEL's Resolution No. 321, of August 6, 2001. Although there can be no
assurance that ANEEL will continue to apply the formula to ESCELSA's tariffs or
that ANEEL will adjust ESCELSA's tariffs on an annual basis, ESCELSA believes
that it will not be treated differently than the other privatized distribution
companies.
Once ESCELSA's average tariff rate is set as described above, ESCELSA
submits a proposal to ANEEL regarding the apportionment of tariff rates among
the various customer classifications.
4
Subject to the terms of ESCELSA's concession contract, ANEEL has
substantial discretion to set its tariffs. There can be no assurance that
tariffs will be set at rates that allow ESCELSA to make interest or principal
payments on the notes. See "Item 4. Information on the Company -- Business
Overview -- Regulation of the Brazilian Electricity Sector," "Item 4.
Information on the Company -- Business Overview -- ESCELSA--Customers, Analysis
of Demand and Tariffs--Tariffs" and "Item 5. Operating and Financial Review and
Prospects."
We depend on key customers, the loss of any of which could affect our
results of operations.
The majority of the energy we sell is purchased by large industrial
customers. Our industrial customers are engaged in the mining, steel, pulp and
paper, chemical and port facility. For the year ended December 31, 2001, our
twelve largest industrial customers accounted for approximately 25% of our
revenues and approximately 41% of the total quantity of electricity sold by us.
Our industrial customers, in the aggregate, accounted in the year ended in
December 31, 2001, for approximately 50% of our total volume of electricity
sales and approximately 36% of our revenues. For more detailed information on
our customers, see "Item 4. Information on the Company - Customers, Analysis of
Demand and Tariffs."
Even though the loss of any one of our ten largest customers would not
individually have a material adverse effect on our net operating revenues, we
believe that the loss of all such ten customers could adversely affect our net
operating revenues, but would not have a material adverse effect on our cash
flow or on our ability to pay interest and principal on the notes, although we
cannot assure you of that. In addition, a slowdown in the manufacturing sector
could reduce the energy demands of some of our major industrial customers, which
could have a material adverse effect on our results of operations.
We may face significant competition from independent power producers and
self-generators, which may adversely affect our business and results of
operations.
ESCELSA holds the concession to distribute electricity in 70 of the 77
municipalities in Espirito Santo and ENERSUL holds the concession to distribute
electricity in 72 of the 77 municipalities in Mato Grosso do Sul. As a result of
legislation, Independent Power Producers, or IPPs, are authorized to generate
electric power, other than nuclear power, if they obtain the approval of ANEEL
(in the case of thermal plants) or successfully bid for a concession (in the
case of hydroelectric plants). The new energy generated by IPPs, unlike our
existing energy, is not subject to rate regulation and accordingly IPPs may
offer large customers rates below those which we are currently required to
charge for its existing energy. Although we believe that ANEEL would permit us
to lower our rates to compete against a lower offer from an IPP, we do not have
the right to do so and there can be no assurance that ANEEL would grant such
approval. Alternatively, we could create our own IPPs to compete with any such
IPPs. See "Item 4. Information on the Company -- Regulation of the Brazilian
Electricity Sector -- Legal and Regulatory Framework" for the definition of an
IPP and an explanation of the activities that may be conducted by IPPs.
Furthermore, distribution and transmission companies, such as ESCELSA and
ENERSUL, are required to permit the use of their facilities for the transmission
of electricity upon payment of a toll, known as a "wheeling charge," the
methodology for the determination of which has been defined by ANEEL. In
addition, any consumer may develop self-generation, although we expect that only
large consumers will consider such an investment. See "Item 4. Information on
the Company -- Regulation of the Brazilian Electricity Sector -- Legal and
Regulatory Framework" for an explanation of the activities that may be conducted
by self-generators. We cannot assure you that competition and self-generation
will not affect the prices we can charge certain large customers and, therefore,
our revenues.
Impact of an electric energy shortage may affect our business and results
of operations.
Hydroelectric power is a major source of energy for the Brazilian industry.
Low levels of investment and below average rainfall have resulted in low
reservoir levels of critical hydroelectric capacity in Brazil's southeast,
central west and northeast regions. The construction of gas-fired thermal
generation plants has been delayed due to regulatory and other issues. On May
15, 2001, the federal government created the Camara de Gestao da Crise de
Energia Eletrica, or GCE, to regulate and administer the program for reduction
of energy consumption to avoid the interruption of electricity supply. This
program, known as the Rationing Program, established limits for energy
5
consumption for industrial, commercial and residential consumers, which ranged
from a 15% to a 25% reduction in energy consumption. This reduction affects all
consumers, including large industrial and commercial consumers and
electricity-intensive users.
The government has since relaxed the rationing program and reduced the
limitation applicable to industrial consumers to 10%. In the beginning of March
2002, the government announced that the rationing program was terminated. We
cannot assure you that there will not be another energy shortage in the future
and that our revenues, EBTIDA and margins of operations will not be reduced in
that event.
There can be no assurance as to whether the maximum term to be set by ANEEL
for the compensation of ESCELSA's losses will be long enough for the full
compensation of the rationing losses. If not, the outstanding balance at the end
of the term will not be compensated at all. Thus, risks associated with
decreases in energy sales are a burden of the concessionaire under Law no.
10,438, of April 26, 2002. Moreover, this risk is aggravated by the following
other measures adopted under Law no. 10,438/02 and that will potentially
lengthen the period for tariff compensation and therefore the exposure to the
risk of not achieving full recovery:
o new criteria for the classification of low revenue residential
consumers. The new criteria is more comprehensive and entails all
residential consumers that consume less than 80 kWh/month, provided
that they are linked to a "monophasic" circuit and do not consume,
over a period of 12 consecutive months, more than 120 kWh/month in two
months, consecutive or not. As low revenue residential consumers are
exempt from the tariff increase for the compensation of rationing
losses, the greater the group of consumers that meet such criteria,
the slower is the tariff compensation and, consequently, the longer
needs to be the relevant term.
o the possible decrease of the captive market in the upcoming years is
also a potential cause for the lengthening of the term for
compensation of rationing losses. Since the relevant tariff increase
levies on the rates charged by the distribution concessionaires for
the supply (tarifas de fornecimento) of its consumers, once such
captive consumers become free ones, they will not be subject to supply
tariffs any longer, but rather to commodity prices and the use of the
distribution system tariff.
o Law No. 10,438/02 created a Universalization Program and substantially
amended the provisions on the PROINFA (program for the incentive of
alternative sources of energy) originally set under Executive Order
no. 14/01. Under the provisions inserted in such law related to both
programs, consumers that are currently considered captive consumers of
the distribution concessionaires are free to purchase energy both from
participants of PROINFA and from newcomers that win bids to supply
electric energy in areas within the concession area where the
incumbent concessionaire services have not arrived yet. Those
possibilities aggravate the risk of decrease in captive market, to the
extent that it potentially accelerates the migration of the consumers
from the captive to the free market (or to the market of someone other
than the distribution concessionaire, in the case of the
universalization program), therefore further decreasing the number of
consumers subject to the tariff increase related to the compensation
for rationing losses.
We are controlled by a few shareholders that act in concert to control all
our subsidiaries and us.
As of the date of this annual report, Iven S.A., or Iven, and GTD
Participacoes S.A., or GTD, own 52.27% and 25.00%, respectively, of our
outstanding voting shares. Iven and GTD entered into a shareholders' agreement
on July 10, 1995 pursuant to which Iven and GTD share the power to control our
operations. The shareholders' agreement expires in July 2002. If the term of the
shareholders' agreement is not extended, we will be controlled by one sole
shareholder - EDP - whose interests may differ from the noteholders'.
Our shareholders are involved in a dispute with each other that may affect
our operations.
Our shareholders' agreement will expire on July 10, 2002. On June 4, 2002,
GTD filed a lawsuit requesting the court to declare an extension of the
shareholders' agreement until the termination of the ESCELSA concession
contract. This scenario may have an impact on the decision-making capabilities
of our management, as
6
decisions requiring shareholders' unanimity may not be approved by our board of
directors. We cannot predict the outcome of the shareholders' dispute, when it
will be resolved, or the extent of the effect that it will ultimately have on
our operations.
Risks Relating to Brazil
The Brazilian government has exercised, and continues to exercise,
significant influence over the Brazilian economy. Brazilian political and
economic conditions have a direct impact on our business and the market
price of our notes.
The Brazilian government frequently intervenes in the Brazilian economy and
occasionally makes drastic changes in policy. The Brazilian government's actions
to control inflation and effect other policies have often involved wage and
price controls, currency devaluations, capital controls and limits on imports,
among other things. See "Item 5. Operating and Financial Review and Prospects --
Brazilian Economic Environment." Our business, financial condition and results
of operations may be adversely affected by changes in policy involving tariffs,
exchange controls and other matters, as well as other factors outside of our
control such as:
o currency fluctuations;
o inflation;
o price instability;
o interest rates;
o tax policy; o energy shortages; and
o other political, diplomatic, social and economic developments in or
affecting Brazil.
Inflation, and certain governmental measures to curb inflation, may
contribute significantly to economic uncertainty in Brazil and to heighten
volatility in the Brazilian securities markets.
Since the real's introduction in July 1994, Brazil's inflation rate has
been substantially lower than in previous periods. Inflation itself has, and
certain governmental measures to curb inflation have, in the past had
significant negative effects on the Brazilian economy. Inflation, actions taken
to curb inflation and public speculation about possible future actions have also
contributed to economic uncertainty in Brazil and to heightened volatility in
the Brazilian securities market. Our cash operating expenses are substantially
all in reais and tend to increase with Brazilian inflation because cost of wages
and other operating expenses generally increase accordingly to consumers'
prices. High inflation generally leads to higher domestic interest rates, and,
as a result, our cost of real-denominated debt may increase. High inflation may
adversely affect our results of operations in other ways. To the extent that the
rate of inflation exceeds the increases in rates that we are allowed to charge
our customers, our operating margins would be adversely affected. In addition,
if the rate of inflation in Brazil is lower than the rate of appreciation of the
U.S. dollar and other foreign currencies against the real, our cost in real
terms of paying interest rates on our foreign currency denominated debt would be
higher. If the Brazilian government increases interest rates in order to curb
any possible inflation, the increased interest rates could negatively affect
credit purchases by our customers.
If Brazil experiences substantial inflation again in the future, our
operating expenses and borrowing costs may increase, our profit margins may
decrease and, if investor confidence lags, the price of our notes may fall. If
economic difficulties result from or occur at the same time as inflation, then
our revenues may also be negatively affected.
7
Fluctuations in the value of the real against the value of the U.S. dollar
may result in uncertainty in the Brazilian economy and the Brazilian
securities market and could have a material adverse effect on our ability
to make payments of interest and principal on the notes.
Our ability to meet our U.S. dollar-denominated obligations is affected by
changes in the relative values of the real against the U.S. dollar. As
substantially all of our revenues are real-based, we are required to purchase
U.S. dollars in foreign exchange markets with reais to meet our U.S.
dollar-denominated obligations. Our principal U.S. dollar-denominated
obligations are our interest and principal payments on the notes and payments
for power purchased from ITAIPU (approximately 29.8% and 29.7% of the total
power purchased by ESCELSA and ENERSUL in 2001, respectively).
The devaluation of the real in 1999 did not significantly affect our
ability to meet our U.S. dollar-denominated obligations with respect to the
notes because we had paid our January 1999 interest payment before the foreign
exchange band was widened and successfully hedged our July 1999 interest
payment. However, the devaluation substantially increased the price of power we
purchased from ITAIPU. Both ESCELSA and ENERSUL received tariff adjustments to
pass through this increase to their customers during the 12-month period
beginning June 1999.
Devaluations can create additional inflationary pressures in Brazil by
generally increasing the price of imported products and requiring recessionary
government policies to curb aggregate demand. On the other hand, appreciation of
the real against the U.S. dollar may lead to a deterioration of the current
account and the balance of payments, as well as dampen export-driven growth. The
potential impact of the floating exchange rate and of measures of the Brazilian
government aimed at stabilizing the real is uncertain. See "Item 5. Operating
and Financial Review and Prospects -- Brazilian Economic Environment."
Unless we successfully hedge devaluation risk, any decrease in the value of
the real relative to the U.S. dollar could have a material adverse effect on our
ability to make payments of interest and principal on the notes. At December 31,
2001, we had no foreign currency or interest rate hedges in place in connection
with the notes. Further, although we believe that our concession contracts
should permit us to pass through to our tariffs any increase in cost of
electricity we purchase from ITAIPU, there can be no assurance in this regard.
If we are not permitted to pass through these increases, any decrease in the
value of the real relative to the U.S. dollar could have a material adverse
effect on our financial condition and results of operations.
Political risk relating to our government transition may contribute
significantly to economic uncertainty in Brazil and, therefore, have a
direct impact in our results of operations.
The volatility that the real and the Brazilian securities market have been
experiencing is mainly due to the uncertainties surrounding the next Brazilian
presidential election in October 2002. Even though the political candidates have
made efforts to demonstrate that they will comply with any agreements and
financial obligations undertaken by the public sector, the lack of confidence
from market participants has put increased pressure on the Brazilian capital
markets. There exists the possibility that the next government may implement
policies that will adversely affect us or the electric energy industry.
Developments in other emerging market countries may affect the market price
of the notes and may make it more difficult or expensive for us to obtain
additional debt financing.
Securities of Brazilian issuers have been, to varying degrees, influenced
by economic and market conditions in other emerging market countries. Although
economic conditions differ in each country, investors' reactions to developments
in one country may affect the securities of issuers in other countries,
including Brazil. Since the fourth quarter of 1997, the international financial
markets have experienced significant volatility, and a large number of market
indices, including those in Brazil, have declined significantly. For example,
the current recession in Argentina, the Asian economic crisis, and the 1998
Russian debt moratorium and devaluation of the Russian currency triggered market
volatility in Brazil's and other emerging market countries' securities markets.
The Argentine crisis may affect the perception of risk in Brazil by foreign
investors. Many people expected that similar problems would occur in Brazil,
which increased volatility in the market prices for Brazilian securities in
early 2001. However, the same problems have not materialized in Brazil.
Nonetheless, if events in Argentina
8
continue to deteriorate, they may adversely affect our ability to raise equity
capital when needed and borrow funds at an acceptable interest rate if
necessary. The market value of our notes, as well as our ability to obtain
additional debt financing on acceptable terms or at all, may be adversely
affected by events elsewhere, especially in emerging market countries.
Restrictions on the movement of capital out of Brazil may hinder the
ability of holders of the notes to receive payments on the notes.
The Brazilian government may impose temporary restrictions on the
conversion of Brazilian currency into foreign currencies and on the remittance
to foreign investors of proceeds from their investments in Brazil. Brazilian law
permits the government to impose these restrictions whenever there is a serious
imbalance in Brazil's balance of payments or there are reasons to foresee a
serious imbalance. The Brazilian government imposed remittance restrictions for
approximately six months in 1989 and early 1990.
The Central Bank has authorized the issuance of the notes and issued a
certificate of foreign capital registration authorizing us to make any payment
under the notes requiring the conversion of reais into U.S. dollars (including
any payment made upon enforcement of a judgment against us). However, additional
Central Bank authorization is needed for the payment of the notes upon
acceleration or for certain late payments of the notes generally. These exchange
control regulations generally have not affected repayment obligations of
securities of a type similar to the notes. There can, however, be no assurance
that the Brazilian government will not in the future impose more restrictive
foreign exchange regulations that would have the effect of preventing or
restricting our access to foreign currency that we may require to meet our
foreign currency obligations under foreign currency denominated liabilities
(including the notes).
ITEM 4. INFORMATION ON THE COMPANY
A. History and Development of the Company
Espirito Santo Centrais Eletricas S.A. - ESCELSA, a Brazilian corporation
(sociedade anonima) with unlimited duration, was incorporated under the laws of
Brazil on July 1, 1968, as a mixed-capital corporation (sociedade de economia
mista) with limited liability. As a Brazilian corporation, we operate generally
under the provisions of the Brazilian corporate law.
At the time of our incorporation, we were controlled by Centrais Eletricas
Brasileiras S.A. - ELETROBRAS, a company controlled by the Brazilian government.
In 1995, the Brazilian government began to liberalize, privatize and deregulate
the Brazilian electric energy sector, almost all of which was government-owned.
In July 1995, we became the first government-owned electricity company to be
privatized. In our privatization auction, 50% (plus one share) of our common
shares were acquired by Iven S.A. and GTD Participacoes S.A., with ELETROBRAS
remaining as minority shareholder until 1997. On January 19, 1996, we became a
public company, registered with the CVM, and presently our shares are traded on
the Sao Paulo stock exchange but they do not have a significant public float.
Our registered office is at Rua Sete de Setembro, 362, Centro, 29015-000
Vitoria, Espirito Santo, Brazil and our telephone number is (55-27) 3321-9000.
Our agent for service of process in the United States is CT Corporation, 111
Eight Avenue, New York, NY 10011.
In 1997, we acquired a 55.4% controlling interest (76.50% voting interest)
in ENERSUL, an electricity distribution company privatized by the state
government of Mato Grosso do Sul.
Our core business is the planning, construction and operation of systems
for electricity generation, transmission, distribution and the sale of electric
energy in the States of Espirito Santo and Mato Grosso do Sul. As a public
concessionaire of electric utility services, we are subject to regulations
established by the ANEEL, successor to the DNAEE, an agency of the Brazilian
government.
9
Capital Expenditures
We recorded capital expenditures in 2001, 2000 and 1999 of R$181.1 million,
R$180.9 million and R$214.4 million, respectively. Our investments in
distribution and transmission lines totaled R$122.8 million in 2001, as compared
to R$130.7 million in 2000 and R$163.8 million in 1999. Our investments in
expansion and modernization of our generation facilities totaled R$5.6 million
in 2001, as compared to R$18.5 million in 2000 and R$22.5 million in 1999. The
decreases in investments in our distribution, transmission and generation
facilities are related to the completion of a comprehensive program implemented
by us after our privatization in 1995. To compensate for the lack of investment
during the years prior to our privatization, we made substantial investments to
upgrade our transmission and distribution lines, which increase stability of
tension.
We have ongoing capital expenditures related to the expansion and
modernization of our transmission, distribution and existing generation
facilities. We expect to invest approximately R$71.0 million for the expansion
and modernization of our distribution lines in 2002, a portion of which may be
financed with additional indebtedness to be obtained from ELETROBRAS and BNDES,
subject, however, to the limitations contained in the indenture that governs the
notes.
B. Business Overview
General
We engage primarily in the transmission and distribution of electricity in
the States of Espirito Santo and Mato Grosso do Sul. We provided approximately
95% and 94% of the electricity distributed in 2001 in the States of Espirito
Santo and Mato Grosso do Sul, respectively. We had net operating revenues (see
"Item 3. Key Information -- Selected Financial Data" for the definition of net
operating revenues) of R$1,385.5 million, R$1,058,6 million and R$990.5 million
in 2001, 2000 and 1999, and net loss of R$60.1 million, net income of R$52.6
million and net loss of R$17.3 million in 2001, 2000 and 1999, respectively. At
December 31, 2001, we had assets totaling R$4.2 billion, and ESCELSA and ENERSUL
together had concessions for 11 hydroelectric generation plants, 10,094
kilometers of transmission lines, 4,092 MVA transformer capacity and 88,585
kilometers of distribution lines.
ESCELSA
ESCELSA engages primarily in the transmission and distribution of
electricity in the State of Espirito Santo. ESCELSA provided approximately 95%
of the electricity distributed in the State of Espirito Santo in 2000. ESCELSA
distributes electricity to 70 of the 77 municipalities that comprise the entire
State of Espirito Santo, covering an area of approximately 42,000 square
kilometers, or 90% of the geographic area of the State of Espirito Santo. In
2001, ESCELSA supplied 6,112 GWh of electricity and, as of December 31, 2001,
had approximately 922,500 customers representing nearly 2.8 million people or
approximately 94% of the total population of the State of Espirito Santo. In
2001, industrial, residential, commercial, rural and other customers, including
other distribution companies, represented 49.9%, 19.4%, 12.8%, 5.5% and 12.4%,
respectively, of ESCELSA's electricity distribution sales by volume of
electricity sold. As of December 31, 2001, ESCELSA's twelve largest industrial
customers accounted for approximately 25% of our revenues and approximately 41%
of the total amount of electricity sold by ESCELSA. ESCELSA's primary load
center is greater Vitoria, the capital of the State of Espirito Santo, which
represented 56% of ESCELSA's entire market in 2001.
ESCELSA is also engaged in the generation of electricity. All of its
generation capacity is hydroelectric. ESCELSA has the concessions for ten
hydroelectric power plants, which in 2001 generated approximately 837 GWh or
12.1% of its total energy needs. In 2001, ESCELSA purchased a total of 5,993 GWh
of electricity, of which 5,809 GWh were purchased under a long-term contract
with Furnas Centrais Eletricas S.A., or FURNAS, including 1,606 GWh produced by
ITAIPU and 184 GWh were purchased from Companhia Siderurgica de Tubarao, or CST.
10
Transmission and Distribution
General. ESCELSA transmits and distributes electricity, either generated by
it or, more commonly, purchased primarily from FURNAS and ITAIPU, to a
geographic area encompassing 90% of the State of Espirito Santo. At December 31,
2001, ESCELSA had 37,885 kilometers of power lines, composed of transmission and
distribution lines.
The following table provides certain information concerning ESCELSA's
transmission and distribution system, as of the dates presented (except for
energy loss data, which is presented for the year ended on that date):
December 31,
------------------------------------------
2001 2000 1999
------- ------- -------
Kilometers of transmission and
subtransmission lines
230 kV............................... 140 140 140
138 kV............................... 1,502 1,499 1,499
69 kV................................ 945 934 934
34.5 kV.............................. 413 413 413
Kilometers of overhead distribution lines
(11.4 kV to 13.8 kV)................. 34,885 34,345 33,813
Transformer capacity (MVA)
Transmission......................... 2,682 2,631 2,603
Distribution......................... 1,408 1,330 1,253
Total energy losses (in percentage)(1).. 10.4 9.6 9.2
--------------
(1) Technical energy losses from ESCELSA's lines and equipment occur
in the ordinary course of transmission and distribution of
electric energy; commercial losses occur as a result of illegal
connections and/or fraud.
Transmission. At December 31, 2001, ESCELSA's transmission system was
comprised of 3,000 km of transmission lines, primarily 138 kV and 69 kV. In
addition, ESCELSA had 67 transformer substations, where electric current is
transformed into lower voltages for subsequent distribution, with total
transforming capacity of 2,682 MVA. The transmission system is connected to
ESCELSA's main load center and to various connecting points with FURNAS. Of
ESCELSA's industrial and commercial customers, 15 have 69 kV or 138 kV
high-voltage electrical energy supplied through direct connections to ESCELSA's
transmission system. Such customers represented approximately 42% of ESCELSA's
total volume of electrical power sales during 2001, and approximately 26% of
ESCELSA's total revenues during that same period.
Distribution. At December 31, 2001, ESCELSA's distribution system was
composed of urban and rural distribution networks which include electric poles
carrying approximately 34,885 km of distribution lines and 33,584 distribution
transformers, with an installed transforming capacity of 1,408 MVA. ESCELSA's
distribution system consists of a widespread network of predominantly overhead
lines and substations having successively lower voltage ranges (13.8 kV and
below). Electricity is supplied to larger industrial customers at a higher
voltage and is supplied to smaller industrial, residential and commercial
customers at lower voltage ranges (13.8 kV and below).
System Performance. ESCELSA's energy losses increased to approximately
10.4% during the twelve-month period ended December 31, 2001, compared to
approximately 9.6% during the twelve-month period ended December 31, 2000 mainly
due to energy rationing. In 2000 (most recent data available), the energy losses
for all distribution companies in Brazil averaged 17.2%, as calculated by
Associacao Brasileira de Distribuidoras de Energia Eletrica (the Brazilian
Association of Distributors of Electric Energy, or ABRADEE). During the
twelve-month period ended June 30, 1995, shortly before ESCELSA was privatized,
its energy losses were 11.4%. ESCELSA has reduced its energy losses since 1995
pursuant to a comprehensive program implemented by ESCELSA after its
privatization in 1995. The program combined technical, operational, commercial
and marketing aspects with legal action. To compensate for the lack of
investment during the years prior to ESCELSA's privatization, we invested
approximately R$396 million since ESCELSA's privatization to upgrade its
transmission and distribution lines, which increases stability of tension and
reduces energy losses, thereby improving reliability. To minimize fraud, another
principal cause of energy losses, ESCELSA inspected existing electricity meters
and initiated legal proceedings against customers it believed to be engaged in
fraud. An estimated 35% of ESCELSA's
11
energy loss in 2001 occurred as a result of illegal connections and/or fraud.
The remaining 65% of ESCELSA's energy loss resulted from the operation in the
ordinary course of its transmission and distribution system.
Scheduled interruptions in ESCELSA's services to customers represented 30%
of all interruptions during 2001. Unscheduled interruptions due to accidental
causes, including lightning strikes, fire, wind and corrosion, represented 70%
of all interruptions. In 2001, we invested an additional R$68 million to
renovate and improve ESCELSA's transmission and distribution system, and we
expect to invest an additional R$71 million for such purposes in 2002.
The average duration of interruptions during the twelve months ended
December 31, 2001 was 12.96 hours per customer, representing a decrease of
approximately 6.6% from 13.87 hours per customer during the twelve months ended
December 31, 2000. Frequency of interruptions for the twelve months ended
December 31, 2001 was 11.04 interruptions per customer, representing a decrease
of approximately 12.9% from 12.67 interruptions per customer during the twelve
months ended December 31, 2000. The average time to respond to interruptions in
customer service increased from 95 minutes for the year ended December 31, 2000
to 110 minutes for the year ended December 31, 2001 due to the customers'
ability to reach ESCELSA faster in the event of interruptions in service, as a
result of the implementation of a toll free number for both urban and rural
customers.
Customers, Analysis of Demand and Tariffs
Customers. Customers of ESCELSA are classified into five principal
categories: industrial (comprising manufacturing and processing activities),
residential, commercial (including service-oriented businesses, universities and
hospitals), rural and others (primarily other distribution companies and public
and municipal services, such as street lighting). In 2001, industrial,
residential, commercial, rural and other customers represented 49.9%, 19.4%,
12.8%, 5.5% and 12.4%, respectively, of ESCELSA's electricity sales by volume of
electricity sold.
The principal industries supplied by ESCELSA during 2001 and the percentage
of the total power supplied to the customers in such industries were as follows:
mining (60%), steel (8%), pulp and paper (2%), food processing (3%) and others
(27%). In 2001, the twelve largest customers accounted for approximately 41% of
ESCELSA's energy sold by volume.
Analysis of Demand. The following table sets forth certain information
regarding ESCELSA's customers, energy sales and revenues for the periods
indicated.
Number of
Customers Year Ended December 31,
at December -------------------------------------------------------
31, 2000 2001 2000 1999
------------ ------------------ ---------------- -----------------
(in thousands of reais)
GWh R$ GWh R$ GWh R$
Industrial....................... 11,192 3,051 327,688 3,386 311,812 3,049 283,762
Residential...................... 725,908 1,186 299,310 1,386 311,505 1,373 303,757
Commercial....................... 88,637 780 149,895 845 143,444 778 130,848
Rural............................ 88,156 333 38,637 342 35,639 356 36,345
Other and miscellaneous.......... 8,514 430 60,998 490 71,714 474 65,191
ESCELSA's own consumption........ 170 10 n/a 12 n/a 12 n/a
Other concessionaires............ 2 322 33,737 319 29,221 306 29,907
------------ -------- ------- ----- ------- ----- -------
Total........................ 922,579 6,112 910,265 6,780 903,335 6,348 849,810
============ ======== ======= ===== ======== ====== =========
For the three-year period ended December 31, 2001, the compound annual
growth rate in the volume of electricity sold by ESCELSA to industrial,
residential and commercial customers was 1.3%, -0.9% and 0.7%, respectively.
During that same period, the compound annual growth rate in the volume of
electricity sold by all Brazilian electricity companies to residential,
commercial and industrial customers was -1.1%, -1% and 2.3%, respectively.
12
Tariffs. ESCELSA's customers are classified according to the voltage level
at which energy is supplied to them. High-voltage customers are classified as
"Group A" customers and low-voltage customers are classified as "Group B"
customers. In addition, Group B customers are further classified as residential,
rural, others and public lighting. According to these classifications, each
customer falls within a certain tariff classification defined by law, although
some flexibility is available according to the nature of each customer's demand.
In addition to customer-based classifications, ESCELSA's tariffs are
determined on the basis of seasonal variation and time of day. The seasonal
variation and time-of-day criteria are used for the establishment of two
separate tariff systems: (i) the conventional tariff system and (ii) the
hour-seasonal tariff system.
Conventional Tariff System -- This system does not take into account any
seasonal or time-of-day variations, and is applied both to Group A and to Group
B customers. Group A customers pay for the electricity that they purchase on the
basis of both a "capacity charge" and an "energy charge;" whereas Group B
customers pay only for energy actually consumed. The capacity charge, expressed
in reais per kW, is based on the higher of (i) contracted firm capacity and (ii)
power capacity actually used. The energy charge, expressed in reais per kWh, is
based on the amount of electricity actually consumed.
Hour-Seasonal Tariff System -- This system takes into account both seasonal
and time-of-day variations, and establishes different rates for different times
of day or different seasons in the year. Seasonal variation refers to the dry
season (May through November) and the rainy season (December through April). For
Group A customers, tariffs are higher during the dry season, when hydroelectric
generation capacity tends to be lower. Time-of-day variations refer to peak
hours of demand (any three consecutive hours between 5:00 p.m. and 10:00 p.m.,
as determined by the concessionaire, except Saturdays, Sundays or holidays
determined by federal law) and to off-peak hours of demand (all other times).
For Group A customers, electricity rates are higher during peak hours of demand.
This system only applies to Group A customers with contracted demand equal to or
in excess of 300 kW. Group A customers that are billed pursuant to the
hour-seasonal tariff system pay for both a "capacity charge" and an "energy
charge," which vary depending on the voltage at which the energy is delivered to
such customers.
The following table details the breakdown of ESCELSA's Group A and Group B
customers and sets forth the average tariff and certain other information for
2001:
Average Net Number of
Group Tariff Volume Revenue Customers
- ----- ----------------- --------- -------------------- ---------------
(R$/MWh) (%) (%)
Group A:
A2-138 kV..................... 69.97 42 26 14
A3-69 kV...................... 69.30 0 0 1
A3a-44 kV..................... 88.78 3 2 13
A4 13.8 to 2.3 kV............. 110.91 16 16 2,796
----------------- --------- -------------------- ---------------
Subtotal..................... 81.68 61 44 2,824
Group B:
B1-Residential................ 191.12 20 34 725,895
B2-Rural...................... 112.01 5 5 87,915
B3-Others..................... 175.66 10 15 105,384
B4-Public lighting............ 93.27 3 2 559
----------------- --------- -------------------- ---------------
Subtotal...................... 168.51 39 56 919,753
----------------- --------- -------------------- ---------------
Total........................... 115.11 100 100 922,577
----------------- --------- -------------------- ---------------
The tariffs charged by ESCELSA for sales of electricity to final customers
are determined pursuant to the concession contract between ESCELSA and ANEEL.
ESCELSA's concession contract establishes a price cap tariff mechanism with
three types of adjustments:
o an annual adjustment to be made in August, which takes into account
the effects of inflation on ESCELSA's tariffs in order to maintain
ESCELSA's economic and financial equilibrium (reajuste);
o extraordinary adjustments, which permit ESCELSA to request revisions
to its tariff rates from time to time, generally to pass through
significant changes in its cost structure that it does not control,
13
particularly the cost of electricity it purchases, changes in the use
of transmission and distribution facilities and any taxes that are
created, altered or extinguished, except for taxes which are levied on
income (revisao extraordinaria); and
o a three-year price cap review by ANEEL (revisao periodica).
ESCELSA's first price cap review was in July 1998, when ANEEL reduced
ESCELSA's tariffs by an average of 3.4%, lowering ESCELSA's operating revenues
by approximately R$7.8 million in 1998 and by R$32.5 million in 1999. ESCELSA's
second price cap review occurred on August 7, 2001, when ANEEL increased
ESCELSA's tariffs by 19.89% (which such percentage is temporary, pending a
determination by ANEEL in connection with the methodology for the adjustment of
the assets remuneration base which affects the final percentage of the tariff
revision). Upon the definition of the applicable methodology, which is expected
to occur by September 2002, the differences, if any, between the provisional
value and the definitive value of ESCELSA's tariff review will be adjusted in
ESCELSA's annual tariff adjustment for 2002, as provided for in ANEEL's
Resolution No. 320, of August 6, 2001.
On December 21, 2001, in order to allow for the recovery from the
consumption losses which were incurred as a result of Rationing Program, ANEEL
authorized a 2.9% extraordinary tariff increase for residential, rural and
public lighting, with the exception of low income customers, and 7.9% for all
other customer segments. The duration of the tariff increase is dependent upon
the time necessary to recover losses.
Since the privatization of ESCELSA, most of the other distribution
companies, including ENERSUL, have been given new concession contracts with
tariff provisions. Under these concession contracts, the annual adjustment was
determined by a tariff adjustment formula. The formula is adjusted annually.
The numerator of this formula is comprised of two components: (i) VPA
(Parcel A Value), which corresponds to a part of the distribution company's
revenues related to costs that the distribution company does not control and
should, therefore, be permitted to pass through to its final customer, including
(a) RGR (Global Reserve Fund), (b) CCC (Fuel Compensation Account), (c) charges
on the financial compensation for the exploitation of hydric resources for
purposes of power generation, (d) inspection tax of the services of electric
energy (TFSEE), and (e) charges for the use of transmission and distribution
network, and (ii) VPB (Parcel B Value), which relates to the remaining value of
the revenues of the distribution company, excluding the value-added tax, after
deducting the amount corresponding to the Parcel A Value that is adjusted to
protect the utility companies against the effects of inflation.
Although ESCELSA's concession contract does not contain the readjustment
formula provided for in the subsequent concession contracts, as a result of the
second price cap review of ESCELSA's tariffs in August 2001, ANEEL issued
Resolution No. 321, dated August 6, 2001, in which it defined the mechanism of
adjustments of ESCELSA's tariffs for 2002 and 2003, by adopting the same tariff
adjustment formula contained in the concession contracts of the more recently
privatized companies.
The more recent concession contracts also state that ANEEL's price cap
review will take into account efficiency gains achieved by the distribution
company, a comparison of the distribution company's tariff with tariffs of
foreign companies and similar companies within the domestic scenario and changes
to the cost and market structures of the distribution company. This adjustment
is known as the X factor. The X factor is intended to permit ANEEL to adjust
tariffs so that consumers may share in the distribution company's realization of
increased operating efficiencies. As a result, a distribution company may not be
able to retain all of the efficiencies and savings achieved by it on a
going-forward basis. The revision based on the X factor is entirely within
ANEEL's discretion. ANEEL has not provided any further clarification as to how
it intends to apply the enumerated elements to revise the X factor nor has it
given any indication as to what percentage of any efficiency gains may be
retained by the distribution company and what percentage should be passed on to
its customers. ESCELSA is subject to an X factor review every three years. On
August 7, 2001, ANEEL set the X factor at 1.89% per year, which represents the
percentage discount to be applied to the IGP-M index, which is used to adjust
our managed cost compensation for the 2002 and 2003 tariff adjustments.
14
Once ESCELSA's average tariff rate is determined subject to the three
criteria set forth in its concession agreement, and ANEEL's Resolution No. 321,
dated August 6, 2001, ESCELSA submits a proposal to ANEEL regarding the
apportionment of tariff rates among the various customer classifications.
There can be no assurance that tariffs will be set at rates that allow us
to make interest or principal payments on the notes. See "-- Regulation of the
Brazilian Electricity Sector" and "Item 5. Operating and Financial Review and
Prospects."
Commercial Arrangements. ESCELSA has entered into contracts, which are
based on general conditions set forth in ruling (Portaria) No. 466 of November
12, 1997. These contracts contain minimum demand clauses that require the
customer to pay for either contracted demand or, if greater, actual capacity
used. These contracts have durations of three or five years, with automatic
renewals for equal durations, subject to notice 12 and 18 months, respectively,
prior to expiration of the term. Other contracts have three-year terms, with
perpetual rolling one-year renewals. Each such contract is subject to
termination on approximately 1-1/2 years notice (if the contract is not
terminated, it automatically extends for one additional year). While,
historically, none of these contracts has been terminated, there can be no
assurance that these contracts will be renewed in the future, particularly given
the threat of competition by IPPs for industrial customers. If any significant
customers fail to renew or terminate their contracts, ESCELSA would be entitled,
pursuant to Law No. 9,648 of May 27, 1998, to immediately reduce its purchases
from FURNAS by a corresponding volume of electricity. Customers with whom
ESCELSA maintained such contracts during 2001 represented approximately 55% of
its sales of electricity (measured in MWh) and 37% of its revenues during the
period. We believe that these contracts provide us with a relatively stable
source of revenue.
On November 29, 2000, ANEEL issued Resolution No. 456, which updated and
consolidated general supply conditions. This resolution replaced Resolution No.
466 November 12, 1997. In the absence of an agreement between the parties on the
term of the supply contracts, the term is 12 months or, if there is a need for
capital expenditures by the concessionaire, 24 months. Provided the customer
does not object, the contract may be automatically renewed for the same period
of time in successive terms, with prior notice of at least 180 days before the
contract's expiration date.
Billing Procedures. The procedure for billing and payment for electricity
supplied is determined by customer category. ESCELSA's industrial customers are
billed on the day of reading, with payment required within five days of the
invoice date. ESCELSA's residential customers are billed within two days of
reading, with payment required within ten days after the invoice date. Meter
readings take place on a monthly basis. Bills are prepared from meter readings
or on the basis of estimated usage. The billing dates of ESCELSA's customers are
staggered throughout each calendar month. ESCELSA may suspend delivery of
electricity to customers if the customer's bill is overdue, within 15 days after
notification is sent to the customer. However, since the services provided by
the distribution company are considered essential services, there are some court
decisions which consider the suspension of delivery of electricity unlawful,
pursuant to the Brazilian Consumer Defense Code. Therefore, we may not be able
to suspend our services if a court decision prohibits us from doing so. In the
event of late payment of electricity bills, when customers are not subject to
other measures set forth by applicable law, a fine of up to 2% will be charged
on the total invoice overdue.
Purchases of Electricity
ESCELSA's electricity purchases from FURNAS and ITAIPU represented
approximately 96.9% of its total purchases volume in 2001. In the year ended
December 31, 2001, ESCELSA purchased 4,068 GWh of electricity from FURNAS, 1,741
GWh from ITAIPU (billed by FURNAS), and 184 GWh from CST. ESCELSA is one of the
15 electricity companies in the South, Southeast and Midwest regions of Brazil
that are required by Law No. 5,899 dated July 5, 1973 to purchase from ITAIPU a
portion of all of ITAIPU's energy purchased by Brazil under a treaty with
Paraguay dated April 26, 1973 based on their respective market shares of the
South, Southeast and Midwest regions taken as a whole. For the year ended 2001,
ESCELSA was obligated to purchase approximately 2.5% of energy purchased by
Brazil from ITAIPU, which amount has been fixed by legislation. To defray the
costs associated with the borrowing incurred to pay for the ITAIPU project, the
concessionaires in Brazil's South-Southeast-Midwest interconnected power system,
including ESCELSA, are required to purchase ITAIPU's energy at U.S.
dollar-indexed rates fixed to cover operating expenses and payments of principal
and interest on such
15
borrowing and the costs of transmitting such power to their concession area. As
a result, the average rates for the purchase of power produced by ITAIPU have
been above the national average for bulk supply of power. As ESCELSA's power
needs increase, power supplied by ITAIPU is expected to represent a smaller
percentage thereof. See "-- Regulation of the Brazilian Electricity Sector."
The following table shows ESCELSA's cost basis for energy purchased from
ITAIPU, FURNAS and CST in 2001:
Capacity Energy Wheeling
Charge Charge Charge Average
---------- -------- -------- --------
(R$/kW) (R$/MWh) (R$/kW) (R$/MWh)
ITAIPU......................... 46.87 - 1.96 85,59
FURNAS......................... 3.13 40.60 3.61 64.07
CST............................ - 24.26 - 31.99
--------
Weighted Average............... - - - 80.21
========
The following table shows the total electricity (i) generated or purchased
by ESCELSA and (ii) sold to final customers and other concessionaires during the
periods indicated:
Year Ended December 31,
----------------------------
Suppliers 2001 2000 1999
- --------- -------- -------- --------
(in GWh)
Electricity generated by ESCELSA.......................... 837 1,056 854
Electricity purchased from ITAIPU......................... 1,606 1,766 1,768
Electricity purchased from FURNAS......................... 4,203 4,281 4,163
Electricity purchased from CST/Samarco.................... 184 396 201
Electricity delivered to final consumers.................. 6,790 6,461 6,042
Electricity delivered to other concessionaires............ 322 319 306
In October 1999, ESCELSA entered into initial contracts with the Operador
Nacional do Sistema (National System Operator), or ONS, which coordinates and
controls the electric energy generation and transmission in the interconnected
system, including the planning and scheduling of the optimization of the
interconnected electro-energetic systems and the contracting and management of
electric energy transmission services and their respective access conditions,
for the transmission of electricity and connection to the interconnected power
system and ESCELSA and FURNAS are currently operating under an initial contract
for the purchase of electricity that was executed in the third quarter of 2000.
See "Regulation of the Brazilian Electricity Sector." The initial contract with
FURNAS, the terms of which are mandated by Law No. 9,648 of 1998, sets forth
ESCELSA's obligations to purchase certain amounts of electricity generated by
FURNAS, at tariffs set by ANEEL.
ESCELSA's generation capacity has no bearing on its commitment to purchase
energy generated by ITAIPU; as far as non-ITAIPU energy sold by FURNAS,
ESCELSA's commitment may be reduced by the amount of ESCELSA's generation
capacity increases. Therefore, if ESCELSA were to increase its generation
capacity in accordance with approvals received from ANEEL, required purchase
amounts from FURNAS would be reduced accordingly. If ESCELSA were to require
energy purchases in an amount greater than those established in the ESCELSA
initial contracts, however, FURNAS' obligation to supply such energy would be
contingent on availability. ESCELSA also has the right to immediately reduce
purchases from FURNAS if a free customer terminates its contract with ESCELSA in
the same proportion.
The tariffs for electricity generated by ITAIPU are established in
accordance with a treaty between Brazil and Paraguay dated April 26, 1973 and
are denominated in U.S. dollars, while the tariffs for electricity generated by
FURNAS are established pursuant to regulations implemented by ANEEL and are
denominated in reais. ESCELSA's purchases of electricity generated by ITAIPU are
paid for on the basis of a capacity charge (as well as a charge for
transmission). ESCELSA's purchases of electricity generated by FURNAS and other
concessionaires are paid for on the basis of both a capacity charge and an
energy charge. See "-- Regulation of the Brazilian Electricity Sector --
Tariffs." Capacity charges for ITAIPU are indexed to U.S. dollars and converted
on the date payment is made into reais at the exchange rate published by the
Central Bank for the previous day. The devaluation of
16
Brazil's currency relative to the prevailing rates of inflation affects the
price of power generated by ITAIPU, which constituted approximately 31.6% of the
total power purchased by ESCELSA in 2000. Although ESCELSA believes that its
concession contract should permit it to pass through to its tariffs any increase
in cost of electricity it purchases limited to the value that limits the
pass-through by the distribution companies to their captive market of the costs
and gains related to the acquisition of electric energy, there can be no
assurance in this regard. See "Item 3. Key Information -- Risk Factors."
Generation
ESCELSA holds the concession for 10 hydroelectric power plants in the State
of Espirito Santo. The total installed capacity of the hydroelectric plants is
approximately 190 MW. ESCELSA generated 837 GWh in 2001. The following table
sets forth certain information concerning ESCELSA's power plants.
Installed 2001
Hydroelectric Plants Capacity Output
-------------------- ------------ --------
(MW) (GWh)
Mascarenhas...................... 131.0 629
Suica............................ 30.6 125
Rio Bonito....................... 13.8 50
Jucu............................. 4.4 8
Others........................... 9.9 25
------------ --------
Total..................... 189.7 837
ENERSUL
ENERSUL engages primarily in the transmission and distribution of
electricity in the State of Mato Grosso do Sul. ENERSUL provided approximately
94% of the electricity distributed in the State of Mato Grosso do Sul in 2001.
ENERSUL distributes electricity to 72 of the 77 municipalities that comprise the
entire State of Mato Grosso do Sul, covering an area of approximately 329,270
square kilometers, or 92% of the geographic area of the State of Mato Grosso do
Sul. In 2001, ENERSUL supplied 2,672 GWh of electricity and, as of December 31,
2001, it had 572,323 customers, representing nearly 1.9 million people, or
approximately 95% of the total population of the State of Mato Grosso do Sul. In
2001, residential, industrial, commercial, rural and other customers, including
other distribution companies, represented 32.5%, 23.1%, 19.6%, 9.4% and 15.4%,
respectively, of ENERSUL's electricity distribution sales by volume of
electricity sold. ENERSUL's ten largest customers accounted for 10.8% by volume
of ENERSUL's electricity distribution sales in 2001. ENERSUL's primary load
center is Campo Grande, the capital of the State of Mato Grosso do Sul, which
represented approximately 35.6% of ENERSUL's entire market in 2001.
ENERSUL is also engaged in the generation of electricity. Its generation
capacity is both hydroelectric and thermal. ENERSUL operates 7 power plants,
which in 2001 generated approximately 229 GWh or 7.5% of its total energy needs.
In 2001, ENERSUL purchased a total of 2,833 GWh of electricity, of which 2,618
GWh were purchased under a long-term contract with Centrais Geradoras do Sul do
Brasil S.A., or GERASUL, including 713 GWh produced by ITAIPU and 215 GWh from
other distribution companies.
On November 19, 1997, Magistra Participacoes S.A., a wholly owned
subsidiary of ESCELSA, paid R$825.9 million to acquire 76.5% and 41.8% of the
common and preferred shares, respectively, of ENERSUL.
Transmission and Distribution
General. ENERSUL transmits and distributes electricity, purchased primarily
from GERASUL and ITAIPU, to a geographic area encompassing 92% of the State of
Mato Grosso do Sul. At December 31, 2001, ENERSUL had approximately 60,794
kilometers of power lines, composed of transmission and distribution lines.
The following table provides certain information concerning ENERSUL's
transmission and distribution system, as of the dates presented (except for
energy loss data, which is presented for the year ended on that date):
17
December 31,
-----------------------------------------
2001 2000 1999
------------- ------------- -------------
Kilometers of transmission and subtransmission lines:
138 kV........................................... 2,749 2,721 2,707
69 kV............................................ 486 485 485
34.5 kV.......................................... 3,859 3,786 3,570
Kilometers of overhead distribution lines:
(11.4 kV to 22 kV)............................... 53,700 49,346 47,956
Transformer capacity (MVA):
Transmission.......................................... 1,410 1,385 1,353
Distribution.......................................... 1,799 1,549 1,510
Total energy losses (in percentage)(1)................ 12.7 15.8 17.1
-------------
(1) Technical energy losses from ENERSUL's lines and equipment occur
in the ordinary course of transmission and distribution of
electric energy; commercial losses occur as a result of illegal
connections and/or fraud.
Transmission. At December 31, 2001, ENERSUL's transmission system was
comprised of 7,094 km of transmission lines, primarily 138, 69 and 34.5 kV. In
addition, ENERSUL had 92 transformer substations, where electric current is
transformed into lower voltages for subsequent distribution, with total
transforming capacity of 1,410 MVA. The transmission system is connected to
ENERSUL's main load center, and to various connecting points with GERASUL. Of
ENERSUL's industrial and commercial customers, seven have 69 kV or 138 kV
high-voltage electrical energy supplied through direct connections to ENERSUL's
transmission system. Such customers represented approximately 9% of ENERSUL's
total volume of electrical power sales during 2001, and approximately 4% of
ENERSUL's total revenues during that year.
Distribution. At December 31, 2001, ENERSUL's distribution system was
composed of urban and rural distribution networks which include electric poles
carrying approximately 53,700 km of distribution lines and 44,598 distribution
transformers, with an installed transforming capacity of 1,799 MVA. ENERSUL's
distribution system consists of a widespread network of predominantly overhead
lines and substations having successively lower voltage ranges (13.8 kV and
below). Electricity is supplied to larger industrial customers at a higher
voltage and is supplied to smaller industrial, residential and commercial
customers at lower voltage ranges (13.8 kV and below). ENERSUL's primary load
center, Campo Grande, represents 35.6% of ENERSUL's entire market.
Customers, Analysis of Demand and Tariffs
Customers. ENERSUL's customers are classified into five principal
categories: residential, industrial (comprising manufacturing and processing
activities), commercial (including service-oriented businesses, universities and
hospitals), rural and others (primarily other distribution companies and public
and municipal services, such as street lighting). In 2001, residential,
industrial, commercial, rural and other customers represented 32.5%, 23.1%,
19.6%, 9.4% and 15.4%, respectively, of ENERSUL's electricity sales by volume of
electricity sold.
In 2001, the ten largest customers accounted for approximately 12.5% of
ENERSUL's energy sold by volume.
Analysis of Demand. The following table sets forth certain information
regarding ENERSUL's customers, energy sales and revenues for the periods
indicated in thousands of reais at December 31, 2001 purchasing power.
Year ended December 31,
Naumber of --------------------------------------------------------
Customers 2001 2000 1999
at December ---------------- ---------------- -----------------
31, 2001 GWh R$ GWh R$ GWh R$
-----------
Residential......................... 469,893 869 190,345 977 196,855 935 193,519
Industrial.......................... 4,731 618 71,890 593 64,132 481 56,311
Commercial.......................... 51,653 523 100,512 558 98,022 509 88,580
Rural............................... 39,969 251 29,985 266 27,983 262 26,183
Other and miscellaneous............. 5,886 380 49,824 411 50,141 411 48,384
18
ENERSUL's own consumption........... 188 6 n/a 6 n/a 8 n/a
Wholesale........................... 3 25 49,782 25 13,502 28 9,673
------- ------- ------- ----- -------- ----- --------
Total............................... 572,323 2,672 492,338 2,836 450,635 2,634 422,650
For the three-year period ended December 31, 2001, the compound annual
growth rate in the volume of electricity sold by ENERSUL to residential,
industrial and commercial customers was -1.5%, 9.9% and 2.9%, respectively.
During that same period, the compound annual growth rate in the volume of
electricity sold by all Brazilian electricity companies to residential,
industrial and commercial customers was -2.4%, -0.6% and 2.3%, respectively.
Tariffs. ENERSUL's customers are classified according to the voltage level
at which energy is supplied to them. In addition to customer-based
classifications, ENERSUL's tariffs are determined on the basis of two factors:
(i) seasonal variation and (ii) time of day. For a more detailed description,
see "-- ESCELSA -- Customers, Analysis of Demand and Tariffs -- Tariffs."
The following table details the breakdown of ENERSUL's Group A and Group B
customers and sets forth the average tariff and certain other information for
2001.
Average Net Number of
Group Tariff Volume Revenue Customers
- ----- ------------------ ---------- --------------------- --------------
(R$/MWh) (%) (%)
Group A:
A2-138 kV..................... 53.06 9 4 5
A3-69 kV...................... 48.08 - - 2
A3a-34.5 kV................... 104.46 6 5 256
A4-13.8 to 22 kV.............. 107.93 23 18 1,694
------------------ ---------- --------------------- --------------
Subtotal................... 94.02 38 27 1,957
Group B:
B1-Residential................ 177.44 33 42 469,885
B2-Rural...................... 113.39 7 6 39,775
B3-Others..................... 178.45 17 22 60,606
B4-Public lighting............ 93.30 5 3 97
------------------ ---------- --------------------- --------------
Subtotal.................. 164.33 62 73 570,363
------------------ ---------- --------------------- --------------
Total..................... 137.05 100 100 572,320
================== ========== ===================== ==============
The tariffs charged by ENERSUL for sales of electricity to final customers
are determined pursuant to the ENERSUL's concession contract, which establishes
a price cap tariff mechanism comprised of three types of adjustments:
o an annual adjustment made in April, which takes into account the
effects of inflation on ENERSUL's tariffs in order to maintain
ENERSUL's economic and financial equilibrium (reajuste);
o extraordinary adjustments, which permit ENERSUL to request revisions
to its tariff rates from time to time, generally to pass through
significant changes in its cost structure that it does not control,
particularly the cost of electricity it purchases, changes in the use
of transmission and distribution facilities and any taxes that are
created, altered or extinguished, except for taxes which are levied on
income (revisao extraordinaria); and
o a five-year price cap review by ANEEL (revisao periodica).
The first five-year revision of ENERSUL's tariffs will occur in April 2003.
On April 7, 2001, ANEEL established a 18.24% tariff increase, of which
approximately 13.24% meant to cover costs such as social security taxes, the RGR
fund, the CCC, COFINS account and purchases of electricity. On December 21,
2001, in order to compensate for losses related to the Rationing Program, ANEEL
authorized a 2.9% extraordinary tariff increase for residential and low-tension
rural customers and 7.9% for all other segments, except for low-income
customers. The duration of the tariff increase is depended upon the time
necessary for ENERSUL to recover losses.
19
Commercial Arrangements. ENERSUL has entered into contracts, which are
based on general conditions set forth in Portaria No. 466 of November 12, 1997,
with 344 hour-seasonal customers. These contracts contain minimum demand clauses
which require the customer to pay for either contracted demand or, if greater,
actual capacity used. Contracts have durations of three years, with no automatic
renewals. Tariffs are set pursuant to ENERSUL's concession contract with ANEEL.
While, historically, none of these contracts has been terminated, there can be
no assurance that these contracts will be renewed in the future, particularly
given the threat of competition by IPPs for industrial customers. If any
significant customers fail to renew or terminate their contracts, ENERSUL would
be entitled, pursuant to Law No. 9,648 of 1998, to immediately reduce its
purchases from GERASUL by a corresponding volume of electricity. Customers with
whom ENERSUL maintained such contracts during 2001 represented approximately 24%
of its sales of electricity (measured in MWh) and 14% of its revenues such
period.
On November 29, 2000, ANEEL issued Resolution No. 456, which updated and
consolidated general supply conditions. This resolution replaced Resolution No.
466 of November 1997. In the absence of an agreement between the parties
regarding the term for the supply contracts, such term will be 12 months or, in
the event there is a need for capital expenditures by the concessionaire, 24
months. Provided the customer does not object, the contract may be automatically
renewed for the same period of time in successive terms, with prior notice of at
least 180 days before the contract's expiration date.
Billing Procedures. The procedure for billing and payment for electricity
supplied is determined by customer category. ENERSUL's industrial customers are
billed on the day of reading, with payment required within five days of the
invoice date. ENERSUL's residential customers are billed within two days of
reading, with payment required within ten days after the invoice date. Meter
readings take place on a monthly basis. Bills are prepared from meter readings
or on the basis of estimated usage. The billing dates of ENERSUL's customers are
staggered throughout each calendar month. ENERSUL may suspend delivery of
electricity to customers if the customer's bill is overdue, within 15 days after
notification is sent to the customer. However, since the services provided by
the distribution companies are considered essential services, courts have
decided that the suspension of delivery of electricity by distribution companies
is unlawful under the Brazilian Consumer Defense Code. In the event of late
payment of electricity bills, when customers are not subject to other measures
set forth by applicable law, a fine of up to 2% will be charged on the total
invoice overdue.
Purchases of Electricity
ENERSUL's electricity purchases from GERASUL and ITAIPU represented
approximately 92.4% by volume of its total purchases in 2001. In the year ended
December 31, 2001, ENERSUL purchased 1,905 GWh of electricity from GERASUL, 713
GWh from ITAIPU (billed by Empresa Transmissora de Energia Eletrica do Sul do
Brasil S.A.-ELETROSUL, or ELETROSUL, and 215 GWh from other distribution
companies. ENERSUL is also required by Law No. 5,899/73 to purchase from ITAIPU
a portion of all of ITAIPU's energy purchased by Brazil under a treaty with
Paraguay dated April 26, 1973. For the year ended 2001, ENERSUL was obliged to
purchase approximately 1.0% of such energy, which amount has been fixed by
legislation. See "-- ESCELSA -- Purchases of Electricity" and "-- Regulation of
the Brazilian Electricity Sector." As ENERSUL's power needs increase, power
supplied by ITAIPU is expected to represent a smaller percentage thereof.
The following table shows ENERSUL's cost basis for energy purchased from
ITAIPU, GERASUL and ELETROSUL in 2001:
Capacity Energy Wheeling
Charge Charge Charge Average
-------- -------- --------- --------
(R$/kW) (R$/MWh) (R$/kW) (R$/MWh)
ITAIPU........................ 46.87 - 1.96 84.99
GERASUL....................... 2.15 31.77 - 44.96
ELETROSUL..................... - - 3.61 17.74
--------
Weighted Average.............. - - - 70.47
========
The following table shows the total electricity (i) generated or purchased
by ENERSUL and (ii) sold to final customers and other concessionaires during the
periods specified:
20
Year Ended December 31,
----------------------------
2001 2000 1999
- ------------------------------------------------ --------- --------- --------
Electricity generated by ENERSUL................ 229 222 222
Electricity purchased from ITAIPU............... 713 720 713
Electricity purchased from GERASUL.............. 1,905 2,202 2,026
Electricity purchased from CESP................. 81 95 101
Electricity purchased from other power plants... 134 131 117
Electricity delivered to final consumers........ 3,062 2,811 2,606
Electricity delivered to other concessionaires.. 25 25 28
In August 1998, ENERSUL entered into initial contracts with GERASUL and
Companhia Paranaense de Energia-COPEL, or COPEL, to purchase electricity and
with ELETROSUL for the transmission of electricity and connection to the
interconnected power system. See "Regulation of the Brazilian Electricity
Sector." These initial contracts, the terms of which are mandated by federal
law, set forth ENERSUL's obligations to purchase certain amounts of electricity
generated by GERASUL and COPEL, at tariffs set by ANEEL.
ENERSUL's generation capacity has no bearing on its commitment to purchase
energy generated by ITAIPU; as far as non-ITAIPU energy sold by GERASUL,
ENERSUL's commitment may be reduced by the amount of ENERSUL's generation
capacity increases. Therefore, if, in any given year, ENERSUL were to increase
its generation capacity in accordance with approvals received from ANEEL,
required purchase amounts from GERASUL would be reduced accordingly. ENERSUL
also has the right to immediately reduce purchases from GERASUL if a large
customer terminates its contract with ENERSUL in the same proportion.
Generation
Currently, ENERSUL's electricity generation, transmission and distribution
operations are vertically integrated into and directly operated by ENERSUL.
However, pursuant to ENERSUL's concession contract and in accordance with
certain changes in the regulatory framework of the Brazilian electricity sector,
ENERSUL has created ENERSUL Geracao S.A., a wholly owned subsidiary of ENERSUL,
to which it will transfer all of its generation assets. According to ANEEL's
rules, the transfer of ENERSUL's generation assets to ENERSUL Energia S.A. must
be completed by October 2002.
ENERSUL currently operates four hydroelectric power plants and three
thermal plants in the State of Mato Grosso do Sul. The total installed capacity
of the power plants is 43.9 MW. ENERSUL generated 229 GWh in 2001. ENERSUL was
granted an authorization by ANEEL to produce and sell energy through the
installation of a 237.5 MW thermal plant near the city of Campo Grande (UTE
Campo Grande). The Campo Grande thermal plant was included in the Brazilian
Priority Thermoelectric Program, a federal government program aimed at
increasing the electricity supply in Brazil by more than 15,000 MW through the
installation of 49 thermoelectric plants in 18 Brazilian states by the end of
2004, which will benefit from gas supply for a 20-year period and financial
support from BNDES, the Brazilian federal development bank. Such natural
gas-fired plant is expected to receive gas from the Bolivia-Brazil pipeline. We
expect that the cost to construct the plant, which is expected to be financed
through a project finance that is still being studied, will be approximately
U.S.$150 million and that the plant will be operational by the end of 2004.
21
The beginning of construction of this plant is dependent upon the
definition of various regulatory matters including the granting of subsidies for
the purchase of natural gas which is used for the production of thermal
electricity.
The following table sets forth certain information concerning ENERSUL's
power plants.
Installed 2001
Hydroelectric and Thermal Plants Capacity Output
-------------------------------- -------------- -----------
(MW) (GWh)
UHE Mimoso(1)........................... 29.5 195
UTE Corumba(2).......................... 6.0 14
UTE Coxim(2)............................ 3.0 9
UTE Porto Murtinho(2)................... 3.7 10
Others.................................. 1.7 1
-------------- -----------
Total.............................. 43.9 229
--------------
(1) Hydroelectric.
(2) Thermal.
Competition
ESCELSA holds the concession to distribute electricity in 70 of the 77
municipalities in Espirito Santo and ENERSUL holds the concession to distribute
electricity in 72 of the 77 municipalities in Mato Grosso do Sul. IPPs are
authorized to generate electric power, other than nuclear power, if they obtain
the approval of ANEEL (for thermal plants) or successfully bid for a concession
(for hydroelectric plants). The new energy generated by IPPs, unlike our
existing energy, is not subject to rate regulation and accordingly IPPs may
offer large customers rates below those which we are currently required to
charge for our existing energy. Although we believe that ANEEL would permit us
to lower our rates to compete against a lower offer from an IPP, we do not have
the right to do so and there can be no assurance that ANEEL would grant such
approval. Alternatively, we could create our own IPPs to compete with any such
IPPs. See "-- Regulation of the Brazilian Electricity Sector -- Legal and
Regulatory Framework" for the definition of an IPP and an explanation of the
activities that may be conducted by IPPs.
Furthermore, distribution and transmission companies, such as ESCELSA and
ENERSUL, are required to permit the use of their facilities for the transmission
of electricity upon payment of a toll, known as a "wheeling charge," the
methodology for the determination of which has been defined by ANEEL. In
addition, any consumer may develop self-generation, although we expect that only
large consumers will consider such an investment. See "-- Regulation of the
Brazilian Electricity Sector -- Legal and Regulatory Framework" for an
explanation of the activities that may be conducted by self-generators.
As a result, large consumers of electricity now have significant
alternatives to purchasing power other than from us. We expect that competition
and self-generation may adversely affect the prices we can charge certain large
customers and, therefore, our revenues.
ESCELSA currently has ten customers with demand greater than 10MW that are
supplied at a voltage level equal to or greater than 69kV and, as a result,
constitute large customers entitled to buy from IPPs or any electric energy
services concession, permission and authorization holders under Law No.
9,074/95. Such customers represented approximately 35% of ESCELSA's total volume
of electrical power sales during 2001, and approximately 23% of ESCELSA's total
revenues during that year.
Although there can be no assurance in this regard, ENERSUL believes
competition will not have a material adverse effect on its results of operations
and financial condition because ENERSUL currently has only two customers with
demand greater than 10MW that are supplied at a voltage level equal to or
greater than 69kV and, as a result, constitute large customers entitled to buy
from IPPs or any electric energy services concession, permission and
authorization holders under Law No. 9,074/95. Such customers represented
approximately 5.7% of ENERSUL's total volume of electrical power sales during
2001, and approximately 2.2% of ENERSUL's total revenues during that year.
22
Raw Material
ESCELSA uses water as its primary source to produce energy. ENERSUL owns
and operates three thermoelectric plants, each of which consumes fuel oil. Fuel
oil consumption for the year ended December 31, 2001 represented an expense of
approximately R$7.0 million, of which approximately R$6.0 was reimbursed to us
by the CCC account (an account created in 1973 to generate financial reserves to
cover fossil fuel costs in thermal power plants in the event of a rainfall
shortage which would require increased use of thermal plants).
Seasonality
Our sales of energy are subject to variations depending on the seasons of
the year, since consumers spend more energy in some seasons that in others.
Because these variations are systematic and already accounted for in our monthly
plans of sales of energy, our results of operations are not affected by the
seasonality.
Concessions
A concessionaire has certain rights and obligations as a result of
receiving a concession. Concessionaires for generation have the duty to produce
and supply electric energy. Concessionaires for transmission and distribution
have the duty to provide transmission and distribution services within their
concession area at applicable rates to whoever requests these services. We
believe that we are in material compliance with its obligations under our
concessions.
In addition, concessionaires, among other things:
o may only charge tariffs which have been approved by ANEEL;
o may not transfer, assign, pledge or sell properties and facilities
used by the concessionaires to perform their duties under their
concessions without the prior consent of ANEEL;
o must operate their facilities in accordance with technical rules
established by ANEEL;
o may not cease providing electricity services which are the subject of
their concessions other than for non-payment of invoices after the
consumer has been notified thereof; and
o must, at the end of the concession period, in the event of non-renewal
of their concessions, allow all property and facilities used in
connection with the concessions to revert to the Brazilian government
against payment of book value of the assets (see note 18 to our
financial statements) to the concessionaires. See "-- Regulation of
the Brazilian Electricity Sector."
Our existing distribution concessions were granted pursuant to the
concession contracts. Pursuant to the ESCELSA's concession contract, ESCELSA was
granted the right to supply electricity in each of the applicable municipalities
through the year 2025. ESCELSA also currently owns ten generation plants
pursuant to concessions that were granted through the year 2025. Pursuant to the
ENERSUL's concession contract, ENERSUL was granted the right to supply
electricity in each of the applicable municipalities through the year 2027 and
to produce electricity through ten hydroelectric which are not required to hold
a concession due to their reduced total installed capacity. ENERSUL also
currently owns one generation plant (Mimoso) pursuant to a concession that was
granted through the year 2027. In the years of their expirations, the concession
contracts may be renewed, at the discretion of the regulatory authorities, for
an additional 30 years.
According to the terms of the concession contracts, and the Concessions
Law, a concession contract may be terminated due to the occurrence of the
following events: (1) forfeiture (i) if service is being rendered inadequately
or deficiently, based on the rules, criteria, indices and parameters defining
service quality, (ii) for failure to comply with the provisions of law,
regulations or the terms of the concession contract, (iii) for failure to
provide service, except in the event of an act of God or force majeure, (iv) if
the concessionaire no longer has the economic, technical or operating conditions
to maintain an adequate level of services, (v) for failure to timely comply with
any
23
penalties imposed in the event of any infractions, (vi) for failure to respond
to notification by the authorities to regularize service rendering, (vii) if the
concessionaire is sentenced by final and unappealable decision for tax evasion,
including social contribution, (2) the bankruptcy or liquidation of the
concessionaire, (3) annulment due to illegalities found in the bidding
procedures or in the award of the bid, (4) expropriation for reasons of public
interest ("encampacao"), (5) rescission of the contract by the concessionaire in
the case of non-compliance with the contractual provisions by the granting
authority through a specific lawsuit filed for this purpose; and (6) expiration
of the term of the contract. In the case of forfeiture, the concessionaire is
entitled to notification, a right to cure and due process. In the event of a
expropriation, forfeiture and the expiration of the term of the contract, we
would be entitled to be paid the portion corresponding to the investments
attached to revertible assets not yet amortized or depreciated which have been
made for the sole purpose of assuring the continuity and improvement of the
service, less contractual penalties and damages caused by the concessionaire in
case of forfeiture. See "-- Regulation of the Brazilian Electricity Sector." The
revocation of the concessions for one of its municipalities would not
automatically revoke its concessions for other municipalities. We are also
subject to penalties and fines imposed by ANEEL under certain circumstances. See
"-- Regulation of the Brazilian Electricity Sector."
Regulation of the Brazilian Electricity Sector
General
The electricity industry in Brazil is regulated by the Brazilian
government, acting through the Ministry of Mines and Energy, which has exclusive
authority over the electricity sector through regulatory powers assigned to it.
Federal Law No. 9,427, dated December 26, 1996, or Law No. 9,427, created ANEEL,
an independent regulatory agency which replaced and assumed all of the duties
and responsibilities of DNAEE, that was responsible for the implementation of
the regulatory policy for the electricity sector. According to this law, ANEEL
was entitled to delegate the performance of complementary activities of
regulation, control and inspection to agencies located in several states of
Brazil, through the execution of cooperation agreements. Some activities,
however, are not subject to delegation, as for example the establishment of
tariffs.
ANEEL is mainly responsible for (i) implementing and regulating the
exploitation of electric energy and the use of hydroelectric power pursuant to
Law No. 9,074, dated July 7, 1995; (ii) promoting the bidding process for the
granting of new generation, transmission and distribution concessions, as well
as the bidding process relating to the granting of concessions for the use of
hydroelectric power potentials; (iii) solving administrative disputes among
utilities, IPP companies, self-producers and customers; (iv) determining the
criteria for the establishment of the cost of the transmission of energy
pursuant to Law No. 9,074, dated July 7, 1995; (v) executing and supervising the
concession and permission agreements, use of public good concession agreements,
and issuing the authorizations and inspecting, directly or through cooperation
agreements executed with state agencies, the electric energy services; (vi)
setting, together with the fossil fuels and natural gas agencies, the parameters
for fixing the transport prices of such fuels; (vii) establishing limits,
restrictions and conditions for the transfer and obtaining of concessions,
permissions and authorizations among electric energy sector agents with a view
at fostering competition among such agents; and (viii) establishing and fixing
administrative penalties to be imposed to concessionaires, permissionaires and
authorization holders.
Legal and Regulatory Framework
The Brazilian electricity sector is undergoing some changes in connection
with the plans of the Brazilian government to stimulate investment and increase
competition in the sector. Legislation enacted in 1995 created a new framework
for the granting of concessions in general, and for the power sector in
particular. The most relevant of these laws and regulations are Law No. 8,987,
dated February 13, 1995, Law No. 9,074, dated July 7, 1995, and Decree No.
1,717, dated November 24, 1995. On September 10, 1996, the Brazilian government
approved Federal Decree No. 2,003/96 specifically regulating the generation of
electric energy by IPPs and self-generators.
Law No. 9,074/95 introduced the concept of the IPP as a means to open up
the electricity sector to private investment. An IPP is a legal entity or
consortium holding a concession or authorization for power generation for sale
to (i) public electric energy providers, (ii) certain large industrial and
commercial consumers, (iii) consumers who have not been supplied by the local
distribution concessionaire for more than 180 days, (iv) certain other consumers
upon previous agreement with the local distribution concessionaire, (v) existing
consumers with demand
24
of at least 10 MW and supplied at a voltage level equal to or greater than 69kV
and (vi) new consumers with demand of at least 3 MW at a voltage level equal to
or greater than 69kV. Self-generators may, upon ANEEL's prior approval, (i) give
or exchange energy with other self-generators within a consortium, (ii) sell
excess energy to the local distribution concessionaire, and (iii) exchange
energy with the local distribution concessionaire to allow for consumption by
industrial plants of the self-generators located somewhere other than in the
area of generation.
In 1997, the results of a study on the electricity sector reform done by a
consortium of independent consultants appointed by the Ministry of Mines and
Energy became public. The primary objective of the reform is to allow the
Brazilian government to focus on its roles as policy-maker and regulator and to
permit the transfer of responsibility for operations and investment to the
private sector. The consultants proposed a new competitive trading model,
central to which is the creation of a wholesale energy market, or MAE, that
would replace the present system of regulated generation prices and tolling
supply contracts. It also proposed the creation of a new entity that would be
responsible for the operational planning, administration of generation and
transmission and planning of transmission investment in the electric sector (or
the ONS). In response, Law No. 9,648 dated May 27, 1998 was passed, providing
the legal foundation for the MAE and the ONS. The ONS is responsible for the
coordination and control of the operation of the electricity generation and
transmission systems in the interconnected systems. One of the main goals of the
ONS is to guarantee that all participants of the electricity sector have access
to the Brazilian transmission network on a non-discriminatory basis.
Upon its creation, the MAE was a self-regulatory body responsible for the
operation of the wholesale energy market and for ensuring that purchases of
energy in the short-term market are settled and cleared in an efficient manner.
Participants in the MAE are subject to rules contained in the charter of the MAE
and to applicable ANEEL regulations, including ANEEL's Resolution No. 290, dated
August 3, 2000, that sets forth the rules for the MAE. Those parties that must
participate in the MAE include (i) generation companies having installed
generation capacity of 50 MW or more; (ii) energy retailers, including
distribution companies, having sold 300 GWh or more during the prior year; and
(iii) importers or exporters of energy having an available capacity of 50 MW or
more. Both ESCELSA and ENERSUL are mandatory participants in the MAE. In
addition, certain other entities have the option to participate in the MAE.
Energy supply contracts, which must be based on the standard form agreement for
use in the MAE that was approved by ANEEL in January 1999, must be registered
with the MAE. Distributors and energy retailers must evidence, through
registration, their compliance with the requirement that 85% of their
contractual obligations to final customers be covered by long-term energy supply
contracts entered into with generation companies. Registration of energy
contracts with the MAE is also designed to ensure that generation companies do
not commit to supplying more than their maximum available capacity as set by
ANEEL.
Through the enactment of ANEEL Resolutions No. 160, 161 and 162, all dated
April 20, 2001, ANEEL has provided for its intervention in the MAE, by
introducing significant changes in MAE's charter, which was executed by its
participants and further homologated by ANEEL Resolution No. 18, of January 28,
1999. Such Resolutions aimed at modifying the operations structure of the MAE,
establishing rules for the setting of penalties to agents in case of
non-compliance with their obligations undertaken with the MAE, as well as for
the posting of financial guarantees, and transforming the current role of ASMAE
(MAE Services Manager) as the Market Services Agent Manager, by granting it
specific attributions.
During the electric energy crisis that occurred in 2001, the federal
government, through the enactment of Provisional Measure No. 2,147 dated May 15,
2001, created the Chamber for Managing the Energy Crisis (Camara de Gestao da
Crise de Energia Eletrica - GCE). Among its attributions, the CGE created the
Committee for Revitalization of the Electric Energy Model (through CGE
Resolution No. 18 dated June 22, 2001) which duties were to address proposals
aiming at adjusting failures and recommending improvements for the electric
energy sector. One of the proposals presented was the restructuring of the MAE.
According to Provisional Measure No. 29 dated February 7, 2002, converted into
Law No. 10,433 dated April 24, 2002, the MAE is now subject to ANEEL's
authorization, inspection and regularization.
The guidelines for computation of the spot price for energy in the MAE have
been homologated by Resolution No. 290. The spot price is determined by market
conditions and by certain public policy and operational considerations,
including the optimal use of resources, transmission bottlenecks, the costs of
an energy deficit, the self-restraint of customers caused by a high spot price,
projected energy requirements and international alternative
25
markets. Prevailing spot prices vary in each of the several sub-markets within
the wholesale energy market. Sub-markets are defined by the MAE and take into
account restrictions in transmission capacity.
Pursuant to Law No. 9,648, during a transition period between 1998 to 2005,
the purchase and sale of electric energy between generation and distribution
concessionaires should be contracted through the execution of the so-called
"initial contracts," based on prevailing market prices. In addition, the
purchase and sale of electric energy should be contracted separately to the
access to the transmission and distribution grids. Like existing agreements, the
initial contracts are primarily "take or pay" commitments that will guarantee
stable energy prices for distribution companies and a steady stream of income
for generation companies. By 2002, initial contracts will have fixed energy and
capacity volumes as the ones defined for the preceding year. Beginning 2003 and
ending on 2005, the volumes will be reduced at a rate of 25% per year. As the
energy and capacity volumes covered by the initial contracts are reduced,
private generation companies and distribution companies will be free to
negotiate with any other market participant for the uncovered energy at market
prices. According to Law No. 10,438 dated April 26, 2002, generation companies
under the federal government control will negotiate at least 50% of the total of
the energy traded by them, including the reduced portion of the initial
contracts in public auctions to be regularized by ANEEL. The initial contracts
expire at the end of 2005, at which time all energy will be freely negotiated.
Also, in accordance with Law No. 9,648, generation and transmission
activities and assets owned by the four federal generating companies should be
segregated by the creation of subsidiaries to which such activities and assets
should be contributed. In addition, in order to create competition and avoid
economic concentration in services and activities in the Brazilian electricity
sector, ANEEL issued Resolution No. 278, dated July 19, 2000, that establishes
self-dealing and cross-ownership limits and conditions for the participation of
companies and their respective shareholders in the generation, distribution and
commercialization of electric energy in Brazil.
On May 10, 1999, the Ministry of Mines and Energy published Portaria No.
150, creating the Comite Coordenador do Planejamento da Expansao dos Sistemas
Eletricos (the Coordinating Committee for Planning the Expansion of the Electric
Systems, or CCPE), which replaced the Grupo Coordenador de Planejamento dos
Sistemas Eletricos (the Coordinating Committee for Planning the Electric
Systems, or GCPS) in January 2000. CCPE has assumed the responsibility of
preparing a Ten-Year Expansion Plan each year (the first one under its
responsibility is the 2001/2010 Plan). The Ten-Year Expansion Plan sets forth
the expansion program for a ten-year period. The plan takes into account
projections of growth in demand in the regional markets and provides a technical
and economic appraisal of the projects proposed to meet forecast demand.
Tariffs
Until March 1993, nationwide tariffs both for the generating companies and
for distribution companies were set by the DNAEE by reference to the average
costs of the whole electricity sector. Tariffs were subject to significant
fluctuations in real terms over the period from 1975 to 1993, as the Brazilian
government maintained tariff increases at rates below the rate of inflation as
an anti-inflationary measure.
In 1971, legislation was enacted creating the "global reserve for reversion
quota," or the RGR fund, a reserve fund controlled by ELETROBRAS designed to
provide funds for compensation to concessionaires upon the loss of their
concessions and to finance projects in the electricity sector. Electric
companies are required to contribute to the RGR fund each month at an annual
rate of 2.5% of "Revertible Assets" (fixed and deferred assets, less accumulated
depreciation or amortization and certain other specified amounts), limited to 3%
of net operating revenues. Pursuant to Law No. 9,648, as amended by Law No.
10,438/02, concessionaires are required to contribute to the RGR fund until the
end of 2010. As of 1998, through the enactment of Law No. 9,648, IPPs that
produce hydroelectric energy were also required to contribute 2.5% of their
annual revenue to a fund controlled by ELETROBRAS called Uso de Bem Publico, or
UBP, over a five-year period, counted from the date of the signing of the
concession contract, which has the same purposes as the RGR fund. The UBP will
be paid to the account of ELETROBRAS until December 31, 2002 and thereafter the
UBP shall be paid to the National Treasury. Concessionaires that are
unsuccessful in renewing their concessions are entitled to receive a payment
representing the book value of their Revertible Assets. In recent years,
virtually no concessions have been denied renewal and therefore the RGR funds
have been used principally to finance new generation, transmission, distribution
and rural electrification projects and conservation.
26
On March 4, 1993, Law No. 8,631 was approved, abolishing nationwide uniform
tariffs and allowing each concessionaire to set its own tariffs, with the
approval of ANEEL (and previously DNAEE), based on such concessionaire's own
costs ("cost plus").
Law No. 8,631 allowed for an initial tariff to be set for a period of three
years, with monthly adjustments of tariffs under a formula that included the
prevailing exchange rate, general price index and interest rate and was specific
to each utility. However, upon the application of the criteria for such
calculation, the Brazilian government found that the tariffs would need to be
subject to a major increase which would have fueled a further rise in inflation
rates. Accordingly, in May 1993 the Brazilian government decided that the price
increases necessary to reach the tariff calculated in accordance with Law No.
8,631 would be gradual and would bring tariffs (on a monthly basis over a
six-month period) to the levels of September 1992 (in real terms).
On this basis, between May and October 1993, generators (other than
ITAIPU), increased their tariffs at a rate of 8.77% per month in real terms
while distribution companies increased their tariffs at a rate of 8% per month
in real terms over the same period. From November 1993 to March 1994, the new
tariffs were adjusted in accordance with the parametric formula; however,
tariffs were frozen as of June 1994 as a result of the implementation of the
Real Plan, which provided that any adjustments made to electricity rates must be
made in accordance with the rules set by the Ministry of Finance. Tariffs were
frozen from June 1994 until November 1995.
As of the enactment of Law No. 8,987/95, the system through which the
tariffs were set was modified. The system in use is the "price cap" tariff
instead of "cost plus" tariff previously adopted. Pursuant to the new system,
the tariffs are determined by the price of the winning bid which precedes the
granting of the concession or in the contract which extends the concession term
or in the contract arising out of privatization or by a specific act of ANEEL
which authorizes the application of values resulting from the reversion or
tariff adjustments
ANEEL Resolution No. 233, of July 29, 1999, established the so-called
"Valor Nominativo," which is the price above which distribution companies have
limited ability to pass through the cost of purchased or self-generated
electricity to final consumers. The "Valor Nominativo" is currently regulated by
Resolution No. 248, dated May 6, 2002 from ANEEL.
Since their respective privatizations in July 1995 and November 1997, rates
of ESCELSA and ENERSUL, have been fixed pursuant to their concession contracts
and the rules in connection therewith established pursuant to the Concessions
Law and Law No. 9,427/96. See "ESCELSA -- Customers, Analysis of Demand and
Tariffs -- Tariffs" and "ENERSUL -- Customers, Analysis of Demand and Tariffs --
Tariffs."
C. Organizational Structure
As of December 31, 2001, ESCELSA had a (i) 100% stake in Magistra
Participacoes S.A., which is the controlling shareholder of ENERSUL, (ii) 97%
stake in TV a Cabo Vitoria S.A. -- TVIX, a pay TV company which was incorporated
in July 1997, and (iii) 100% stake in ESCELSA Participacoes S.A. -- ESCELSAPAR,
which is an Internet service provider and provider of various services in the
area of technology information. All such companies are organized under the laws
of Brazil.
D. Property, Plants and Equipment
Our principal properties consist of hydroelectric generation plants,
transmission lines, substations and distribution networks, all of which are
located in the States of Espirito Santo and Mato Grosso do Sul. The net book
value of our total plant, property and equipment at December 31, 2001 was R$2.3
billion. At December 31, 2001, we had concessions for 11 hydroelectric
generation plants, 10,094 km of transmission lines, 4,092 MVA transformer
capacity and 88,585 km of distribution lines. Apart from the distribution and
transmission network, no single property produces more than 10% of our total
revenues. We have rights of way for its transmission and distribution lines.
These rights of way are our assets and do not revert to the landowner upon
expiration of the concession.
We own 62 administrative properties and 165 warehouses. Our headquarters
building is owned by ESCELSA. There are encumbrances on certain of our
properties in connection with labor lawsuits; however, such encumbrances are not
material to our ability to conduct our current business. Pursuant to Brazilian
law, certain
27
other properties and facilities used by us to perform our duties under the
concession contracts cannot be transferred, assigned, pledged, sold or
encumbered by a creditor of ours without prior approval from ANEEL.
We have ongoing capital expenditures related to the expansion and
modernization of our transmission, distribution and existing generation
facilities. We expect to invest approximately R$71 million in the expansion and
modernization of our distribution lines in 2002, a portion of which may be
financed with additional indebtedness to be obtained from ELETROBRAS and BNDES,
subject, however, to the limitations contained in the indenture that governs the
notes.
Environment and Resettlement
Our distribution, transmission and generation activities are subject to
comprehensive federal and state legislation relating to the preservation of the
environment. In the context of potential expansion of our distribution,
transmission and generation activities, the procedure for constructing
generation plants and the installation of new distribution and transmission
lines or substations, requires compliance with a number of environmental
safeguards in accordance with the Brazilian constitution and related federal
legislation. First, environmental impact studies are prepared by outside experts
who make recommendations as to how to minimize the impact of such construction
on the environment, except in the case of the installation of transmission lines
that will operate at a voltage level under 230 kV, and certain other projects,
which only require authorization from the Brazilian environmental regulatory
agency, known as IBAMA. The environmental impact study or IBAMA authorization,
as the case may be, must then be submitted to federal and state government
authorities for analysis and approval. Once approved, the project goes through a
three-stage licensing process, which includes a license to (i) begin
construction, (ii) complete the project, and (iii) operate the hydroelectric
plant, transmission lines or substations.
In addition, we are mandated by law to devote 0.5% of the total cost of any
investment in new hydroelectric plants to environmental preservation, through
the creation of environmental preservation areas. We also have a policy of
implementing programs to encourage conservation of electricity in order to
minimize the environmental impact of our ongoing operations. We are not aware of
any costs or liabilities relating to environmental matters which would have a
material adverse effect on our financial condition or results of operations.
Although the Brazilian government grants concessions to construct
hydroelectric plants, it does not grant title to the land underlying the
projects. Areas required for the implementation of hydroelectric projects are
expropriated by the Brazilian government pursuant to specific legislation. The
entities awarded concessions to construct such plants negotiate with the
communities regarding their relocation to other areas and with individual owners
occupying the land to be affected regarding the compensation to be paid to such
individual owners. If the concessionaire and landowners cannot agree on a price
for the land or right of way, a court-appointed expert will determine the fair
market value.
Insurance
We maintain insurance for losses resulting from fire at our various
substations and power plants, and for equipment losses during transportation. We
do not have insurance coverage for business interruption risk because we do not
believe that the high premiums are justified by the risk of major interruption,
considering the energy available in the interconnected power systems in Brazil.
Our management believes that we maintain insurance that is customary in Brazil
for the type of business in which we are engaged.
ITEM 5. OPERATING AND FINANCIAL REVIEW AND PROSPECTS
Overview
We had net operating revenues of R$1,385.5 million, R$1,058.6 million and
R$990.5 million in 2001, 2000 and 1999, respectively and net losses of R$60.1
million, net income of R$52.6 million and net losses of R$17.3 million in 2001,
2000 and 1999, respectively. On November 25, 1997, we acquired a 55.4%
controlling interest (76.5% voting interest) in ENERSUL. The results of
operations of ENERSUL have been included in our consolidated results of
operations since November 25, 1997.
28
Discussion of Critical Accounting Policies
In connection with the preparation of the financial statements included in
this annual report, we have relied on estimates and assumptions derived from
historical experience and various other factors that we deemed reasonable and
relevant. Although we review these estimates and assumptions in the ordinary
course of business, the portrayal of our financial condition and results of
operation often requires our management to make judgments regarding the effects
of matters that are inherently uncertain on the carrying value of our assets and
liabilities. Actual results may differ from those estimated under different
variables, assumptions or conditions. Note 3 to our financial statements
includes a summary of the significant accounting policies and methods used in
the preparation of our financial statements. In order to provide an
understanding about how management forms its judgments about future events,
including the variables and assumptions underlying the estimates, and the
sensitivity of those judgments to different variables and conditions, we have
included below a brief discussion of the more significant accounting policies
and methods used by us.
General
The following discussion should be read in conjunction with our financial
statements included elsewhere in this annual report. Our financial statements
are prepared in accordance with Brazilian GAAP, which differs in certain
significant respects from U.S. GAAP. Note 25 to our financial statements
describes the principal differences between Brazilian GAAP and U.S. GAAP as they
relate to us, and a reconciliation to U.S. GAAP of net income and shareholders'
equity. See "Item 3. Key Information--Selected Financial Data."
Revenue Recognition
Revenue for all services is recognized when earned. Billing for
residential, industrial and commercial customers is performed monthly. Unbilled
revenues from the billing date to month-end are estimated and recognized as
revenue during the month in which the service was provided. Revenues from
electricity sales to the final consumers are recognized when earned. Billings
for these sales are made on a monthly basis throughout the month. Unbilled
revenues from the billing cycle up to the end of each month are estimated based
on the prior month's billing and are accrued at the end of the month.
Differences between estimated and actual unbilled revenues, which have not been
significant, are recognized in the following month. Value added tax, or VAT,
which is a state tax due on the sales to the final consumers, is billed to the
consumers and recorded as part of gross revenue. The VAT payable to the state is
recorded as deduction of the gross revenue in a separate line in the statement
of income to disclose the net operating revenues.
Property, Plant and Equipment
Property, plant and equipment are stated at acquisition or construction
cost, monetarily restated under the constant currency method through December
31, 2001. Depreciation is computed on the straight-line method at the following
annual rates: thermoelectric plants - 5%; distribution facilities - 4%; and
hydroelectric generation, transmission and other facilities - 3%. Since January
1, 1998, we adopted the depreciation rates established by ANEEL in Resolutions
No. 2/97 and 44/99, using an average rate of 4.5% and 4.6% for ESCELSA and
ENERSUL, respectively. The interest charges, monetary variations and exchange
differences accrued on loans and financing relating to construction work in
progress are capitalized. Interest on the shareholders' equity portion of the
financing of electric energy-related construction work in progress is also
capitalized at the Taxa de Juros de Longo Prazo, the Brazilian long-term
interest rate, or TJLP, but limited to 10% per year through December 31, 1997.
From January 1, 1998 to December 31, 2001, the TJLP was used. The corresponding
amount is credited directly to a capital reserve. During 2000, we, and our
subsidiaries did not capitalize interest on shareholders' equity. When the
assets are placed in service, such charges, as from January 1, 1996, are
depreciated at the rates applicable to each related class of assets.
Deferred Taxes
We recognize deferred tax assets and liabilities based on the differences
between the financial statement carrying amounts and the tax basis of assets and
liabilities. We regularly review the deferred tax assets for recoverability and
establish a valuation allowance, as required, based on historical taxable
income, projected future
29
taxable income, and the expected timing of the reversals of existing temporary
differences. Although the realization of net deferred tax assets is not assured,
our management believes that, except where a valuation allowance has been
provided, such realization is more likely than not to occur. The amount of
deferred tax asset considered realizable could, however, be reduced if estimates
of future taxable income during the tax loss carry-forwards period are reduced.
Reserves for Contingencies
We are currently involved in certain legal proceedings. As discussed in
Note 17 to our financial statements, we have accrued our estimate of the
probable costs for the resolution of these claims. This estimate has been
developed in consultation with outside legal counsel handling our defense in
these matters and is based upon an analysis of potential results, assuming a
combination of litigation and settlement strategies. We do not believe these
proceedings will have a material adverse effect on our financial position. It is
possible, however, that future results of operations could be materially
affected by changes in our assumptions, and the effectiveness of our strategies
with respect to these proceedings.
Allowance for Doubtful Accounts
We record an allowance for doubtful accounts at an amount estimated by
management as sufficient to cover presently foreseeable losses.
The allowance for doubtful accounts is estimated considering the following
procedures:
o 100% of reserve on amounts past due over 90 days for residential
customers;
o 100% of reserve on amounts past due over 180 days for commercial
customers; and
o 100% of reserve on amounts past due over 360 days for other customers.
We continuously monitor collections and payments from customers and review
and refine the estimation process.
Regulation
Low levels of investment and below average rainfall in 2000 and early 2001,
as well as growth in demand for energy, resulted in abnormally low water levels
of critical hydroelectric capacity in Brazil's southeast, central west and
northeast regions. In May 2001, the Brazilian federal government announced
several measures in response to these conditions. These measures included:
o the creation of the Camara de Gestao da Crise de Energia Eletrica
(Energy Crisis Committee, or CGE) which determined that certain
electricity distributors, including us, suspend distribution of
electricity to new customers (except residential and rural customers)
and for certain non-essential purposes such as nighttime sporting
events and advertising use, and reduce distribution for the
illumination of public areas by 35%,
o the reduction of the federal government's electricity consumption by
35% beginning July 1, 2001,
o power rationing measures to be imposed on industrial, commercial and
residential customers in the most industrialized and heavily populated
areas of Brazil beginning on June 1, 2001. These measures required
most residential consumers to reduce their electricity consumption by
one-fifth of the average consumption in May, June and July 2000.
Industrial and commercial consumers also had to reduce their
consumption by 15% to 25% of the average consumption during the same
period, and
30
o the payment of bonuses to residential consumers whose energy
consumption was lower than the requisite target and power cuts and
surcharges to be imposed on consumers whose energy consumption
exceeded the requisite target.
The power rationing measures ultimately ceased on March 1, 2002.
On October 17, 2001, the Brazilian federal government, through Executive
Act No. 4, subsequently approved by Law No. 10,310 of November 22, 2001,
established that electric utilities, including us, would be reimbursed for
expenses associated with payment of bonuses to consumers and other costs related
to the Rationing Program that exceeded the surcharges. The CGE established
through CGE Resolution No. 65, of November 6, 2001, the procedures and deadlines
relating to such reimbursement. ANEEL is responsible for the inspection of the
special account created for such purposes.
Provisional Measure No. 14, of December 12, 2001, further converted into
Law No. 10, 438, of April 26, 2002, provides that electric power distribution
companies in Brazil, such as us, will be compensated for revenue losses caused
by the reduction in amounts of energy sold due to the Rationing Program.
Compensation would be made by means of an increase in the energy rate applicable
to future power sales (2.9% for residential, rural and public lighting, except
for low income customers and 7.9% for all other customer segments) and companies
would be entitled to use this increased rate only up to the maximum compensation
term to be set by ANEEL and provided that the nationwide weighted average of
such term for all distribution companies does not exceed 72 months. However, in
order to have this rights assured, the distribution concessionaire should adhere
to the so called Electric Energy Sector Agreement, which comprises a number of
actions to be taken by each concessionaire, including but not limited to waivers
of certain rights that they are entitled pursuant to applicable law (including,
inter alia, requests, either in the administrative or judicial spheres, future
or ongoing, for compensation in relation to Parcel A costs amounts accrued from
the date of execution of the concession contract to October 26, 2001; requests,
either in the administrative or judicial spheres, future or ongoing, for
extraordinary tariff reviews associated to facts occurred from the execution
date of the concession contract to December 31, 2001; requests, either in the
administrative or judicial spheres, future or ongoing, for recovery, of any
nature, of revenues associated with the rationing program, etc), execution of
agreements to settle disputes with electricity generators regarding energy
supply during the Rationing Program and amendments to the initial contracts.
ESCELSA and ENERSUL have adhered to the Electric Energy Sector Agreement.
Provisional Measure No. 14, of December 12, 2001, further converted into
Law No. 10,438, of April 26, 2002 further provides for BNDES to lend the
distribution companies an amount equivalent to up to 90% of their lost revenues
so that these companies would be able to maintain their account balances
basically as if no rationing program had taken place. On February 15, 2002 we
secured a line of credit with BNDES under the provisions of Law no. 10,438/02 in
the aggregate amount of R$212.4 million (of which R$41.8 million and R$22.0
million have been disbursed to ESCELSA and ENERSUL, respectively). The loan
provides for repayment in 12 monthly installments and it accrues interest of 1%
per annum over the SELIC rate. Our obligations under this line of credits are
secured by billing receivables for electricity services provided by us. The
remaining tranches of the loan will be withdrawn upon the approval by ANEEL of
the amount of losses for which we will be entitled to be reimbursed. We expect
ANEEL to establish such amount by no later than August 2002. This loan would
then be re-paid to BNDES using revenue obtained from the sale of energy to
consumers at the increased rate. See note 26 to our financial statements.
Provisional Measure No. 14, of December 12, 2001, further converted into
Law No. 10,438, of April 26, 2002 also encompasses the Parcel A costs which are
certain costs that each distribution company is permitted to defer and pass
through to its customers via a future rate adjustment. Parcel A costs are
limited by the concession contracts to the cost of purchased power and certain
other costs and taxes. ANEEL had granted rate increases to recover a portion of
previously deferred Parcel A costs. However, due to uncertainty surrounding the
Brazilian economy, ANEEL had been denying approval of Parcel A rate increases.
Provisional Measure No. 2,227, of September 4, 2001 provided a tracking account
mechanism, further regulated by Ordinance No. 296, of October 25, 2001, issued
jointly by the Ministry of Economy and Ministry of Mines and Energy, further
replaced by Ordinance No. 25, of January 24, 2002, to record the variation in
the Parcel A costs for rate adjustment calculation purposes. Parcel A costs
incurred previous to January 1, 2001 are not recoverable thought the tracking
account. As a result, we
31
have not recognized any regulatory asset for Parcel A costs incurred prior to
2001 (see note 4 to our financial statements).
As a result of various actions taken by the federal government and ANEEL in
2001, we are subject to the provisions of Statement of Financial Accounting
Standards No. 71, "Accounting for the Effects of Certain Types of Regulation"
because the rate-setting structure in Brazil is now designed to provide for
recovery of our allowable costs incurred as a result of the Rationing Program.
Accordingly, we capitalize incurred costs as deferred regulatory assets when
there is a probable expectation that future revenue equal to the costs incurred
will be billed and collected as a direct result of the inclusion of the costs in
an increased rate set by the regulator. The deferred regulatory asset is
eliminated when we collect the related costs through billings to customers.
ANEEL performs a rate adjustment on an annual basis. If ANEEL excludes all or
part of a cost from recovery, that portion of the deferred regulatory asset is
impaired and is accordingly reduced to the extent of the excluded cost. ESCELSA
and ENERSUL have recorded deferred regulatory assets of R$392 million at
December 31, 2001, we expect to pass through to our customers in accordance with
and subject to regulatory provisions. The regulatory assets include R$214
million and R$94 million at December 31, 2001, for recovery of lost revenues due
to rationing and Parcel A costs incurred in 2001, respectively. In addition, we
recorded deferred regulatory assets for the cost of energy traded on the spot
market (energy not traded pursuant to contracts during the rationing period)
("free energy") in the amount of R$84 million.
Brazilian Economic Environment
The Brazilian economy has been characterized by frequent and occasionally
drastic intervention by the Brazilian government and by volatile economic
cycles. The Brazilian government has often changed monetary, taxation, credit,
tariff and other policies to influence the course of Brazil's economy. For
example, the Brazilian government has the authority, when a serious imbalance in
Brazil's balance of payment occurs, to impose restrictions on the remittance to
foreign investors of the proceeds of their investments in Brazil, and on the
conversion of Brazilian currency into foreign currencies. Furthermore, in late
September 1999, a court in the state of Minas Gerais ruled that the
representatives of the board of directors of the minority foreign private
partners of Companhia Energetica de Minas Gerais, a privatized electric utility
in that state, could no longer have veto power over corporate actions. Also in
late September 1999, Brazil's Federal Supreme Court ruled that pension taxes on
retired federal employees and pensioners, as well as the increase of pension
taxes charged to active employees, were unconstitutional. Changes in monetary,
taxation, credit, tariff and other policies could adversely affect our business,
as could inflation, currency and interest rate fluctuations, social instability
and other political, economic or diplomatic developments, as well as the
Brazilian government's response to such developments.
Rapid changes in Brazilian political and economic conditions that have
already occurred and that might continue will require continued emphasis on
assessing the risks associated with our activities and adjusting our business
and operating strategy. Future developments in Brazilian government policies,
including changes in the current policy and incentives adopted for financing the
export of Brazilian goods, or in the Brazilian economy, over which we have no
control, may materially adversely affect our business. See "Item 3D. Risk
Factors--Risks Relating to Brazil."
Brazilian economic conditions may be affected negatively by events
elsewhere, especially in emerging markets. For instance, the Argentine
government's default on certain of its debt obligations, the devaluation of the
Argentine peso and the terrorist attacks of September 11, 2001 present causes
for concern relating to Brazil's economic stability. Instability in the
Brazilian financial markets caused by developments in the international
financial markets may adversely affect our financial condition and,
specifically, our ability to raise capital when needed. See "Item 3D. Risk
Factors--Risks Relating to Brazil."
The Brazilian government has proposed a broad tax reform in Brazil, mainly
designed to reduce public deficit through the increase in tax collection. It is
expected that the final tax reform bill will be submitted to the Brazilian
Congress for approval before the coming Presidential elections in 2002. It is
anticipated that the reform will include the creation of a VAT on goods and
services which would replace six existing taxes (including the contribution for
social purposes, the federal tax on industrial products and the state tax on the
circulation of goods and services). In addition, the Contribuicao Provisoria
sobre Movimentacao Financeira-CPMF, a provisional levy
32
on checking account transactions, would be replaced by a permanent federal tax
on financial transfers. We may have a higher tax burden if the tax reform bill
is approved and implemented. See "Item 3D. Risk Factors."
In the last quarter of 2000 and the first quarter of 2001, the real has
come under increasing pressure and in nominal terms has devalued by 6.1% and
10.5% against the U.S. dollar in each of those two periods, respectively.
Our ability to meet our dollar-denominated obligations is affected by
changes in the relative values of the real and the U.S. dollar. Our revenues are
real-denominated and some of the costs, such as part of the interest expenses,
are dollar-denominated. If we are not able to obtain U.S. dollars to meet our
U.S. dollar-denominated obligations, we would be required to purchase U.S.
dollars on foreign exchange markets with reais. These purchases could be
expensive in real terms and could adversely affect our financial condition and
results of operations. The devaluation of the real in 1999, for example,
increased debt expenses because some of our loans are U.S. dollar-denominated.
Gross Domestic Product
The Brazilian economy grew rapidly immediately following the introduction
of the government-sponsored an anti-inflationary and economic stabilization
program, the Real Plan, in July 1994, particularly in the consumer sector. The
Real Plan succeeded in lowering inflation and stimulating growth until 1997. GDP
grew in constant terms by 5.9% in 1994, 4.2% in 1995, 2.8% in 1996, 3.0% in 1997
and 0.2% in 1998. The effect was a marked increase in purchasing power.
Beginning in 1996, the Brazilian economy grew at a slower rate and by late 1998
the Brazilian economy entered a downturn, which was exacerbated by a significant
currency devaluation beginning in mid-January 1999.
The recovery of the economy in 1999, in the wake of the 48.0% devaluation
of the local currency against the U.S. dollar and the strong fiscal adjustment
produced by the public sector led to strengthened consumer confidence. In 2000,
the economy grew at a steady pace of 4.5% while consumers registered gains in
disposable income of 3.1%. However, despite a 4% annualized increase in GDP in
the first quarter of 2001, the outlook for the rest of the year entails reduced
GDP growth as a result of the electric energy crisis in Brazil and the
unfavorable investment climate resulting from the current recession in
Argentina.
Inflation
The reduction and stabilization of inflation following the implementation
of the Real Plan resulted in increased spending on consumer goods, higher real
income growth and increased consumer confidence. Since 1994, inflation has
remained under control, although it increased particularly in the first half of
1999 due to the devaluation of the real in January 1999.
During the first three months of 2002, increased concerns over a weakening
Argentine economy, inflationary pressures, a weakening real, and a perceived
decrease in confidence of emerging markets by foreign investors, led the Central
Bank to increase interest rates from 15.8% on March 31, 2001 to 16.75% on May
24, 2001.
The Brazilian general price (IGP-M) and consumer price (IPC) inflation
indices and the devaluation of the real against the U.S. dollar are presented
below:
2001 2000 1999 1998 1997
---- ---- ---- ---- ----
Inflation IGP-M (1)................. 10.4% 9.9% 20.1% 1.8% 7.7%
Inflation IPC (2)................... 7.1% 4.4% 8.6% (1.8%) 4.9%
Nominal devaluation of the real
against the U.S. dollar......... 18.7% 9.3% 48.0% 8.3% 7.4%
- ------------------
(1) Indice Geral de Precos - Mercado (general price index) compiled by the
Fundacao Getulio Vargas.
(2) Indice de Precos ao Consumidor (consumer price index) compiled by the
Fundacao Instituto de Pesquisas Economicas.
Our results of operations have been affected both positively and negatively
by inflation itself, as well as by certain governmental measures to combat
inflation. Prior to their privatization, the electricity rates of ESCELSA
33
and ENERSUL did not increase as fast as inflation rates generally or ESCELSA's
and ENERSUL's costs specifically. See "Item 4. Information on the Company --
Business Overview --Regulation of the Brazilian Electricity Sector--Tariffs."
The introduction of the Real Plan in July 1994, the resulting reduction of
inflation and the changes to the tariff system in connection with privatization
have significantly limited the effects of such monetary gains and losses on our
statements of operations.
As of December 31, 2001 and 2000, approximately 99% and 98%, respectively,
of our marketable securities, in the total amount of R$256.8 million and R$262.2
million, respectively, were invested in U.S. dollar-linked instruments. We
believe that over the long term we can raise our tariffs in reais sufficiently
to generate cash to pay the principal and interest on the U.S.
dollar-denominated loans, although we cannot assure you that this will happen.
Tariffs
Prior to their privatization, the results of operations of both ESCELSA and
ENERSUL were significantly affected by fluctuations in the levels of electricity
tariffs. The tariff-setting process in Brazil has been frequently affected by
government attempts to control inflation and, prior to July 1995, tariff
increases were not determined on the basis of any express, precise guidelines or
policies, but rather tended to be established as corrective measures. In 1991,
electricity tariffs were increased at a rate lower than general inflation. The
Real Plan in 1994 set electricity tariffs in reais as of July 1, 1994. The Real
Plan provided that tariffs would be set on an annual basis, although the
Brazilian government could, in its discretion, change tariffs more frequently.
Since their privatization in July 1995 and November 1997, respectively, the
tariffs charged by both ESCELSA and ENERSUL have been determined pursuant to Law
No. 8,987/95 and their respective concession contracts and are subject to
approval by ANEEL. See "Item 4B. Information on the Company--Business
Overview--ESCELSA--Customers, Analysis of Demand and Tariffs--Tariffs" and "Item
4B. Information on the Company--Business Overview--Regulation of the Brazilian
Electricity Sector--Tariffs."
Cost of Electricity Purchased; Electricity Sales
We purchase energy on the basis of a "capacity charge" and/or an "energy
charge." The capacity charge, based on contracted firm capacity and charged on a
kilowatt basis, is charged without regard to the amount of electricity actually
delivered. The energy charge, expressed in reais per megawatt-hour, is based on
the amount of electricity actually delivered. In the case of ITAIPU, we purchase
electricity on the basis of a capacity charge expressed in U.S. dollars plus a
"wheeling" (or transportation) charge expressed in reais. We purchase
electricity generated by FURNAS and ELETROSUL on the basis of both a capacity
charge and an energy charge (these charges include transportation). See "Item
4B. Information on the Company--Business Overview--ESCELSA--Purchases of
Electricity." We generally bill for the electricity we sell to industrial
customers on the basis of both a capacity charge and an energy charge, while
other customers are billed only on the basis of an energy charge. Certain of our
large customers incur differing capacity and energy charges during peak or
non-peak hours and during dry or rain seasons. For a discussion of our
procedures for billing of electricity, see "Item 4B. Information on the
Company--Business Overview--ESCELSA--Customers, Analysis of Demand and Tariffs."
The following table sets forth volume and average rate components of our
electricity purchases and sales for the periods indicated:
For the Year Ended December 31,
----------------------------------
2001 2000 1999
------- ------- -------
Electricity purchased from ITAIPU, FURNAS
and GERASUL:
Purchases (thousands of reais)........ 675,189 500,139 501,102
Volume (GWh).......................... 8,730 9,595 9,005
Average Rate (R$/MWh)................. 77.41 52.12 55.65
Electricity Sales:
Sales to final consumers
34
For the Year Ended December 31,
----------------------------------
2001 2000 1999
------- ------- -------
(thousands of reais)............... 973,787 982,987 929,261
Volume (GWh)....................... 8,437 9,616 8,982
Average rate (R$/MWh)(1)........... 115.42 102.22 103.46
Sales to other concessionaires
(thousands of reais).............. 22.398 17,718 18,489
Volume (GWh)....................... 347 345 334
Average rate (R$/MWh).............. 64.73 51.35 55.36
Sales on the Spot Market(2)
(thousands of reais).............. 27,550 13,953 20,583
Volume (GWh)....................... 131 368 512
Average rate (R$/MWh).............. 211.87 37.92 40.20
- -----------
(1) Rates for sales to final customers have been computed by dividing (i) the
corresponding sales to final customers after deduction of value-added taxes
on sales (ICMS and COFINS) and regulatory assets by (ii) MWh of electricity
sold.
(2) Do not include regulatory assets revenue.
A. Operating Results
The following discussion should be read in conjunction with our financial
statements included elsewhere in this annual report. Our financial statements
are prepared in accordance with Brazilian GAAP, which differs in certain
significant respects from U.S. GAAP. Note 25 of the notes to our financial
statements appearing elsewhere in this annual report describes the principal
differences between Brazilian GAAP and U.S. GAAP as they relate to us, and a
reconciliation to U.S. GAAP of net income and shareholders' equity. See "Item 3.
Key Information--Presentation of Financial Information."
The following table sets forth certain of our consolidated income statement
data for the periods indicated.
For the Year Ended December 31,
----------------------------------------------------
2001 2000 1999
---- ---- ----
(in thousands of reais, on a consolidated basis)
Operating revenues................... 1,730,782 1,388,793 1,299,040
Value-added taxes on sales........... (345,297) (330,229) (308,558)
Net operating revenues 1,385,485 1,058,564 990,482
Operating expenses (1,185,564) (951,551) (957,090)
Financial income (expense) (235,831) (23,499) (119,345)
Nonoperating income (expense)........ (24,384) (13,325) (14,339)
Minority interest.................... (10,794) (3,314) 13,509
Income tax and social contribution... (11,012) (14,228) 69,503
Net income (loss).................... (60,076) 52,647 (17,280)
Year Ended December 31, 2001 Compared with Year Ended December 31, 2000
Operating Revenues
Our consolidated operating revenues increased 24.6% to R$1,730.8 million
for 2001 from R$1,388.8 million for 2000. The increase was attributable to the
extraordinary revenues in the amount of R$298.5 million. The extraordinary
revenue consists of recording the effects of (i) compensation for revenue losses
caused by the reduction of sales of energy due to the Rationing Program, (ii)
compensation for non-controllable cost items variation relating to Parcel A
costs from January 1, 2001 to October 25, 2001 and (iii) MAE transactions
(energy transactions on the spot market). See note 5 to our financial
statements.
Consolidated operating revenues from sales to other distributors increased
95.5% to R$83.5 million for 2001 from R$42.7 million for 2000. The increase was
attributable to the accounting as short-term supply of the surplus power made
available to the Wholesale Power Market.
35
Operating Expenses
Consolidated operating expenses increased 24.6% to R$ 1,185.6 million for
2001 from R$951.6 million for 2000, mainly due to increased electricity purchase
expenses and non-recurring provisions for operational contingencies arising from
civil and fiscal lawsuits (see note 17 to our financial statements).
Consolidated expenses for electricity purchased for resale increased 35.0%
to R$675.2 million for 2001 from R$500.1 million for 2000. The increase was
attributable to electric energy generation companies for free energy (see note 5
to our financial statements).
Consolidated depreciation and amortization expenses increased 5.8% to
R$149.1 million for 2001 from R$140.9 million for 2000. This increase was
attributable to a R$101.1 million increase in property, plant and equipment in
service at December 31, 2001 compared to December 31, 2000.
Consolidated personnel expenses decreased 5.8% to R$108.3 million for 2001
from R$115.0 million for 2000, principally because salary increases in 2001 did
not keep pace with inflation during that year and also due to a reduction in the
number of employees to 2,466 employees at December 31, 2001 from 2,551 employees
at December 31, 2000.
Consolidated regulatory charges decreased 2.4% to R$95.9 million in 2001
from R$98.2 million in 2000 mainly due to a 4.8% decrease in fuel usage
quota-CCC in 2001 equivalent to R$66.7 million compared to R$70.1 million in
2000. The decrease was due to the fact R$12.2 million was recorded as a
regulatory asset, under non-controllable Parcel "A" costs pursuant to
Provisional Measure No. 14/01, which was converted into Law No. 10,438/02.
Consolidated expenses for materials and supplies increased 20.7% to R$21.0
million for 2001 from R$17.4 million for 2000. The increase was attributable to
fuel for electric energy production used by ENERSUL.
Consolidated expenses related to third-party services decreased 3.9% to
R$53.6 million for 2001 from R$55.8 million for 2000. This reduction was caused
mainly by lower expenses associated with maintenance of the distribution
networks.
Consolidated other expenses increased 242.9% to R$82.5 million for 2001
from R$24.0 million for 2000. This increase was mainly due to a change of
criteria and the methodology for calculating the Allowance for Doubtful Accounts
(R$17.4 million higher than the previous year) and the provision for operational
contingencies arising from civil and fiscal lawsuits, in the total amount of
R$29.9 million. The change to both criteria and methodology for recording, is
based on the New Accounting Manual for the Brazilian Electricity Utilities
issued by ANEEL to be applied as from January 1, 2002. The Allowance for
Doubtful Accounts was due to the inclusion of credits from residential customers
past due more than 90 days, commercial customers past due more than 180 days and
other customers past due more than 360 days in the calculation. Up to and
including fiscal year 2000 the calculation considered credits after 120 days
past due, and did not consider credits from public authorities, public services
and public lighting.
Net Financial Income (Expense)
Consolidated net financial expense increased 903.6% to R$235.8 million in
2001 from R$23.5 million in 2000. This increase was due principally to the
devaluation of the real relative to the U.S. dollar in 2001, which increased our
financial expenses.
Net Non-operating Income (Expense)
Consolidated net non-operating expense, principally losses on the write-off
or sale of obsolete assets, increased 83% to R$24.4 million for 2001 from R$13.3
million for 2000.
36
Income Tax and Social Contribution
Our provision for income tax and social contribution was a credit of R$11.0
million in 2001, compared to an expense of R$14.2 million in 2000. This change
is due to the fact that in 2001 we had fiscal losses, as a result of the
devaluation of the real, and paid no taxes, while in 2000 we had profits and
consequently were required to pay taxes.
Net Income (Loss)
Net income under Brazilian GAAP decreased from a loss of R$60.1 million in
2001 to an income of R$52.6 million in 2000 as a result of the reasons described
above. Net loss reconciled to U.S. GAAP increased to a loss of R$122.2 million
in 2001 from income of R$12.2 million in 2000. For a discussion of the principal
differences between U.S. GAAP and Brazilian GAAP as they affect us, see note 25
to our financial statements.
Year Ended December 31, 2000 Compared with Year Ended December 31, 1999
Operating Revenues
Our consolidated operating revenues increased 6.9% to R$1,388.8 million for
2000 from R$1,299.0 million for 1999. The increase was attributable to (i)
tariff adjustments granted for the absorption of incremental costs incurred as a
result of energy purchased from the increase in costs related to the RGR and CCC
accounts and ONS connection charges; (ii) the annual tariff adjustment; and
(iii) an increase in energy sales.
Consolidated operating revenues from sales to other distributors increased
9.2% to R$42.7 million for 2000 from R$39.1 million for 1999. The increase was
attributable to an increase in the quantity of electricity sold on the spot
market in 1999.
Operating Expenses
Consolidated expenses for electricity purchased for resale remained
virtually the same, being R$500.1 million in 2000 and R$501.1 million in 1999.
Consolidated depreciation and amortization expenses increased 8.9% to
R$140.9 million for 2000 from R$129.4 million for 1999. This increase was
attributable to a R$211.7 million increase in property, plant and equipment in
service at December 31, 2000 compared to December 31, 1999.
Consolidated personnel expenses decreased 11.7% to R$115.0 million for 2000
from R$130.3 million for 1999 principally because salary increases in 2000 did
not keep pace with inflation during the year and also due to a reduction in the
number of employees to 2,551 employees at December 31, 2000 from 2,628 employees
at December 31, 1999.
Consolidated expenses for materials and supplies decreased 21.3% to R$17.4
million for 2000 from R$22.1 million for 1999 due to decreased investments in
maintenance of our distribution systems as a result of the completion of a
comprehensive program implemented by us after our privatization in 1995 to
compensate for the lack of investment during the years prior to our
privatization.
Consolidated expenses related to third-party services increased 3.1% to
R$55.8 million for 2000 from R$54.1 million for 1999. This increase was due to
the outsourcing of certain system maintenance activities at ESCELSA and ENERSUL.
Consolidated other expenses decreased 57.3% to R$24.0 million for 2000 from
R$56.2 million for 1999. This decrease is due principally to the fact that in
1999 we had to make a substantial adjustment to our provisions related to labor
lawsuits in order to bring the provisions up to an adequate level, while in 2000
we only needed to maintain such provisions.
37
Net Financial Income (Expense)
Consolidated net financial expense decreased 80.3% to R$23.5 million in
2000 from R$119.3 million in 1999. This decrease was due principally to the
devaluation of the real relative to the U.S. dollar in 1999, which increased our
financial expenses.
Net Non-operating Income (Expense)
Consolidated net non-operating expense, principally losses on the write-off
or sale of obsolete assets, decreased 7% to R$13.3 million for 2000 from R$14.3
million for 1999.
Income Tax and Social Contribution
Our provision for income tax and social contribution was R$14.2 million in
2000, compared to a tax credit of R$69.5 million in 1999. This change is due to
the fact that in 1999 we had fiscal losses, as a result of the devaluation of
the real, and paid no taxes, while in 2000 we had profits and consequently were
required to pay taxes.
Net Income (Loss)
Net income under Brazilian GAAP increased to R$52.6 million in 2000 from a
loss of R$17.3 million in 1999 as a result of the reasons described above. Net
income reconciled to U.S. GAAP increased to R$12.2 million in 2000 from a loss
of R$37.5 million in 1999. For a discussion of the principal differences between
U.S. GAAP and Brazilian GAAP as they affect us, see note 25 to our financial
statements.
Liquidity and Capital Resources
Our business is capital intensive and our principal capital requirements in
recent years have been to finance the purchase of ENERSUL and the expansion,
replacement and maintenance of ENERSUL's electricity distribution and
transmission system. Due to the limited availability of financing for the
Brazilian electricity sector expansion in recent years, ESCELSA has financed its
capital investment program primarily with cash provided by operations. In 1999,
ENERSUL funded its capital investment program through a R$55 million loan
provided by BNDES and R$28 million in intercompany loans. In 2000, we funded our
capital investment program through a R$29.3 million loan provided by BNDES, a
R$29.3 million loan provided by the European Investment Bank-EIB and a R$10.8
million loan provided by ELETROBRAS.
A significant portion of our current liabilities of R$623.0 million at the
end of 2001 represented (i) long-term loans and financing becoming due in 2002
(totaling R$246.8 million); (ii) accrued liabilities (including, among other
things, interest, fees, income tax and social contribution) (totaling R$123.0
million); (iii) obligations owed to FURNAS, GERASUL, ELETROSUL, MAE and ITAIPU
related to purchases of electricity (totaling R$178.9 million); and (iv)
regulatory charges payable (totaling R$13.2 million).
We had working capital of R$108.6 million at December 31, 2001, as compared
with working capital of R$149.8 million at December 31, 2000. The decrease in
working capital was mainly due to an increase in accounts payable from FURNAS,
GERASUL and ONS related to purchases of electricity included in current
liabilities and an increase in interest expenses due to the devaluation of the
real.
On December 31, 2001, our total debt was R$1,744.9 million, of which
R$595.0 million (34.1%) was in real-denominated loans and R$1,149.3 million
(65.9% of the total debt) was U.S. dollar-denominated debt. Our U.S.
dollar-denominated debt included R$1,000 million related to the notes and R$150
million related to the loans obtained from other banks. The real-denominated
loans included (i) R$384.3 million borrowed from BNDES, of which R$270.8 million
was used to finance our capital expenditures program and R$113.5 million was
utilized to finance the acquisition of our participation in ENERSUL's; (ii)
R$76.5 million borrowed from ELETROBRAS and (iii) R$134.2 million borrowed to
finance our capital expenditures program and working capital.
The average cost of our U.S. dollar-denominated debt on December 31, 2001
was 10.0% per year, plus foreign exchange variation. The average cost of our
real-denominated debt was TJLP (the long-term interest rate)
38
plus 4.0% per year related to the BNDES financing, while R$210.7 million were
indexed to the CDI, INPC or IGP-M plus 2-12% per year.
Our debt matures as follows:
At December 31, 2001
----------------------------------------------
Maturity Local Currency Foreign Currency Total
- ----------------------------- -------------- ---------------- -------
(in millions of reais)
2002......................... 190.2 56.6 246.8
2003......................... 102.5 11.0 113.5
2004......................... 107.2 24.0 131.2
2005......................... 67.6 12.1 79.7
2006......................... 50.3 10.8 61.1
2007......................... 26.9 1,008.7 1,035.6
2008......................... 14.6 5.6 20.2
2009......................... 9.6 1.9 11.5
2010......................... 8.6 1.5 10.1
2011......................... 5.5 1.5 7.0
After 2011................... 11.9 16.2 28.1
--------------- --------------- --------
Total................... 594.9 1,149.9 1,744.8
=============== =============== ========
As of December 31, 2001, approximately 99% of our marketable securities, in
the total amount of R$256.7 million, were invested in U.S. dollar-linked
instruments. We believe that over the long term we can raise our tariffs in
reais sufficiently to generate cash to pay the principal and interest on the
U.S. dollar-denominated loans, although we cannot assure you of this.
Over the next several years, we expect that our principal liquidity
requirements will consist of the interest expense on the notes and capital
expenditures. We plan to finance the interest expense on the notes and capital
expenditures with cash provided by operations. In addition, if we incur any
additional indebtedness, we will need to make interest payments, and may need to
make principal payments, thereon during the next several years.
We have ongoing capital expenditures related to the expansion and
modernization of our transmission, distribution and existing generation
facilities. We expect to use in the aggregate approximately R$71 million for the
expansion and modernization of our distribution system during 2002. A portion of
this may be financed with additional indebtedness from ELETROBRAS and BNDES
(subject to the limitations contained in the indenture that governs the notes).
Consolidated capital expenditures in 2001, 2000 and 1999 were as follows:
39
Area 2001 2000 1999
---- ------------ ------------ ------------
Distribution and transmission........... R$122,754 R$130,684 R$163,793
Generation.............................. 36,695 18,542 22,473
Other................................... 21,616 31,693 28,122
--------- --------- ---------
Total.............................. R$181,065 R$180,919 R$214,388
========= ========= =========
Research and Development, Patents and Licenses, Etc.
Research and development costs are not significant and are expensed as
incurred. Law No. 9,991 dated July 24, 2000 determines that distribution
companies shall apply, annually, at least 0.75% of their net operating revenues
to research and development in the electric sector and 0.25% to energy
efficiency programs. In case of the latter, such amounts can be deducted from
the amounts already spent by the distribution company for purposes of such
programs pursuant to the relevant concession contracts. Generation companies
shall apply, annually, at least 1% of their net operating revenues to research
and development in the electric energy sector, with an exception made for
generation companies which produce energy through alternative sources of energy.
ITEM 6. DIRECTORS, SENIOR MANAGEMENT AND EMPLOYEES
A. Directors and Officers
We are managed by our board of directors, comprised of at least nine
members, and a board of executive officers comprised of the chief executive
officer and a maximum of five other officers.
Board of Directors
Our board of directors generally meets twice every two months. It is
responsible for, among other things, establishing our general business policies
and electing the executive officers and supervising their management.
Under Brazilian corporate law, each member of the board of directors must
hold at least one of our common shares, may reside outside of Brazil (provided
that the director's empowerment is conditioned upon the appointment of an
attorney-in-fact residing in Brazil and that the relevant power of attorney
remains valid for three years after the officer's term of office has expired),
and is elected by the holders of common shares at the Assembleia Geral, or the
general shareholders' meeting.
The following matters, among others, require the approval of our board of
directors:
o the authorization for the acquisition, sale, any other transfer or
encumbrance of any fixed assets, as well as for the creation of any
liens on our real property;
o the authorization for the acquisition, sale or any transfer of capital
stock of another company;
o the authorization for the issue of any guarantee to an unrelated third
party;
o the incurrence of substantial indebtedness;
o the participation in any public bidding process;
o the amendment and termination of a concession contract; and
o the disposal or acquisition of any asset that exceeds 5% of our
permanent assets.
Members of our board of directors serve a three-year term, and may be
reelected. According to our bylaws, the terms of the current members of our
board of directors expire in April 2005. Set forth below are the names,
positions, dates of birth and brief biographical descriptions of the members of
our board of directors at May 31, 2002.
40
Name Member Since Position Date of Birth
- ---- ------------ -------- -------------
Fernando Noronha Leal................... December 1999 Chairman September 9, 1945
Adir Pereira Keddi...................... March 1998 Deputy Chairman November 18, 1947
Alcir Augustinho Calliari............... July 1995 Member September 14, 1938
Antonio Jose Sellare.................... April 2002 Member July 19, 1953
Antonio Manuel Garcia................... December 1999 Member February 20, 1940
Eduardo Jose Bernini.................... April 2002 Member November 18, 1956
Francisco Carlos Coutinho Pitella....... April 2002 Member February 9, 1953
Julio Moraes Sarmento de Barros......... April 2002 Member December 7, 1937
Ruth Storch Damasceno(1)................ November 1996 Member June 25, 1952
-----------
(1) Ms. Damasceno is the representative of our employees, a board position
provided for in our bylaws.
Fernando Noronha Leal. Mr. Leal is also chairman of the board of directors
of Iven S.A., a director of EDP Brasil S.A. and a member of the boards of
directors of EDP International S.A. and Bandeirante de Energia S.A. He has also
served as chief executive officer of Kaiser Engineers & Constructors and of
Petrogal -- Petroleos de Portugal S.A. He holds a degree in economics from the
Instituto Superior de Ciencias Economicas e Financeiras da Universidade Tecnica
de Lisboa.
Adir Pereira Keddi. Mr. Keddi was elected deputy chairman of the board of
directors on April 30, 2002 and has been a member of the board of directors
since March 1998. He is an executive officer of Fundacao Vale do Rio Doce de
Seguridade Social. He was previously in the accounting and finance department of
ESSO Brasileira de Petroleo S.A. He holds a degree in economics from Faculdade
Candido Mendes -- Rio de Janeiro and a masters degree in financial
administration from the Centro de Extensao e Aperfeicoamento Profissional of Rio
de Janeiro -- CEAP-RJ.
Alcir Augustinho Calliari. Mr. Calliari is an economic consultant at
Brasilconsult. He was previously the chairman of the board of directors,
president and chief executive officer of Banco do Brasil S.A. He holds a degree
in economics from Faculdade de Ciencias Politicas e Economicas de Cruz Alta --
RS, a law degree from Faculdade Nacional de Direito do Rio de Janeiro and a
degree in sociology from Colegio de Filosofia de Iju-Rio Grande do Sul.
Antonio Jose Sellare. Mr. Sellare is the investor relations director and
chief financial officer of EDP Brasil S.A. and chief financial officer of
Enertrade Comercializadora de Energia S.A. and of Calibre Participacoes S.A. He
is also a member of the board of directors of Bandeirante Energia S.A., the
investor relations director and CEO of Iven S.A. and 135 Participacoes S.A. He
was previously the treasury director of Banco Axial S.A and the chief financial
officer of Organizacoes BMD. He holds a degree in business administration from
Pontificia Universidade Catolica-- Sao Paulo.
Antonio Manuel Garcia. Mr. Garcia is an executive officer of EDP Brasil S.A
and a member of the board of directors of Bandeirante de Energia S.A. He was
previously the vice-president of Investco S.A. and a director of
PROET-Projectos, Engenharia e Tecnologia S.A. He holds a degree in mechanical
engineering from the Universidade Tecnica de Lisboa.
Eduardo Jose Bernini. Mr. Bernini is the president and chief executive
officer of EDP Brasil S.A. and Enertrade Comercializadora de Energia S.A. He is
also the chairman of the board of directors of Bandeirante Energia S.A. and of
CERJ-Cia Energetica do Rio de Janeiro. He was previously the president of
COEX-Comite Executivo do Mercado Atacadista de Energia-MAE, the chief executive
officer of VBC Energia S.A., the chief executive officer of
Eletropaulo-Metropolitana de Eletricidade de Sao Paulo S.A., the chief executive
officer of EBE-Empresa Bandeirante de Energia S.A. He holds a degree in
economics from Universidade de Sao Paulo -- USP and a master's degree in
economic development theory from Pontificia Universidade Catolica de Sao Paulo
and in the energy sector economy from Universidade de Sao Paulo -- USP.
Francisco Carlos Coutinho Pitella. Mr. Pitella is the investor relations
director of GTD Participacoes S.A. He was previously a director of Vale do Rio
Doce Aluminio S.A. and a member of the board of directors of Valesul and
Mineracao Rio do Norte. He holds a degree in civil engineering from Escola
Nacional de Engenharia da Universidade Federal do Rio de Janeiro.
41
Julio Moraes Sarmento de Barros. Mr. Barros is a member of the board of
directors of EDP Brasil S.A. and since January 2002, he has been an alternate
member of the board of directors of EDP, S.A. He was previously the chief
executive officer of Bandeirante Energia S.A., director of the Camara Portuguesa
de Comercio do Brasil, and a manager of Eletricidade de Lisboa e Vale do Tejo,
S.A. He holds a degree in electric engineering from the Instituto Superior
Tecnico da Universidade Tecnica de Lisboa.
Ruth Storch Damasceno. Ms. Damasceno is the president of CINVES. She holds
a degree in business administration from the Universidade Federal do Espirito
Santo.
Executive Officers
Our executive officers are elected by the board of directors for a
three-year term, although any executive officer may be removed by the board of
directors before the expiration of his term. Our executive officers, as well as
other officers, are responsible for our day-to-day management.
On October 16, 2001, Francisco Luiz Sibut Gomide, our former chief
executive officer, resigned. As of the date hereof, we have not elected a new
chief executive officer.
Set forth below, are the names, positions, dates of birth and brief
biographical descriptions of our executive officers at May 31, 2002.
Name Position Date of Birth
- ---- -------- -------------
Sergio Pereira Pires....... Chief Financial Officer September 13, 1959
Antonio Soares Diniz....... Technical Officer October 6, 1941
Sergio Pereira Pires. Mr. Pires has been the chief financial officer of
ESCELSA since June 1997 and of ENERSUL since November 1997. He was previously a
director of Grupo Habitasul and a corporate director of Banco Multiplic. He
holds a degree in economics from the Universidade de Sao Paulo and a master's
degree in finance from the Fundacao Getulio Vargas.
Antonio Soares Diniz. Mr. Diniz has been the technical officer of ESCELSA
since October 1995 and of ENERSUL since November 1997. He was previously the
director of operations and a superintendent of planning of COPEL. He holds a
degree in electromechanical engineering from the Universidade Federal de Minas
Gerais.
B. Compensation
For the year ended December 31, 2001, the aggregate compensation paid by us
to all directors, executive officers and members of our audit committee for
services in their respective capacities was approximately R$2.4 million. At the
annual shareholders' meeting held on April 30, 2002, the shareholders of ESCELSA
determined that an aggregate compensation of R$2.7 million would be paid to our
directors and executive officers for the year ending on December 31, 2002.
Neither the members of our board of directors nor our executive officers
receive pension benefits from us.
At December 31, 2001, the members of our board of directors and our
executive officers owned an aggregate of 10 common shares of our capital stock.
C. Board Practices
According to our bylaws, the terms of the current members of our board of
directors expire in April 2005.
Our executive officers are elected for three-year terms, although any
executive officer may be removed by our board of directors before the expiration
of his term.
42
None of the members of our board of directors or our executive officers is
a party to an employment contract providing for benefits upon termination of
employment.
Audit Committee
Under Brazilian corporate law, the Conselho Fiscal (audit committee) is a
corporate body independent of management and a company's external auditors. A
Brazilian audit committee is not equivalent to, or comparable with, a U.S. audit
committee. The primary responsibility of the audit committee is to review
management's activities and the financial statements, and report its findings to
the shareholders. Under Brazilian corporate law, the audit committee may not
contain members that are on the board of directors, on the executive committee,
the company's employees, employees of a controlled company or of a company of
the same group, as well as a spouse or relative of any member of the company's
management. In addition, the Brazilian corporate law requires the audit
committee to receive as remuneration at least 10% of the average amount paid to
each executive officer. The Brazilian corporate law requires an audit committee
to be composed of a minimum of three and a maximum of five members and their
respective alternates.
We have a permanent audit committee whose members are elected at the annual
shareholders' meeting, with their terms lasting until the next annual
shareholders' meeting after their election. The current members and their
respective alternates were elected by our shareholders on April 30, 2002.
Name Position
- ---- --------
Carlos Roberto Veroneze..................... Effective member
Dionisio Leonidas de Medeiros Neto.......... Alternate
Waldir Nascimento........................... Effective member
Adilson Rodrigues Fontes.................... Alternate
Eduardo Soares.............................. Effective member
Allain Brasil Bertrand Junior............... Alternate
D. Employees
At December 31, 2001, we employed 2,466 persons. We provide our employees
with a course for quality management, known as the Total Quality Management
Continuing Education Program, consisting of eleven sections (totaling 360 hours
of classes). In 1999, 284 employees were enrolled and the program ended during
2000. In 2001, a new group of employees began this program. In 2001, our total
investment in development and training activities amounted to R$1.0 million,
comprising 166,899 hours of training, with an average of 68 hours of training
per employee.
Since 1997, part of each employee's compensation is linked to previously
agreed upon goals. The program has presented good results, increasing
productivity and efficiency gains.
The following table sets forth the number of employees for the periods
indicated:
At December 31,
2001 2000 1999
-------- -------- --------
Professionals (including engineers,
accountants, economists and attorneys)... 659 2 574 2553
Management................................. 73 74 72
Operational................................ 1,734 1,903 2,007
Total.................................... 2,466 2,551 2,632
We provide our employees and their dependents with medical and dental
assistance through a system that uses a network of accredited doctors and
services. We pay the major portion of the costs for these services, with a
smaller amount being paid by the employees. In 2001, we spent R$4.3 million on
this assistance.
We and our subsidiaries are sponsors of retirement benefit plans, which are
managed by Fundacao ESCELSA de Seguridade Social - ESCELSOS or ESCELSOS and
Fundacao ENERSUL. ESCELSOS and Fundacao ENERSUL are non-profit entities, whose
main focus is to supplement the benefits provided by the federal
43
social security system to our employees. The majority of our employees
participate in these pension plans. In 2001, we contributed an aggregate of
R$4.5 million to the funds. See note 22 to our financial statements.
In Brazil, employees have the right to organize unions. Within the confines
of a defined geographic area, employees belonging to any specific professional
category and employees constituting a specific economic category may each be
represented by only one union. Individual unions generally belong to state-wide
union federations, which in turn belong to nationwide union confederations.
ESCELSA's employees are members of the Sindicato dos Trabalhadores na
Industria de Energia Eletrica no Estado do Espirito Santo -- SINDES and
ENERSUL's employees are members of the Sindicato dos Trabalhadores na Industria
e Comercio de Energia no Estado de Mato Grosso do Sul -- STICE-MS.
We believe that our relationships with our employees and their respective
labor unions are generally good.
E. Share Ownership
As of December 31, 2001, the members of our board of directors and our
executive officers, on an individual basis and as a group, beneficially owned
less than one percent of our common shares. None of the members of our board of
directors or our executive officers holds any options to purchase our common
shares.
ITEM 7. MAJOR SHAREHOLDERS AND RELATED PARTY TRANSACTIONS
A. Major Shareholders
At ESCELSA's privatization auction held on July 11, 1995, 50% (plus one) of
the common shares of ESCELSA were acquired by Iven and GTD. Iven and GTD are
currently parties to a shareholders' agreement which provides them with joint
control of our operations. See "--Shareholders' Agreement."
In August 1999, EDP -- Eletricidade de Portugal acquired 73% of Iven, and
since that date control of Iven has been shared between EDP and Opportunity
Fund.
GTD is a holding company that invests in Brazil's electricity sector and is
owned by 17 Brazilian pension funds, including Caixa de Previdencia dos
Funcionarios do Banco do Brasil -- PREVI, Instituto Aerus de Seguridade Social,
Fundacao de Assistencia e Previdencia Social BNDES -- FAPE, Fundacao Telebras de
Assistencia Social -- SISTEL, Fundacao Eletrobras de Seguridade Social, Real
Grandeza Fundacao de Previdencia e Assistencia and other foundations.
The following table sets forth information with respect to ownership of our
common shares as of December 31, 2001.
Percentage
Shareholder Number of Shares of Total
- ----------- ---------------- ----------
Iven....................................................... 2,378,673 52.27%
GTD........................................................ 1,137,709 25.00
Fundacao Central Bank de Previdencia Privada - CENTRUS..... 275,678 6.06
Officers and Directors as a group.......................... 10 *
Others..................................................... 966,388 16.67
--------------- ----------
Total...................................................... 4,550,833 100.0%
- -------------
* Less than 1%.
Shareholders' Agreement
Iven and GTD entered into a shareholders' agreement on July 10, 1995 when
they purchased, in a consortium, 50% (plus one share) of the voting stock of
ESCELSA. Shares purchased by GTD and Iven pursuant to the privatization of
ESCELSA may not be sold without the prior authorization of ANEEL. The
shareholders'
44
agreement expires on July 10, 2002. See "Item 2C. Risk Factors--Risks Relating
to Us and Our Notes--We are controlled by a few shareholders that act in concert
to control all our subsidiaries and us and we may be controlled by one
shareholder in the future." The joint ownership of a majority of our voting
shares gives Iven and GTD the ability to control the election of the majority of
the members of our board of directors, as well as the ability to determine the
outcome of major decisions requiring the approval of our shareholders. According
to the shareholders' agreement, no shares held by Iven and GTD subject to the
agreement may be voted unless both parties agree to vote in the same manner.
Accordingly, if Iven and GTD do not agree as to any particular matter, a
deadlock would result.
B. Related Party Transactions
Our concession contracts require that we obtain approval from ANEEL prior
to entering into commercial relationships with any of our shareholders. Our
transactions with our affiliates are restricted by the provisions of the
indenture that governs the notes.
Banco Opportunity S.A., an affiliate of the Opportunity Fund, which is also
one of Iven's shareholders, is among the several banks that manage our pension
fund, ESCELSOS. Fund managers are paid 15% of any return above IGP-M plus 8%.
C. Interest of Experts and Counsel
Not applicable.
ITEM 8. FINANCIAL INFORMATION
A. Consolidated Statements and Other Information
See Item 18 for a list of financial statements filed with this annual
report.
Legal Proceedings
We are party to certain lawsuits and administrative proceedings before
various courts involving tax, labor and civil matters. The principal lawsuits
currently in process are as follows:
Tax Litigation
Brazilian companies are required to pay contributions to the PIS Program
(Program for Social Integration) and COFINS (Program for Financing Social
Security). The rates for these contributions are 0.65% and 3.0% (2.0% in 1998
and 1997) of the revenues, respectively. ESCELSA and ENERSUL have filed lawsuits
against the Brazilian government questioning the constitutionality of (i) with
respect to COFINS, contributions relating to non-operational and financial
income and (ii) with respect to PIS, the contributions relating to income
related to the sales of energy, and to non-operational and financial income.
Our management believes that the ultimate outcome of these tax-related
proceedings will not have a material adverse effect on our financial position or
results of operations. As of December 31, 2001, we had reserved R$128.1 million
for these contingencies, of which R$97.4 million is deposited in judicial escrow
accounts in connection with these lawsuits.
Labor Claims
We are party to several labor-related lawsuits, including a lawsuit filed
by the Sindicato dos Trabalhadores da Industria de Energia Eletrica do Estado do
Espirito Santo -- SINDEES (the labor union in the State of Espirito Santo for
the electricity sector), as well as several disputes filed by employees and
former employees related principally to our wage structure and overtime. As of
December 31, 2001, we had reserved R$20.0 million for labor contingencies, of
which R$11.6 million is deposited in judicial escrow accounts in connection with
these lawsuits.
45
We believe, based on the judgment of our management and our legal counsel,
that the amount provisioned is sufficient to cover the probable losses from
lawsuits that remain pending, with a range of possible loss 10% higher or lower
than the reserved amount.
Civil Litigation
We are party to civil lawsuits and administrative proceedings arising from
the ordinary course of our business. We believe that the ultimate outcome of
these proceedings will not have a material adverse effect on our financial
position or results of operations. As of December 31, 2001, we had reserved
R$24.4 million for civil litigation, of which R$7.2 million is deposited in
judicial escrow accounts in connection with these lawsuits.
Tariff Litigation
A number of industrial consumers have brought a lawsuit against ESCELSA and
ENERSUL seeking refunds of amounts paid to ESCELSA and ENERSUL as a result of
rate increases that became effective during an economic stabilization plan in
1986. The lawsuits claim that such increases were in violation of price controls
instituted as part of the economic stabilization plan. Our management believes
that the ultimate outcome of these proceedings will not have a material adverse
effect on our financial position or results of operations. As of December 31,
2001, we had reserved R$6.7 million for these contingencies.
Dividend Policy and Dividend Distributions
Amounts Available for Distribution
At each annual shareholders' meeting, the board of directors is required to
recommend how net profits for the preceding fiscal year are to be allocated. For
purposes of Brazilian corporate law, net profits are defined as net income after
income taxes and social contribution taxes for such fiscal year, net of any
accumulated losses from prior fiscal years and any amounts allocated to
employees' and management's participation in our profits. In accordance with
Brazilian corporate law, the amounts available for dividend distribution are the
amounts equal to our net profits less any amounts allocated from such net
profits to:
o the legal reserve; and
o a contingency reserve for anticipated losses.
We are required to maintain a legal reserve, to which we must allocate 5%
of net profits for each fiscal year until the amount of such reserve equals 20%
of our paid-in capital. However, we are not required to make any allocations to
our legal reserve in respect to any fiscal year in which it, when added to our
other established capital reserves, exceeds 30% of our capital. Net losses, if
any, may be charged against the legal reserve.
The Brazilian corporate law also provides for two additional, discretionary
allocations of net profits that are subject to approval by the shareholders at
the annual meeting. First, a percentage of net profits may be allocated to a
contingency reserve for anticipated losses that are deemed probable in future
years. Any amount so allocated in a prior year must be either reversed in the
fiscal year in which the loss was anticipated if such loss does not in fact
occur, or written off in the event that the anticipated loss occurs. Second, if
the amount of the mandatory distribution exceeds the realized portion of net
profits for the fiscal year, such excess may be allocated to an unrealized
revenue reserve.
The amounts available for distribution may be increased by a reversion of
the contingency reserve for anticipated losses constituted in prior years but
not realized, or further increased or reduced as a result of the allocations of
revenues to or from the unrealized revenue reserve. The amounts available for
distribution are determined on the basis of financial statements prepared in
accordance with the corporate law method.
46
Mandatory Distribution
The Brazilian corporate law generally requires that the bylaws of each
Brazilian corporation specify a minimum percentage of the amounts available for
distribution by such corporation for each fiscal year that must be distributed
to shareholders as dividends, also known as the mandatory distributable amount.
Under our bylaws, the mandatory distributable amount has been fixed at an amount
equal to not less than 25% of the amounts available for distribution, to the
extent amounts are available for distribution.
The mandatory distribution is based on a percentage of adjusted net income,
not lower than 25%, rather than a fixed monetary amount per share. The Brazilian
corporate law, however, permits a publicly held company to suspend the mandatory
distribution of dividends if the board of directors and the audit committee
report to the shareholders' meeting that the distribution would be inadvisable
in view of the company's financial condition. The suspension is subject to
approval of holders of common shares. In this case, the board of directors shall
file a justification for such suspension with the CVM. Also, a publicly held
company may suspend the payment of dividends exclusively for purposes of raising
funds through the issuance of nonconvertible debentures. Profits not distributed
by virtue of the suspension mentioned above shall be attributed to a special
reserve and, if not absorbed by subsequent losses, shall be paid as dividends as
soon as the financial condition of such company permits such payments.
Payment of Dividends
We are required by the Brazilian corporate law and by our bylaws to hold an
annual shareholders' meeting by the fourth month after the end of each fiscal
year at which, among other things, the shareholders have to decide on the
payment of an annual dividend. The payment of annual dividends is based on the
financial statements prepared for the relevant fiscal year. Under the Brazilian
corporate law, dividends generally are required to be paid within 60 days
following the date the dividend was declared, unless a shareholder's resolution
sets forth another date of payment, which, in either case, must occur prior to
the end of the fiscal year in which the dividend was declared. A shareholder has
a three-year period from the dividend payment date to claim dividends in respect
of its shares, after which the amount of the unclaimed dividends reverts to us.
The Brazilian corporate law also permits a company to pay interim dividends out
of preexisting and accumulated profits for the preceding fiscal year or
semester, based on financial statements approved by its shareholders.
Dividend Distributions
The following table sets forth our historical payments of dividends to our
shareholders.
Period in which profits Total amount of
Date of Approval were generated distribution
------------------------ ---------------------------- ---------------
April 1999............... Year ended December 31, 1998 R$72.1 million
April 2000............... Year ended December 31, 1999 -*
April 2001............... Year ended December 31, 2000 R$13.2 million
April 2002............... Year ended December 31, 2001 -*
-----------------------
* No dividends were declared for the years ended December 31, 2001 and
1999 because we had net losses for such periods.
The declaration of annual dividends, including dividends in excess of the
mandatory distribution, requires approval by the vote of the majority of the
holders of our common stock. The amount of any distributions will depend on many
factors, such as our results of operations, financial condition, cash
requirements, prospects and other factors deemed relevant by our board of
directors and shareholders.
47
B. Significant Changes
No significant changes or events have occurred after the close of the
balance sheet date at December 31, 2001, other than the events already described
in this annual report.
ITEM 9. THE OFFER AND LISTING
A. Offer and Listing Details
The carrying value of our notes as of December 31, 2001, consisting of the
fair value of the notes based on the bid price as of such date, was R$860.0
million. At December 31, 2001 and May 31, 2002 the notes were trading at 86.0%
and 88.0% of their face value, respectively.
B. Plan of Distribution
Not applicable.
C. Markets
Our common shares are traded on the Sao Paulo Stock Exchange in Brazil and
are not traded in the United States. The notes are listed on the Luxembourg
Stock Exchange.
D. Selling Shareholders
Not applicable.
E. Dilution
Not applicable.
F. Expenses of the Issue
Not applicable.
ITEM 10. ADDITIONAL INFORMATION
A. Share Capital
Not applicable.
B. Memorandum and Articles of Association
Set forth below is certain information concerning our capital stock and a
brief summary of certain significant provisions of our by-laws and the Brazilian
corporate law. This description does not purport to be complete and is qualified
by reference to our by-laws (an English translation of which has been filed with
the Securities and Exchange Commission) and to the Brazilian corporate law.
Corporate Purposes
We are a share company with principal place of business and jurisdiction in
the City of Vitoria, Brazil, governed mainly by our by-laws and by the Brazilian
corporate law.
In accordance with our by-laws, our main purposes are: (a) to carry out
studies, projects, constructions and operations of production mills,
transmission lines and distribution of electric power, as well as to enter into
trading acts arising from such activities, while retaining the right to
simultaneously join other corporations for the accomplishment of other projects;
(b) to develop activities associated with the rendering of electric power
service,
48
such as multiple use of electric power poles, through assignment to
other users, data transmission through installations while observing relevant
legislation, rendering of operational technical services, maintenance and
planning of third-party electrical installations, optimization services of
energy processes and consumer electrical installations, supply of expensive
assignment lines, land subject to mill exploration, and reservoirs for better
electric power use and supply; (c) to join study groups, syndicates, association
groups or any other entity for research purposes in the energy sector or for the
training of technical personnel which may be deemed necessary, as well as for
the rendering of technical, operational and administrative support services to
electrical power subsidiary companies in the public sector.
Capital Stock and Dividend Policy
General
As of December 31, 2001, our capital stock in reais was R$153,946,942.07.
Our share capital is comprised of registered common shares, all without par
value. Our share capital consists of a total of 4,550,833 issued common shares,
without par value. Our bylaws authorize our board of directors to increase our
capital stock up to R$1,000,000,000.00, without seeking specific shareholder
approval. The shareholders must approve any further capital increase at a
shareholders' meeting.
Mandatory Annual Distribution
Under our bylaws, at least 25% of our adjusted net income for the preceding
fiscal year must be distributed as a mandatory annual distribution, to be paid
out within 60 days of the annual shareholders' meeting in which the distribution
is approved. The Brazilian corporate law permits, however, a public company to
suspend payment of the mandatory distribution (i) if the board of directors and
the conselho fiscal report to the shareholders' meeting that the distribution
would be incompatible with our financial condition, subject to approval by the
shareholders' meeting or (ii) for purposes of raising funds through the issuance
of nonconvertible debentures. The board of directors must file a justification
for a distribution suspension with the CVM within five days of the shareholders'
meeting. Profits not distributed due to such suspension must be allocated to a
special reserve and, if not absorbed by subsequent losses, must be paid as
dividends as soon as our financial situation permits such payments. There is no
restriction on our repurchase or redemption of shares while the mandatory
distribution is suspended due to duly approved and justified financial reasons,
other than the generally applicable restrictions on trading by companies with
their own shares, as set forth in the Brazilian corporate law and in the rules
and regulations issued by CVM.
Voting Rights
Each common share entitles its holder to one vote at our shareholders'
meetings.
Allocation of Net Income
At each annual shareholders' meeting, our by-laws require our board of
directors to recommend that net income for the preceding fiscal year from which
income tax and losses carried forward from prior fiscal years have already been
deducted be allocated as follows:
o 5% for a legal reserve that will not exceed 20% of our paid-in
capital;
o at least 25% for mandatory distribution to shareholders; and
o any balance to be allocated in the manner determined by the
shareholders.
Under the Brazilian corporate law, payment of the mandatory dividend is not
required if the board of directors has formally declared such distribution to be
inadvisable in view of the company's financial condition and has provided the
shareholders at the annual shareholders' meeting with an opinion to that effect
which has been reviewed by the conselho fiscal and reported to the CVM prior to
such meeting. See "Item 8A. Financial Information -- Consolidated Statements and
Other Information -- Dividend Policy and Dividends -- Mandatory Distribution."
49
C. Material Contracts
Contract for the Installment of Transmission Services
On October 28, 1999, ESCELSA and ONS entered an agreement to render
transmission of electric energy services, in which ESCELSA grants to ONS
authorizations for the management and coordination of the transmission services
rendered by ESCELSA and to represent the latter before its customers to execute
the contracts for the use of the transmission system. This agreement will
terminate on the date of the expiration of the ESCELSA concession contract.
Under this agreement, ESCELSA is responsible for:
o implanting, protecting and maintaining the installations,
o reporting to ONS so it may supervise and control the system, and
o providing telecommunication services.
ESCELSA is also responsible for measuring the volume of energy sold to each
customer and for billing such customers for the energy consumed.
Contract for Use of the Transmission System
On October 28, 1999, ESCELSA and ONS also entered into a contract providing
for the use by ESCELSA of the system of transmission of electric energy
controlled and operated by ONS, for distribution of that electric energy in its
concession area. The term of this agreement is until the expiration of the
concession obtained by ESCELSA. Under this agreement, ESCELSA is required to
provide ONS with the information necessary for the operation of the system.
ESCELSA shall pay ONS a monthly tariff for the use of the transmission system,
including for eventual excess of demand and overloads in the installation and
equipments of ESCELSA, at the amounts established pursuant to regulations
implemented by ANEEL.
Contract for Connection to the Transmission System
ESCELSA entered into a contract, effective June 10, 1999, with FURNAS, a
transmitter of electric energy, providing for ESCELSA's connection to FURNAS'
transmission system, for the purpose of acting as a distributor of the electric
energy in its concession area. Under this agreement, ESCELSA and FURNAS jointly
assume responsibility for the operation and maintenance of installations of
connection and/or points of connection of their property as well as guarantee
mutual access to all such facilities. In addition, this contract imposes
responsibility on both parties for the evaluation of the operative conditions
and identification of necessary adaptations to the facilities. However, it is
ESCELSA's sole responsibility to forecast the load of installations to FURNAS.
ESCELSA must pay FURNAS a monthly tariff for the installation of connection
and/or points of connection of FURNAS' property, for every month of use of that
connection, at the amounts established by ANEEL, in the same proportion.
Contract for Purchase and Sale of Electric Energy
ESCELSA entered into an agreement to purchase electric energy and demand
from FURNAS in order to distribute such energy to the public in ESCELSA's
concession area. The contract became effective on August 7, 1999 and continues
in effect until December 31, 2005, throughout which time, ESCELSA is required to
purchase certain amounts of electricity generated by FURNAS, at tariffs set by
ANEEL. ESCELSA's commitment may be reduced by the amount of ESCELSA's generation
capacity increases. Therefore, if ESCELSA were to increase its generation
capacity in accordance with approvals received from ANEEL, required purchase
amounts from FURNAS would be reduced accordingly. If ESCELSA were to require
energy purchases in an amount greater than that established in ESCELSA's initial
contracts, however, FURNAS' obligation to supply such energy would be contingent
on availability. ESCELSA also has the right to immediately reduce purchases from
FURNAS if a large customer terminates its contract with ESCELSA.
Indenture for the Notes
50
We entered into an indenture dated as of July 28, 1997 with The Chase
Manhattan as Trustee for the issuance of our 10% senior Notes due 2007 in the
total amount of U.S.$500 million, or the notes.
We agreed, among other things, to:
o limitations on our indebtedness;
o limitations on restricted payments;
o limitations on dividend payments;
o limitations on the issuance of Capital Stock of our subsidiaries;
o limitations on issuances of guarantees by our subsidiaries;
o limitations on asset sales;
o limitations on transactions with our shareholders and our affiliates;
o repurchase of the notes upon a change of control;
o limitations on liens;
o limitations on sale-leaseback transactions; and
o limitations on the consolidation, merger and sale of assets.
D. Exchange Controls
Brazilian law provides that, whenever there is a significant imbalance in
Brazil's balance of payments or reasons to foresee such an imbalance, temporary
restrictions may be imposed on the conversion of Brazilian currency into foreign
currencies and on remittances of foreign capital abroad. For approximately six
months in 1989 and early 1990, for example, the Brazilian government imposed
remittance restrictions on all dividend and capital repatriations that were owed
to foreign equity investors and held by the Central Bank in order to conserve
Brazil's foreign currency reserves. These amounts were subsequently released in
accordance with Brazilian federal directives.
The Central Bank has authorized the issuance of the notes and issued a
certificate of foreign capital registration authorizing us to make any payment
under the notes requiring the conversion of reais into U.S. dollars (including
any payment made upon enforcement of a judgment against us). However, additional
Central Bank authorization is needed for the payment of the notes upon
acceleration or for certain late payments of the notes generally. These exchange
control regulations generally have not affected repayment obligations of
securities of a type similar to the notes. There can, however, be no assurance
that the Brazilian government will not in the future impose more restrictive
foreign exchange regulations that would have the effect of preventing or
restricting our access to foreign currency that it may require to meet its
foreign currency obligations under foreign currency denominated liabilities
(including the notes).
See "Item 3. Key Information-- Exchange Rates" for more information on
exchange rates of the real versus the U.S. dollar.
E. Taxation
General
The following is a summary of certain material Brazilian and U.S. federal
income tax consequences resulting from the investment in, and ownership and
disposition of, the notes, but it does not purport to be a comprehensive
description of all the tax considerations that may be relevant to a decision to
invest in, or own and dispose of, the notes. While this description is
considered to be a correct interpretation of existing laws and regulations in
force as of the date of this annual report, no assurance can be given that the
courts or fiscal authorities responsible for the administration of such laws and
regulations will agree with this interpretation or that changes to such laws and
regulations will not occur. The discussion of Brazilian tax matters is based
upon the advice of Ulhoa Canto, Rezende e Guerra -- Advogados, Rio de Janeiro,
Brazil. The discussion of U.S. federal income tax matters is based upon the
advice of Shearman & Sterling, New York, New York.
51
Investors and holders of the notes should consult their own tax advisors as
to the Brazilian, U.S. or other tax consequences of the purchase, ownership and
disposition of the notes including the particular tax consequences to them in
light of their particular investment circumstances.
Although at present there is no income tax treaty between Brazil and the
United States, the tax authorities of the two countries have had discussions
that may culminate in such a treaty. There can be no assurance, however, as to
whether or when a treaty will enter into force or how it will affect holders of
the notes.
Brazilian Tax Considerations
Individuals domiciled in Brazil and Brazilian companies are taxed in Brazil
on the basis of their worldwide income (which includes earnings of Brazilian
companies' foreign subsidiaries, branches and affiliates). The earnings of
foreign companies and persons not resident in Brazil in general are taxed in
Brazil when derived from Brazilian sources unless there exists a tax treaty
between Brazil and the country of domicile of the non-resident providing
otherwise.
Interest, fees, commissions and any other income (which for the purposes of
this paragraph includes any deemed income on the difference between the issue
price of the notes and the price at which the notes are redeemed ("original
discount") payable by a Brazilian obligor to an individual, company, entity,
trust or organization domiciled outside Brazil is subject to income tax withheld
at the source. Brazilian tax laws expressly authorize the paying source to pay
the income or earnings net of taxes and, therefore, to assume the cost of the
applicable tax. The rate of withholding is 15% or such other lower rate as is
provided for in an applicable tax treaty between Brazil and such other country
where the recipient of the payment has its domicile. Notwithstanding the
foregoing, pursuant to Law No. 9,481 dated August 13, 1997, the applicable
income tax rate for negotiable instruments such as the notes was reduced to zero
with respect to payments of interest, fees and commissions made during 1997,
provided that such negotiable instruments have a minimum maturity of 96 months.
In accordance with Article 1st of Law No. 9,959 dated January 27, 2000,
negotiable instruments such as the notes which are issued as of January 1, 2000,
are no longer eligible for this rate reduction.
We believe and intend to take the position for Brazilian tax reporting
purposes that, as long as the principal paying agent is located in Japan and
payment to the principal paying agent discharges our obligations to make
payments in accordance with the notes, interest and other income with respect to
the notes will be subject to Brazilian withholding tax at a rate of 12.5% under
the tax treaty in effect between Brazil and Japan. In any event, under the terms
of the notes, we are required to gross up noteholders for any Brazilian
withholding tax, subject to customer exceptions. We have the right to redeem the
notes at par in the event that it is required to gross up for Brazilian
withholding tax at a rate in excess of 15%.
Any earnings or capital gains made outside Brazil as a result of a
transaction between two non-residents of Brazil with funds not located in Brazil
are not subject to tax in Brazil. In such transactions, the gains obtained by a
non-resident in the purchase and sale of the notes to non-residents are not
subject to tax in Brazil. However, any gains obtained by a non-resident in the
sale of the notes to a Brazilian resident may be subject to tax in Brazil.
On August 15, 1996, the Brazilian Congress approved Constitutional
Amendment No. 12 creating a new temporary tax, the Contribuicao Provisoria sobre
Movimentacao Financeira (the provisional contribution on transfers of value and
of credits and rights of a financial nature, or CPMF). Based on such Amendment,
Federal Law No. 9,311 dated October 24, 1996 was enacted, determining the
creation of the CPMF tax. Under Law No. 9,311/96, all financial debit and money
transfers effected as from January 23, 1997 until February 23, 1998 will be
subject to the assessment of the CPMF tax at the rate of 0.20%. Law No. 9,539
dated December 12, 1997 extended the assessment of the CPMF tax at the same rate
of 0.20% until January 23, 1999. Constitutional Amendment No. 21 dated March 28,
1999, extended the CPMF for a period of three years with a tax rate of 0.38%
within the first year, starting on June 17, 1999 and of 0.30% thereafter. From
March 18, 2001, the tax rate was increased to 0.38% by Constitutional Amendment
No. 31 dated December 14, 2000, and Decree No. 3,775 dated March 15, 2001.
Constitutional Amendment No. 37 dated June 12, 2002 further extended until
December 31, 2004 the CPMF and determined that from January 1, 2004 the CPMF
rate will be reduced to 0.08%.
52
Portaria No. 241 of October 31, 1996 imposed a tax on foreign exchange
transactions ("IOF tax") related to the entry into Brazil of proceeds resulting
from foreign loans (including the issue of debt securities such as the notes).
Initially the IOF tax had varying rates depending upon the final maturity of the
transaction. Consequently, in case of early redemption or payment of the notes a
tax at a rate varying from 3% to 0%, depending on the date of redemption, would
have been assessed on the corresponding proceeds. However the IOF tax is a tax
upon the Brazilian issuer (in this case, us) and will have no effect on the
amounts received by the holders of the notes. We thus would be liable for and
would pay the IOF tax as well as any charges imposed by Brazilian tax
authorities on Brazilian issuers. Portaria No. 5 of January 21, 1999 and Decree
No. 2,219 of May 2, 1997 reduced the IOF tax rate to 0%. There can be no
assurance that the IOF tax rate will not be increased in the future.
There is no stamp, transfer or other similar tax in Brazil with respect to
the transfer, assignment or sale of any debt instrument outside Brazil
(including the notes).
U.S. Federal Income Tax Considerations
The following discussion, which is a summary of certain material U.S.
federal income tax considerations relevant to the investment in, and ownership
and disposition of, the notes, is limited to investors in notes who hold such
notes as capital assets. This summary is based on provisions of the U.S.
Internal Revenue Code of 1986, as amended, existing and proposed U.S. Treasury
regulations promulgated thereunder, and administrative and judicial
interpretations thereof, all as currently in effect and all of which are subject
to change (possibly with retroactive effect) and to differing interpretations.
This summary does not discuss all aspects of U.S. federal income taxation that
may be applicable to holders of notes in light of their particular circumstances
or to holders of notes subject to special treatment under U.S. federal income
tax law (including, but not limited to, life insurance companies, dealers in
securities, financial institutions, tax-exempt organizations and persons having
a functional currency other than the U.S. dollar).
As used herein, the term "U.S. Holder" means a beneficial owner of a note
that is, for U.S. federal income tax purposes, (i) a citizen or resident alien
individual of the United States, (ii) a corporation or other entity treated as a
corporation for U.S. federal income tax purposes created or organized in or
under the laws of the United States or of any state thereof or the District of
Columbia, (iii) an estate the income of which is subject to U.S. federal income
taxation regardless of its source, or (iv) a trust, if a court within the United
States is able to exercise primary supervision over the administration of the
trust and one or more United States persons have the authority to control all
substantial decisions of the trust. If a partnership (including for this purpose
any entity treated as a partnership for United Sates federal income tax
purposes) is a beneficial owner of the notes, the treatment of a partner in the
partnership will generally depend upon the status of the partner and upon the
activities of the partnership. A holder of the notes that is a partnership and
partners in such partnership should consult their U.S. tax advisors. As used
herein, a "non-U.S. Holder" means a beneficial owner of a note that is not a
U.S. Holder.
Payments of Interest
Stated interest payable on the notes (and additional amounts, if any)
generally will be includible in the gross income of the U.S. Holder as ordinary
interest income at the time accrued or received, in accordance with such U.S.
Holder's method of accounting for U.S. federal income tax purposes. The amount
of income taxable to a U.S. Holder will include the amount of any Brazilian
taxes withheld (as described above under "Brazilian Tax Considerations") by us
in respect thereof. Thus, a U.S. Holder could be required to report income in an
amount greater than the cash it receives in respect of payments on its notes.
Such interest income will be treated as derived from sources outside the United
States.
Foreign Tax Credit
Interest income typically is treated as "passive" or "financial services"
income and is considered separately (together with other items of passive or
financial services income) for purposes of applying certain limitations on the
claiming of foreign tax credits under U.S. federal income tax law. However, if
interest income derived by a U.S. Holder in respect of the notes is subject to
Brazilian withholding tax at a rate of at least 5%, then such interest should
represent "high withholding tax interest" to the U.S. Holder (together with
other items of high withholding tax interest), and the foreign tax credit
limitations will apply separately to foreign income taxes attributable thereto.
53
Subject to such limitations and certain other conditions, any Brazilian income
taxes withheld from interest income derived by a U.S. Holder in respect of the
notes may be eligible for credit against the U.S. federal income tax liability
of the U.S. Holder. A U.S. Holder may not be able to obtain a foreign tax credit
benefit with respect to Brazilian income taxes, if any, imposed on any gain
resulting from a disposition of the notes, as such gain generally will not
constitute foreign source income. In lieu of claiming a credit for any foreign
income taxes paid in a taxable year, a U.S. Holder may elect to deduct such
foreign income taxes in computing its U.S. federal taxable income. The rules
relating to foreign tax credits are complex, and U.S. Holders should consult
their own tax advisors with regard to the availability of a foreign tax credit
and the application of the foreign tax credit limitations to their particular
situations.
Market Discount and Premium
If a U.S. Holder purchases a note for an amount that is less than its
stated principal amount, such note will be treated as having "market discount"
equal to the amount of such difference (unless such difference is less than a
specified de minimis amount).
Unless a U.S. Holder elects to accrue market discount as described below,
such U.S. Holder will be required to treat any partial principal payment on, or
any gain realized on the sale, exchange, or retirement of, a note having market
discount as ordinary income to the extent of the lesser of (i) the amount of
such payment or realized gain or (ii) the market discount that has not
previously been included in gross income and is treated as having accrued on
such note at the time of such payment or disposition. Market discount on a note,
if any, will be considered to accrue on a straight-line basis during the period
from the date of acquisition to the maturity date of the note, unless the U.S.
Holder elects to accrue on a constant yield basis.
A U.S. Holder may be required to defer the deduction of all or a portion of
the interest paid or accrued on any indebtedness incurred or maintained to
purchase or carry a note having market discount until the maturity of the note
or its earlier disposition. A U.S. Holder may elect to include market discount
in income currently as it accrues (on either a straight-line or a constant yield
basis), in which case such U.S. Holder will not be subject to the rules
described above regarding the treatment of gain upon the disposition of, and the
receipt of certain cash payments on, a note as ordinary income and regarding the
deferral of interest deductions.
If a U.S. Holder purchases a note for an amount that is greater than its
stated principal amount, such U.S. Holder will be considered to have purchased
the note at a "premium" equal to such excess, and may elect to amortize such
premium, on a constant yield basis, over the remaining term of the note (subject
to special rules concerning early call provisions). If an election to amortize
the premium on a note, if any, is not made, the premium will decrease the gain
or increase the loss otherwise recognized on a taxable disposition of the note.
An election to include market discount in income currently, or to amortize
premium, once made, applies to all debt obligations held or subsequently
acquired by the electing U.S. Holder on or after the first day of the first
taxable year to which the election applies and may not be revoked without the
consent of the Internal Revenue Service.
Sale, Exchange or Retirement of the Notes
A U.S. Holder's adjusted tax basis in a note generally will equal the cost
of the note to the U.S. Holder, increased by the amount of any market discount
previously included in gross income, and reduced by the amount of any premium
amortized and payments (other than payments of stated interest) previously
received, by the U.S. Holder with respect to such note. Upon the sale, exchange
or retirement of a note, a U.S. Holder generally will recognize gain or loss
equal to the difference between the amount realized on the sale, exchange or
retirement (other than amounts attributable to accrued but unpaid interest not
previously included in gross income, which will be taxable as ordinary interest
income), and such holder's adjusted tax basis in the note. Subject to the
foregoing discussion regarding the U.S. federal income tax treatment of notes
acquired at a market discount, such gain or loss recognized by a U.S. Holder on
the sale, exchange or retirement of a note generally will be capital gain or
loss and will be long-term capital gain or loss if the note was held for more
than one year at the time of the sale, exchange or retirement. Long-term capital
gain recognized by certain non-corporate U.S. Holders (including individuals)
will generally be subject to U.S. federal income tax at preferential rates. The
deduction of capital losses is subject to
54
limitations for U.S. federal income tax purposes. Gain from the sale, exchange
or retirement of a note by a U.S. Holder generally will be treated as U.S.
source income.
Backup Withholding
A U.S. Holder may be subject to backup withholding at a rate of 30% on
payments of principal of, interest on (and additional amounts, if any), and the
proceeds of disposition of, a note. In general, backup withholding will apply
only if a U.S. Holder fails to comply with certain identification procedures,
fails to properly report payments of interests and dividends or otherwise fails
to comply with applicable requirements of the backup withholdings rules. Backup
withholding will not apply with respect to payments made to certain exempt
recipients, such as corporations and tax-exempt organizations. Backup
withholding is not an additional tax and may be claimed as a credit against the
U.S. federal income tax liability of a U.S. Holder, provided that the required
information is timely furnished to the Internal Revenue Service.
Non-U.S. Holders
A non-U.S. Holder generally will not be subject to U.S. federal income or
withholding tax on (a) interest (and additional amounts, if any) received in
respect of the notes, unless such payments are effectively connected with the
conduct by the non-U.S. Holder of a trade or business in the United States or
(b) gains realized on the sale, exchange or retirement of the note, unless (i)
such gain is effectively connected with the conduct by the non-U.S. Holder of a
trade or business in the United States or (ii) in the case of gain realized by
an individual non-U.S. Holder, such non-U.S. Holder is present in the United
States for 183 days or more in the taxable year of the disposition and certain
other conditions are met.
F. Dividends and Paying Agents
Not applicable.
G. Statements by Experts
Not applicable.
H. Documents on Display
We are subject to the information requirements of the Securities Exchange
Act of 1934, as amended, pursuant to which it files reports and other
information with the Securities and Exchange Commission, or the Commission.
Reports and other information filed by us with the Commission may be inspected
and copies at the public reference facilities maintained by the Commission at
Room 1024, 450 Fifth Street, N.W., Washington, D.C. 20549 and at the
Commission's Regional Offices at Northwestern Atrium Center, 500 West Madison
Street, Suite 1400, Chicago, IL 60661-2511 and 233 Broadway, New York, New York
10279. You may obtain copies of this material by mail from the Public Reference
Section of the Commission, 450 Fifth Street, N.W., Washington, D.C. 20549, at
prescribed rates.
We also file financial statements and other periodic reports with the CVM.
Copies of our annual reports on Form 20-F and documents referred to in this
annual report and our bylaws will be available for inspection upon request at
our headquarters at Rua Sete de Setembro, 362, Vitoria, Espirito Santo, Brazil
29015-000.
I. Subsidiary Information
Not applicable.
55
ITEM 11. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
As a result of its dollar-denominated, short- and long-term debt, we are
exposed to changes in exchange rates between the real and the U.S. dollar. We
are also exposed to changes in interest rates and inflation rates. Virtually all
of our real-denominated, short- and long-term debt bears interest at floating
rates and the principal amount of some of this debt is also indexed for
inflation.
Foreign Exchange Rate Sensitivity
All of the amounts below are in thousands of reais, translated at the
commercial selling rate on December 31, 2001 of R$2.3204 to U.S.$1.00.
Our foreign currency exposure gives rise to market risks associated with
exchange rate movements against the U.S. dollar. Foreign currency denominated
liabilities as of December 31, 2001 include the notes, in the principal amount
of R$999,995, and other U.S. dollar-denominated borrowings in the amount of
R$149,904, for a total of R$1,149,899. In addition to the principal amount to be
paid by ESCELSA in connection with the notes, ESCELSA is required to make
payments of interest on the notes in the amount of R$100,000 per year from 2002
to 2007.
Of the other U.S. dollar-denominated borrowings, in the total amount of
R$149,904 at December 31, 2001, R$56,566 were short-term loans and R$93,338 were
long-term loans. These loans bear interest ranging from 5.0% to 12.0% per annum.
As of December 31, 2001, approximately 99% of our cash and cash
equivalents, in the total amount of R$256,678, were invested in dollar-linked
instruments. We believe that over the long-term we can raise its tariffs in
reais sufficiently to generate cash to pay the principal and interest on the
U.S. dollar-denominated loans, although there can be no assurance in this
regard.
We hedge 99% of our marketable securities with U.S. dollar-linked
instruments.
Interest Rate Sensitivity and Sensitivity to Inflation Rates
We also has loans denominated in reais, which bear interest at variable
rates. The principal amount of certain loans is also indexed to inflation. In
times of high inflation, the Taxa de Juros de Longo Prazo, the Brazilian
long-term interest rate, or TJLP, is generally higher, i.e., the nominal rates
include an inflation factor. The TJLP ranged from 10.0% to 9.25% in 2001, with
an average of 9.50% p.a. Our real-denominated loans bear interest and are
indexed as follows:
Lender Principal Amount Interest Rate Indexation Rate
BNDES.............. R$384,284 TJLP + 4.0% not indexed
Other.............. R$210,695 5 - 12% IGP-M/INPC/UFIR
As demonstrated above, we shall pay interest on the BNDES loans at the rate
of TJLP plus 4% per annum. However, the agreements with BNDES provide that if
the TJLP in a given year is higher than 6% (and, therefore, the total interest
rate would be higher than 10%), we will only be required to pay interest at the
rate of 10% and the excess will be incorporated into the principal amount of the
loan, and amortized over the term of the agreements. As a result, if the TJLP
increased over 6%, there would not be any impact on the interest payments on the
BNDES loans.
Of the debt indexed to inflation, approximately R$76.5 million
corresponding to the ELETROBRAS loan requires payment of principal of R$23
million in 2002. The remainder of this debt, in the amount of R$164.2 million,
is indexed to inflation and has varying payment terms. The contracts with
ELETROBRAS specify that indexation is done only on an annual basis. Therefore,
the payment due in 2002 was indexed to inflation based on the inflation rate for
2001. Only the payment due in 2003 will be indexed to inflation based on the
2002 inflation rate.
56
Expected Maturity Date
There- Fair
2002 2003 2004 2005 2006 2007 2008 after Total Value
LIABILITIES:
Long-Term Debt, including
current portion
Denominated in U.S. dollars
(in thousands):
Fixed Rate ............ 23,997 1,637 6,685 1,530 1,144 431,351 393 5,271 472,010 413,831
Variable Rate
Amount ................ 381 3,109 3,665 3,666 3,520 3,374 2,010 3,826 23,551 23,551
Average interest rate.. LIBOR LIBOR LIBOR LIBOR LIBOR LIBOR LIBOR LIBOR
Spread range is + + + + + + + +
1.0% to 6.9%..... Spread Spread Spread Spread Spread Spread Spread Spread
Average interest rate
considering LIBOR
effective on
December 31, 2001.. 9.6% 10.0% 10.0% 9.9% 9.7% 9.3% 7.0% 7.0%
Denominated in reais
(in thousands):
BNDES financing 73,340 87,650 93,740 58,735 40,749 16,665 6,193 7,212 384,284 384,284
Average interest rate.. TJLP TJLP TJLP TJLP TJLP TJLP TJLP TJLP
Spread range is + + + + + + + +
3.8% to 4.0% Spread Spread Spread Spread Spread Spread Spread Spread
Average interest rate..
Considering TJLP effective
on December 31, 2001 3.9% 3.9% 3.9% 3.9% 3.9% 3.9% 3.9% 3.9%
Other financing............ 100,886 9,874 9,184 3,160 4,060 5,114 3,364 2,273 137,915 137,915
CDI
Average interest rate.. RGPM IGPM IGPM
INPC INPC INPC INPC INPC INPC INPC INPC
Spread range is + + + + + + + +
10% to 12%. Spread Spread Spread Spread Spread Spread Spread Spread
Considering IGP-M effective 8.0% 8.2% 7.9% 8.2% 7.7% 7.6% 7.0% 7.0%
Fixed Rate in reais.... 16,023 4,971 3,947 3,553 3,315 2,837 2,837 15,299 52,782 52,782
Average interest rate.. 7.2% 8.3% 8.3% 8.8% 8.4% 7.8% 7.1% 7.0%
ASSETS:
Denominated in U.S. dollars.... 110,618 110,618 110,618
Average rate................... 10.5% -
ITEM 12. DESCRIPTION OF SECURITIES OTHER THAN EQUITY SECURITIES
Not applicable.
57
PART II
ITEM 1. DEFAULTS, DIVIDEND ARREARAGES AND DELINQUENCIES
Not applicable.
ITEM 2. MATERIAL MODIFICATIONS TO THE RIGHTS OF SECURITY HOLDERS AND USE OF
PROCEEDS
Not applicable.
ITEM 3. [RESERVED]
ITEM 4. [RESERVED]
PART III
ITEM 1. FINANCIAL STATEMENTS
See pages F-1 through F-43, in response to Item 18 of this annual report.
ITEM 2. FINANCIAL STATEMENTS
a) List of financial statements
Page
Report of Independent Public Accountants............................... F-2
Consolidated Balance Sheets as of December 31, 2001 and 2000........... F-4
Consolidated Statements of Operations for the years ended
December 31, 2001, 2000 and 1999....................................... F-6
Consolidated Statements of Changes in Shareholders' equity for the years ended
December 31, 2001, 2000 and 1999....................................... F-7
Consolidated Statements of Changes in Financial Position for the years ended
December 31, 2001, 2000 and 1999....................................... F-8
Consolidated Statements of Cash Flows for the years ended
December 31, 2001, 2000 and 1999....................................... F-10
Notes to the Consolidated Financial Statements for the years ended
December 31, 2001, 2000 and 1999....................................... F-12
ITEM 3. EXHIBITS
None.
58
ANNEX A
GLOSSARY OF TERMS
ANEEL....................... Agencia Nacional de Energia Eletrica, the
Brazilian Electric Energy Regulatory Agency,
responsible for regulating the electric energy
sector.
Average Tariff or Rate...... Total sales revenue divided by total number of
MWh sold for each relevant period. Total sales
revenue, for the purpose of computing average
tariff or rate, consists of gross revenues not
of value-added tax (ICMS).
Capacity Charge............. The charge for purchases or sales based on
contracted firm capacity whether or not used.
Distribution................ Distribution is the transfer of electricity from
transmission lines at supply points on the
network and its delivery to customers through a
distribution system. ESCELSA's distribution
system consists of a widespread network of
primarily above ground networks and lines at
voltages between 11.4kV and 34.5kV. The
electricity is passed through distribution
transformers and is delivered at a voltage of
127 volts to customers in residential, small
industrial and commercial segments as well as to
public utilities and other customers.
Distributors................ An organization supplying electricalenergy to a
group of consumers by means of a distribution
network.
Energy Charge............... Refers to the variable charge for purchases or
sales based on actual electricity consumed.
Final Customer or
Final Consumer
(End User).................. A customer who uses electricity for its own
needs.
Firm Capacity............... The amount of electric energy that can be
delivered from a given power plant with a 95%
degree of certainty (or higher), determined in
accordance with certain prescribed statistical
models.
Gigawatt (GW)............... 1,000,000,000 watts (1,000 megawatts).
Gigawatt-hour (GWh)......... A gigawatt of power that is supplied or demanded
for a period of one hour.
Hydroelectric Plant......... A generation plant which uses water power to
turn an electric generator.
Installed Capacity.......... The amount of electric power that can be
delivered from a given generator at full power
under specified conditions as indicated by the
manufacturer.
Interconnected Power System. Systems or networks connected together by means
of one or more links (lines and/or
transformers).
Interruptible Energy........ The load of certain consumers for which supply
may be interrupted for a specified period of
time as per contractual agreement.
A-1
Kilovolt (kV)............... 1,000 volts.
Kilowatt (kW)............... 1,000 watts.
Kilowatt-hour (kWh)......... A kilowatt of power that is supplied or demanded
for a period of one hour.
Load Factor................. The ratio, expressed as a numerical value or as
a percentage, of the consumption within a
specified period (year, month, day, etc.) to the
consumption that would result from continuous
use of the maximum or other specified demand
occurring within the same period.
Megawatt (MW)............... 1,000,000 watts (1,000 kilowatts).
Megawatt-hour (MWh)......... A megawatt of power that is supplied or demanded
for a period of one hour.
MVA......................... One million volt-amperes.
Peak Load................... The average load (power) during a time interval
of specified duration occurring within a given
period of time, that time interval being
selected during which the average power is
greatest.
Primary Energy.............. The energy generated by hydroelectric and
thermal plants of the system in order to meet
demands for firm service plus reserve
requirements.
Secondary Energy............ See interruptible energy.
South Region................ The States of Parana, Rio Grande do Sul and
Santa Catarina.
Southeast Region............ The States of Sao Paulo, Rio de Janeiro, Minas
Gerais and Espirito Santo.
Substation.................. An assemblage of equipment which interchanges
and/or alters or regulates the voltage of
electricity within transmission and distribution
system.
Thermoelectric Plant........ A generation plant which uses hydrocarbon fuel,
such as coal, oil, diesel, natural gas, as a
source of energy to turn the electric generator.
Transmission................ The transfer of electricity (in lines with
capacity between 750 kV and 34.5 kV) from
generation facilities to the distribution system
in a charge center by means of the transmission
network.
Unbilled Electricity........ Electricity which has been consumed by a
customer, but for which a meter reading has not
been taken, and thus no corresponding invoice
generated.
Volt........................ Standard unit of electric potential or
electromotive force.
Watt........................ The basic unit of electric energy.
Wheeling or Transportation.. A transportation charge expressed in reais.
A-2
INDEX TO FINANCIAL STATEMENTS
Page
Report of Independent Public Accountants................................... F-2
Consolidated Balance Sheets as of December 31, 2001 and 2000............... F-4
Consolidated Statements of Operations for the years ended
December 31, 2001, 2000 and 1999........................................... F-6
Consolidated Statements of Changes in Shareholders' equity for the years
ended December 31, 2001, 2000 and 1999..................................... F-7
Consolidated Statements of Changes in Financial Position for the years
ended December 31, 2001, 2000 and 1999..................................... F-8
Consolidated Statements of Cash Flows for the years ended
December 31, 2001, 2000 and 1999........................................... F-10
Notes to the Consolidated Financial Statements for the years ended
December 31, 2001, 2000 and 1999........................................... F-12
F-1
Report of Independent Public Accountants
To the Board of Directors and Shareholders of
Espirito Santo Centrais Eletricas S.A. - Escelsa:
(1) We have audited the accompanying consolidated balance sheets of ESPIRITO
SANTO CENTRAIS ELETRICAS S.A. - ESCELSA (a Brazilian Corporation) and
subsidiaries ("the Company") as of December 31, 2001 and 2000, and the related
consolidated statements of operations, changes in shareholders' equity and
changes in financial position for each of the three years in the period ended
December 31, 2001. These consolidated financial statements are the
responsibility of the Company's management. Our responsibility is to express an
opinion on these consolidated financial statements based on our audits.
(2) We conducted our audits in accordance with auditing standards generally
accepted in Brazil and the United States of America. Those standards require
that we plan and perform the audit to obtain reasonable assurance about whether
the consolidated financial statements are free of material misstatement. An
audit includes examining, on a test basis, evidence supporting the amounts and
disclosures in the consolidated financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
(3) In our opinion, the consolidated financial statements referred to in
paragraph (1) present fairly, in all material respects, the consolidated
financial position of Espirito Santo Centrais Eletricas S.A. - Escelsa and
subsidiaries as of December 31, 2001 and 2000, and the results of their
operations, changes in shareholders' equity and changes in their financial
position for each of the three years in the period ended December 31, 2001 in
conformity with accounting principles generally accepted in Brazil.
(4) Our audits were conducted for the purpose of forming an opinion on the basic
financial statements taken as a whole. The consolidated statements of cash flows
for each of the three years in the period ended December 31, 2001 are presented
for purposes of additional analysis and are not a required part of the basic
financial statements under accounting principles generally accepted in Brazil.
Such information has been subjected to the auditing procedures applied in the
audit of the basic financial statements and, in our opinion, is fairly stated in
all material respects in relation to the basic financial statements taken as a
whole.
(5) Accounting practices of the Company used in preparing the accompanying
financial statements conform with accounting principles generally accepted in
Brazil (Brazilian GAAP), which vary in certain respects from accounting
principles generally accepted in the United States of America ("US GAAP"). The
application of accounting principles generally accepted in the United States of
America would have affected results of operations for each of the three years in
the period ended December 31, 2001 and shareholders' equity of Espirito Santo
Centrais Eletricas S.A. - Escelsa and subsidiaries as of December 31, 2001 and
2000 to the extent summarized in Note 25 to the consolidated financial
statements. As more fully described in Note 25.2. (c), the reported amounts of
shareholders' equity and the net income (loss) as of December 31, 2000 and 1999
under US GAAP have been restated for certain accounting errors for the years
presented.
F-2
(6) As commented in Notes 5 and 7, the Company and its subsidiary, Enersul,
recorded in the financial statements as of December 31, 2001, regulatory assets
related to the recovery of revenue losses during the energy rationing period and
prepaid expenses related to variations of Parcel A costs (CVA) resulting from
the application of Executive Act No. 14 (approved on April 26, 2002 by Law No.
10,438), Resolution No. 90 of the National Electric Energy Agency (ANEEL) and
Resolution No. 91 of the Energy Crisis Management Committee (GCE). Additionally,
the Company and its subsidiary, Enersul, recorded assets and liabilities related
to the sale and purchase of energy within the context of the Wholesale Energy
Market (MAE), based on internal estimates, in accordance with guidance provided
by ANEEL. The amounts related to tariff recovery for the energy rationing period
and the prepaid expenses related to variations of Parcel A costs (CVA) will be
realized by means of extraordinary tariff increases already approved by specific
resolutions of ANEEL, as well as through inclusion of the CVA in the annual
analysis of tariff adjustments.
Vitoria , Brazil,
Deloitte Touche Tohmatsu
June 3, 2002.
F-3
ESPIRITO SANTO CENTRAIS ELETRICAS S.A. - ESCELSA AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS AS OF DECEMBER 31, 2001 AND 2000
(In thousands of Brazilian reais at December 31, 2001 and thousands of
constant Brazilian reais as of December 31, 2000 )
A S S E T S
2 0 0 1 2 0 0 0
------------ ------------
CURRENT ASSETS:
Cash and cash equivalents 2,637 5,746
Marketable securities 256,859 272,045
Accounts receivable 323,641 191,651
Allowance for doubtful accounts (28,778) (7,856)
Other accounts receivable 32,329 30,395
Recoverable taxes 67,209 20,233
Material and supplies 7,255 5,736
Escrow deposits 39,382 39,382
Prepaid expenses 795 5,219
Deferred regulatory assets - parcel A costs 7,815 -
Other credits 22,453 24,108
----------- ------------
731,597 586,659
----------- ------------
LONG-TERM ASSETS:
Accounts receivable 258,462 24,902
Bonus paid to consumers and costs incurred -
Emergency rationing program 47,664 -
Affiliates and subsidiaries 52,849 45,666
Accounts receivable - UTE Campo Grande - 30,054
Debt issuance costs 3,426 4,195
Escrow deposits and others 80,429 60,406
Deferred income taxes 231,309 230,295
Deferred regulatory assets - parcel A costs 86,002 -
Others 11,425 2,909
----------- ------------
771,566 398,427
----------- ------------
PERMANENT ASSETS:
Investments 2,700 6,983
Property, plant and equipment 2,293,555 2,270,049
Goodwill 439,770 442,781
----------- ------------
2,736,025 2,719,813
----------- ------------
TOTAL ASSETS 4,239,188 3,704,899
=========== ============
The accompanying notes are an integral part of
these consolidated balance sheets.
F-4
ESPIRITO SANTO CENTRAIS ELETRICAS S.A. - ESCELSA AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS AS OF DECEMBER 31, 2001 AND 2000
(In thousands of Brazilian reais at December 31, 2001 and thousands of
constant Brazilian reais as of
December 31, 2000)
LIABILITIES AND SHAREHOLDERS' EQUITY
2 0 0 1 2 0 0 0
------------ -----------
CURRENT LIABILITIES:
Suppliers 178,976 106,961
Accrued Payroll 2,389 2,562
Accrued interest and fees 52,787 43,958
Regulatory charges payable 13,240 18,442
Accrued taxes and social contributions 48,235 43,024
Dividends payable 4,083 14,422
Loans and financing 246,815 128,308
Accrued pension and other postretirement benefits 2,420 -
Accrued liabilities 22,016 10,227
Accrual for contingencies 39,382 39,382
Others 12,628 29,610
------------ -----------
622,971 436,896
------------ -----------
LONG-TERM LIABILITIES:
Suppliers 84,600 -
Deferred income taxes 214,093 236,329
Surtax charged to consumers - Emergency rationing program 13,148 -
Accrued interest and fees 1,289 -
Loans and financing 1,498,063 1,293,277
Accrued pension and other postretirement benefits 28,031 -
Accrual for contingencies 139,811 68,087
Others 35,694 12,226
------------ ------------
2,014,729 1,609,919
Special liabilities 262,320 247,547
------------ ------------
2,277,049 1,857,466
------------ ------------
MINORITY INTEREST 245,343 238,558
------------ ------------
SHAREHOLDERS' EQUITY:
Capital stock 239,141 239,141
Capital reserves 849,422 924,069
Income reserves - 3,507
------------ ------------
1,088,563 1,166,717
Advances for capital increase 5,262 5,262
------------ ------------
1,093,825 1,171,979
------------ ------------
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY 4,239,188 3,704,899
============ ============
The accompanying notes are an integral part of these consolidated
balance sheets.
F-5
ESPIRITO SANTO CENTRAIS ELETRICAS S.A. - ESCELSA AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
FOR THE YEARS ENDED DECEMBER 31, 2001, 2000 AND 1999
(In thousands of Brazilian reais at December 31, 2001 and thousands of
constant Brazilian reais as of December 31, 2000, except per share amounts)
2001 2000 1999
--------------- ------------- -------------
OPERATING REVENUES:
Electricity sales to final customers 1,617,617 1,313,126 1,237,819
Electricity sales to distributors 83,519 42,723 39,072
Other revenues 29,646 32,944 22,149
--------------- ------------- -------------
1,730,782 1,388,793 1,299,040
TAXES ON SALES (345,297) (330,229) (308,558)
--------------- ------------- -------------
Net operating revenues 1,385,485 1,058,564 990,482
--------------- ------------- -------------
OPERATING EXPENSES:
Electricity purchased for resale (675,189) (500,139) (501,102)
Depreciation and amortization (149,138) (140,906) (129,353)
Personnel (108,271) (115,014) (130,265)
Regulatory charges (95,852) (98,233) (63,947)
Materials (20,964) (17,364) (22,102)
Third party services (53,640) (55,834) (54,091)
Other expenses (82,510) (24,061) (56,230)
--------------- ------------- -------------
(1,185,564) (951,551) (957,090)
--------------- ------------- -------------
RESULT BEFORE FINANCIAL EXPENSES 199,921 107,013 33,392
FINANCIAL EXPENSES, NET (235,831) (23,499) (119,345)
--------------- ------------- -------------
INCOME (LOSS) FROM OPERATIONS (35,910) 83,514 (85,953)
NON-OPERATING EXPENSES, NET (24,384) (13,325) (14,339)
--------------- ------------- -------------
INCOME (LOSS) BEFORE INCOME TAX, SOCIAL (60,294) 70,189 (100,292)
CONTRIBUTION AND MINORITY INTEREST
INCOME TAX AND SOCIAL CONTRIBUTION
Current (2,189) (863) -
Deferred 13,201 (13,365) 69,503
--------------- ------------- -------------
11,012 (14,228) 69,503
--------------- ------------- -------------
MINORITY INTEREST (10,794) (3,314) 13,509
--------------- ------------- -------------
NET INCOME (LOSS) (60,076) 52,647 (17,280)
=============== ============= =============
SHARES OUTSTANDING AT YEAR END 4,550,833 4,550,833 4,550,833
=============== ============= =============
NET INCOME (LOSS) PER SHARE - R$ (13.20) 11.57 (3.80)
=============== ============= =============
The accompanying notes are an integral part of these
consolidated statements.
F-6
ESPIRITO SANTO CENTRAIS ELETRICAS S.A. - ESCELSA AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS' EQUITY
FOR THE YEARS ENDED DECEMBER 31, 2001, 2000 AND 1999
(In thousands of Brazilian reais at December 31, 2001
and thousands of constant Brazilian reais as of
December 31, 2000)
Advance
for
Capital Capital Income Retained Capital
Stock Reserves reserves Earnings Subtotal increase Total
--------- ---------- ---------- ------------ ----------- ---------- -----------
BALANCES AS OF DECEMBER 31, 1998 239,141 918,075 127,388 - 1,284,604 5,262 1,289,866
Proposed dividends (R$6.60 reais per share) - - (30,043) - (30,043) - (30,043)
Remuneration on construction work in progress - 17,927 - - 17,927 - 17,927
Income reserve - - (10,344) 10,344 - - -
Deferred income tax on price-level - - - (91,998) (91,998) - (91,998)
restatement of shareholders equity
Loss for the year - - - (17,280) (17,280) - (17,280)
Absorption of loss (11,933) (87,001) 98,934 - - -
--------- ---------- ---------- ------------ ----------- ---------- -----------
BALANCES AS OF DECEMBER 31, 1999 239,141 924,069 - - 1,163,210 5,262 1,168,472
Deferred income tax on price-level - - - (35,895) (35,895) - (35,895)
restatement of shareholders equity
Net income for the year - - - 52,647 52,647 - 52,647
Proposed destination of net income for the year- - - 188 (188) - - -
Legal reserve
Proposed dividends (R$2.91 reais per share) - - (9,681) (3,564) (13,245) - (13,245)
Income reserve - - 13,000 (13,000) - - -
--------- ---------- ---------- ------------ ----------- ---------- -----------
BALANCES AS OF DECEMBER 31, 2000 239,141 924,069 3,507 - 1,166,717 5,262 1,171,979
Remuneration on construction work in progress - 2,325 - - 2,325 - 2,325
Prior year adjustment - recognition of pension
and other postretirement obligations under CVM
Instruction No. 371 (See note 22) - - - (20,403) (20,403) - (20,403)
Loss for the year - - - (60,076) (60,076) - (60,076)
Absorption of loss - (76,972) (3,507) 80,479 - - -
--------- ---------- ---------- ------------ ----------- ---------- -----------
BALANCES AS OF DECEMBER 31, 2001 239,141 849,422 - - 1,088,563 5,262 1,093,825
========= ========== ========== ============ =========== ========== ===========
The accompanying notes are an integral part of these
consolidated statements.
F-7
1 of 2
ESPIRITO SANTO CENTRAIS ELETRICAS S.A. - ESCELSA AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN FINANCIAL POSITION
FOR THE YEARS ENDED DECEMBER 31, 2001, 2000 AND 1999
(In thousands of Brazilian reais at December 31, 2001 and thousands
of constant Brazilian reais as of December 31, 2000)
2 0 0 1 2 0 0 0 1999
----------------- ---------------- ------------------
SOURCES OF FUNDS:
From operations
Net Income (loss) (60,076) 52,647 (17,280)
Expenses (income) not affecting net working capital:
Monetary and foreign exchange variation on long-term assets 176,462 (7,134) 100,180
and liabilities
Depreciation and amortization 149,138 140,906 129,353
Loss on disposal of property, plant and equipment 25,266 17,026 19,105
Deferred income taxes (13,201) 13,365 (69,503)
Regulatory assets (138,591) - -
Provision for loss on investment 12,428 - -
Provision for contingencies 71,724 2,180 5,959
Minority interest 10,794 3,314 (13,509)
Others (1,436) - -
----------------- ---------------- ------------------
232,508 222,304 154,305
----------------- ---------------- ------------------
From third parties
Loans and financing 124,890 71,082 110,631
Accrual for pension and other postretirement benefits 7,629 - -
Decrease in long-term assets 49,856 - -
Affiliates and subsidiaries 15,359 - -
Consumer contributions and donations 14,773 5,038 5,865
Proceeds from sale of investment 3,718 - -
Others 5,780 6,129 3,851
----------------- ---------------- ------------------
222,005 82,249 120,347
----------------- ---------------- ------------------
Total sources of funds 454,513 304,553 274,652
----------------- ---------------- ------------------
APPLICATIONS OF FUNDS:
Increase in long-term assets 51,941 39,973 45,477
Additions to property, plant and equipment 188,349 180,919 214,388
Investments - 2,394 26,717
Deferred regulatory assets - parcel A costs 86,002 - -
Transfer from long-term liabilities to current liabilities 80,542 85,087 78,729
Proposed dividends 4,083 16,559 30,043
Re-purchase of senior notes - - 37,003
Bonus paid to consumers and costs incurred-emergency 34,516 - -
rationing program
Related parties 47,237 24,093 -
Others 2,980 - -
----------------- ---------------- ------------------
Total applications of funds 495,650 349,025 432,357
----------------- ---------------- ------------------
DECREASE IN WORKING CAPITAL (41,137) (44,472) (157,705)
----------------- ---------------- ------------------
F-8
Changes in components of working capital
Current assets
At beginning of year 586,659 595,728 776,724
At end of year 731,597 586,659 595,728
----------------- ---------------- ------------------
144,938 (9,069) (180,996)
----------------- ---------------- ------------------
Current liabilities
At beginning of year 436,896 401,493 424,784
At end of year 622,971 436,896 401,493
----------------- ---------------- ------------------
186,075 35,403 (23,291)
----------------- ---------------- ------------------
DECREASE IN WORKING CAPITAL (41,137) (44,472) (157,705)
----------------- ---------------- ------------------
The accompanying notes are an integral part of these
consolidated statements.
F-9
1 of 2
ESPIRITO SANTO CENTRAIS ELETRICAS S.A. - ESCELSA AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
FOR THE YEARS ENDED DECEMBER 31, 2001, 2000 AND 1999
(In thousands of Brazilian reais at December 31, 2001
and thousands of constant Brazilian reais as of
December 31, 2000)
2 0 0 1 2 0 0 0 1999
-----------------------------------------------------
Operating activities
Net income (loss) for the year (60,076) 52,647 (17,280)
Adjustments to reconcile net income (loss) to cash provided by
operating activities
Monetary and exchange variation on long-term asset and
liabilities 176,462 (7,134) 100,180
Depreciation and amortization 149,138 140,906 129,353
Allowance for doubtful accounts 20,922 (1,229) (1,623)
Loss on disposal of property, plant and equipment 25,266 17,026 19,105
Accrual for contingencies 71,724 2,180 5,959
Interest accrued on marketable securities (12,388) (35,094) (41,835)
Gain on extinguishment of debt, net of applicable tax effect - - (10,325)
Provision for loss on investment 12,428 - -
Regulatory assets (218,056) - -
Minority interest 10,794 3,314 (13,509)
Deferred income taxes (13,201) 13,365 (69,503)
Others (1,436) (342)
-----------------------------------------------------
161,577 185,639 100,522
-----------------------------------------------------
Changes in operating assets and liabilities
Accounts receivable (62,894) (45,212) (12,368)
Marketable securities 29,232 1,212 7,180
Other accounts receivable (1,934) (4,722) (18,250)
Recoverable taxes (46,976) 1,870 (751)
Bonus paid and costs incurred - emergency rationing program (34,516) - -
Deferred regulatory asset - parcel A costs (86,002) - -
Material and supplies (1,519) 3,665 1,662
Escrow deposits (19,203) (6,863) (16,591)
Prepaid expenses (3,391) 7,938 (390)
Suppliers 72,015 24,375 6,664
Accrued payroll (173) (889) 3,451
Accrued taxes and social contributions 5,211 (58) 1,673
Accrued liabilities 11,789 (1,007) (1,243)
Regulatory charges payable (5,202) (555) 97
Accounts receivable - UTE Campo Grande 30,054 3,957 (34,132)
Accrued interest and fees 10,887 (2,408) (3,955)
Re-purchase of senior notes - - (37,003)
Others (4,557) 4,109 7,951
-----------------------------------------------------
(107,179) (14,588) (96,005)
-----------------------------------------------------
Net cash provided by operating activities 54,398 171,051 4,517
-----------------------------------------------------
F-10
2 of 2
Investing activities
Additions to property, plant and equipment (181,065) (180,919) (214,388)
Proceeds from sale of investments 3,718 - -
Additions to investments - (2,394) (26,717)
Net proceeds from marketable securities 1,658 59,025 257,432
Affiliates and subsidiaries (18,368) (12,244) (19,350)
Consumers' contributions and donations-special liabilities 14,773 5,038 5,962
-----------------------------------------------------
Net cash provided by (used in) investing activities (179,284) (131,494) 2,939
-----------------------------------------------------
Financing activities
Proceeds from new loans and financing 354,587 115,379 156,565
Repayment of loan and financing (215,031) (156,421) (87,629)
Dividends paid (17,779) (1,284) (77,184)
-----------------------------------------------------
Net cash provided by (used in) financing activities 121,777 (42,326) (8,248)
-----------------------------------------------------
Net decrease in cash and cash equivalents (3,109) (2,769) (792)
Cash and cash equivalents, beginning of year 5,746 8,515 9,307
-----------------------------------------------------
Cash and cash equivalents, end of year 2,637 5,746 8,515
=====================================================
Supplemental cash flows disclosure-
Taxes paid 46,976 10,620 -
Interest paid, net of interest capitalized 142,342 134,335 92,365
The accompanying notes are an integral
part of these consolidated statements.
F-11
ESPIRITO SANTO CENTRAIS ELETRICAS S.A. - ESCELSA AND SUBSIDIARIES
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
FOR THE YEARS ENDED DECEMBER 31, 2001, 2000 AND 1999
(In thousands of Brazilian reais at December 31, 2001 and thousands of
constant Brazilian reais as of December 31, 2000, unless otherwise noted)
1. THE COMPANY AND ITS OPERATIONS
a. The Company
Espirito Santo Centrais Eletricas S.A. - Escelsa, a Brazilian corporation
("sociedade anonima") located in the city of Vitoria, State of Espirito Santo,
was incorporated on July 1, 1968, as a mixed capital corporation ("sociedade de
economia mista") with limited liability, organized under the laws of Brazil and
controlled by Centrais Eletricas Brasileiras S.A. - Eletrobras, a company
controlled by the Brazilian federal government. In the privatization auction
held on July 11, 1995, 50% (plus one share) of the common shares of Escelsa were
acquired by Iven S.A. and GTD Participacoes S.A. On January 19, 1996, Escelsa
became a registrant with the Comissao de Valores Mobiliarios (the "CVM"), the
Brazilian Securities Commission, and presently, its shares are traded on
Brazilian stock exchanges in small amounts. Escelsa's core business is the
planning, construction and operation of systems for electricity generation,
transmission, distribution and the sale of electric energy in the State of
Espirito Santo.
The Company also has a wholly-owned subsidiary, Magistra Participacoes S.A.,
which has a 76.5% and 41.8% interest in the common and preferred shares of
Empresa Energetica do Mato Grosso do Sul S.A. - Enersul ("Enersul"),
respectively. Enersul, which was acquired in a privatization bid auction on
November 25, 1997, is an electricity generation, distribution and transmission
company with operations in the state of Mato Grosso do Sul. The Company also has
a 97,40% participation in TV A Cabo Vitoria S.A. - TVIX, which was created on
July 4, 1997 and provides cable TV service to condominiums and residences in the
municipalities of Vitoria and Vila Velha in Espirito Santo. The Company has a
100% participation in ESCELSA Participacoes S.A. - ESCELSAPAR, which provides
internet and information technology services.
ENERSUL is taking steps to raise long-term funding through domestic and
international banks in light of its liquidity position as of December 31, 2001
and to improve its overall debt profile, both in terms of costs and maturity.
ENERSUL obtained the following lines of credit from the BNDES (Brazilian
Economic and Social Development Bank) (see additional comments below under part
c of this section):
o Advance of R$71,553 related to 90% of the revenue losses due to
rationing (June 2001 through February 2002), which will be amortized
through an extraordinary tariff recovery, of which R$22,010 was made
available in 2002;
o Financing of R$33,000 for the capital investment program for the
period 2001 through 2003;
o As per Resolution 123/CGE of March 15, 2002, the Emergency Crisis
Management Chamber authorized financing in the amount of R$22,000,
corresponding to 90% of "Parcel A" costs (non-controllable costs) for
2001.
Management expects that with measures taken and lines of credit obtained, that
the Company's liquidity will improve, as will the profitability of its
operations.
F-12
b. Regulatory environment
As a public concessionaire of electric utility services, the parent Company and
its subsidiary Enersul are subject to regulations established by the Agencia
Nacional de Energia Eletrica (the National Agency of Electric Power, or
"ANEEL"), successor to the "Departamento Nacional de Aguas e Energia Eletrica"
("DNAEE"), which is related to the Brazilian Ministry of Mines and Energy.
Supplying electric energy to over 90% of the State of Espirito Santo, with about
3.0 million people and a concession area of 41,372 km2, Escelsa connected 57,385
new consumers in 2001 with a total of 922,579 electric energy consumers as of
December 31, 2001. Escelsa generated from its 10 power plants approximately 12%
of its energy sold. (All information unaudited.)
The electricity sector in Brazil is regulated by the Brazilian federal
government, acting through the Ministry of Mines and Energy, which has exclusive
authority over the electricity sector through regulatory powers assigned to it.
Regulatory policy for the sector is implemented by an autonomous national
electric energy agency (Agencia Nacional de Energia Eletrica or "ANEEL"). ANEEL
is responsible for (1) granting and supervising concessions for the setting of
electricity tariffs; (2) supervising and performing financial examinations of
the concessionary companies; (3) issuing regulations for the electricity sector;
and (4) planning, coordinating and executing water resource studies and granting
and supervising concessions for the use of water resources. The Company's
electricity business is subject to regulation by the Brazilian regulatory
authority, ANEEL. Retail electricity sales by the Company are made pursuant to
provisions of its long-term electricity sales concession agreements.
Pursuant to a concession contract signed by Escelsa on July 17, 1995 (the
"Escelsa Concession Contract"), Escelsa was granted the right to supply
electricity in 70 of the 77 municipalities that comprise the State of Espirito
Santo through the year 2025. In 2025, the Escelsa Concession Contract may be
renewed, at the discretion of the regulatory authorities, for an additional 30
years. Escelsa also currently owns ten-generation plants pursuant to concessions
that were granted through year 2025. The Escelsa Concession Contract establishes
a price cap tariff mechanism with three types of adjustments. Escelsa may
periodically apply for the first type of adjustment, which takes into account
the effects of inflation on Escelsa's tariffs in order to maintain the "economic
and financial equilibrium" of Escelsa. The second type of adjustment permits
Escelsa to request revisions to its tariff rates from time to time, generally to
pass through significant changes in its cost structure that it does not control,
particularly the cost of electricity it purchases, that affect the "economic and
financial equilibrium" of Escelsa. In addition, ANEEL has the right, every three
years, beginning in July 1998, to adjust Escelsa's price cap.
Escelsa primarily purchases electricity from Furnas Centrais Eletricas S.A. -
Furnas ("Furnas") (under a long-term electric energy supply contract) - (see
note 12), which represented approximately 83.9% of its total energy sold. From
the total energy supplied by Furnas, approximately 30.2% is generated by Itaipu
(hydroelectric plant owned by Itaipu Binacional) and approximately 70% is
generated by its own power plants.
Pursuant to the Enersul Concession Contract, Enersul was granted the right to
distribute electricity in 72 of the 77 municipalities in Mato Grosso do Sul
through year 2027. Supplying electric energy to over 90% of the State of Mato
Grosso do Sul , with about 1.9 million people and a concession area of 329,270
km2, Enersul connected 57,385 new consumers in 2001 with a total of 2,672GWh
electric energy consumers as of December 31, 2001. Enersul generated from its 7
power plants approximately 7.5% of its energy sold. (All information
unaudited.).
In 2027, the Enersul Concession Contract may be renewed, at the discretion of
the regulatory authorities, for additional 30 years. Enersul also currently owns
one-generation plant (Mimoso) owned by Enersul pursuant to a concession that was
granted through the year 2027. The installed capacity of each of the other ten
plants is less than the minimum, which requires a concession contract.
The Enersul Concession Contract establishes a price cap tariff mechanism with a
tariff adjustment formula (the "Formula"). The Formula is adjusted annually and,
in the case of significant increases, may be adjusted upon request of Enersul.
The numerator of the Formula is comprised of two components: one related to
costs that Enersul does not control and should therefore be permitted to pass
through to its final customers, including the cost of electricity it purchases
and certain taxes, referred to as Parcel A costs, and the other related to costs
related to transmission, distribution and its own generation, such as
depreciation and amortization, personnel, materials and third party expenses,
that are adjusted to protect the utility against the effects of inflation,
referred to as Parcel B costs. The denominator of the
F-13
Formula is Enersul's annual net revenues. In addition, ANEEL has the right,
every five years, to adjust Enersul's price cap to take into account efficiency
gains achieved by Enersul, technological advances or improvements, a comparison
of Enersul's tariffs with tariffs of foreign companies and the Brazilian
economic situation.
Enersul primarily purchases electricity from Gerasul and Itaipu (under a
long-term electric energy supply contract) - approximately 86% of its total
energy needs.
As a result of changes in regulation in December 2001, the pricing provisions of
the contract are now linked to a tracking account which permits tariff changes
for events such as exchange rate changes between the Brazilian real and the U.S.
dollar. In addition to the annual adjustment, the Company has the option to
request additional rate adjustments arising from significant events which
disrupt the economic and financial equilibrium of the business. Other normal, or
recurring, events are also included as a specific tariff increase and may
include normal increases in purchased power costs, taxes on revenue generated or
local inflation. The Company has the burden to prove the impact on its financial
or economic equilibrium, and there can be no assurance that such adjustments
will be granted.
c. Power Rationing and Government Measures to Compensate Electric Utilities
Low amounts of rainfall in 2000 and early 2001, vigorous growth in demand for
energy and Brazil's significant dependence on electricity generated from
hydrological resources resulted in abnormally low water levels in many
reservoirs that are used to power Brazil's major hydroelectric generation
facilities. In May 2001, the Federal Government announced several measures in
response to these conditions. First, the President of Brazil passed Provisional
Measure No. 2,147 on May 15, 2001 (as updated by Provisional Measure No. 2,152-2
on June 1, 2001), creating the Camara de Gestao da Crise de Energia Eletrica, or
Enery Crisis Committee. The Energy Crisis Committee resolved on May 16, 2001 to
require certain electricity distributors, including us, to suspend distribution
of electricity to new customers (except residential and rural customers) and for
certain non-essential purposes such as nighttime sporting events and advertising
use, and to reduce distribution for the illumination of public areas by 35%.
Second, the President passed Decree No. 3,818 on May 15, 2001, requiring the
Federal Government to reduce its electricity consumption by 35% beginning July
1, 2001. Third, on May 18, 2001, the Federal Government announced additional
power rationing measures to be imposed on industrial, commercial and residential
customers in the most industrialized and heavily populate areas of Brazil
beginning on June 1, 2001. These measures required most residential consumers to
reduce their electricity consumption by 20% of the average consumption in May,
June and July 2000. Industrial and commercial consumers also had to reduce their
consumption by 15% to 25% of the average consumption during the same period.
Further measures provided that bonuses would be paid to residential consumers
whose energy consumption was lower than the requisite target and that power cuts
and surcharges would be imposed on consumers whose energy consumption exceeded
the requisite target. ANEEL established specific accounts and controls to record
the effect of the rationing measures relating to the bonus, surcharge and other
related costs. The power rationing measures ultimately ceased on March 1, 2002.
On October 17, 2001, the Federal Government, through Provisional Measure No. 4,
subsequently approved by Law No. 10,310 of November 22, 2001, stated that
electric utilities, including us, will be reimbursed for expenses associated
with payment of bonuses to consumers and other related costs that exceeded the
surcharges. The Energy Crisis Committee is expected to establish the procedures
and deadlines relating to such reimbursement and any reimbursement will be
subject to ANEEL's approval.
On December 12, 2001, through Provisional Measure No. 14, approved on April 26,
2002 by Law No. 10,438, the Federal Government authorized the creation of the
General Agreement of the Electricity Sector. The General Agreement of the
Electricity Sector provides that electric power distribution companies in
Brazil, such as us, will be compensated for revenue losses caused by the
reduction in amounts of energy sold due to the Federal Government-mandated
rationing measures. Compensation will be made by means of an increase in the
energy rate applicable to future power sales and companies will be entitled to
use this increased rate only until they are fully compensated for their
rationing-related losses. The General Agreement of the Electricity Sector
further provides for Banco Nacional de Desenvolvimento Economico e Social
(National Bank for Economic and Social Development), or BNDES, to lend the
distribution companies an amount equivalent to their lost revenues so that these
companies would be able to maintain their account balances as if no rationing
program had taken place. This loan would then be re-paid to BNDES using revenue
obtained from the sale of energy to consumers at the increased rate.
F-14
2. BASIS FOR PRESENTATION OF THE
FINANCIAL STATEMENTS
a. Requirements of Brazilian Legislation through December 31, 1995
Until December 31, 1995, publicly traded companies were required to publish
financial statements prepared pursuant to two methods: (i) the corporate law
method, which was valid for all legal purposes, and (ii) the constant currency
method, pursuant to which publicly traded companies presented supplementary
price-level adjusted financial statements.
Under the constant currency method, all historical Brazilian real amounts were
expressed in constant purchasing power at the latest balance sheet date. These
standards required that all transactions and balances recorded in a company's
statutory accounts under the corporate law method be monetarily restated to
reflect the changes caused by inflation (as measured by a specified inflation
index) from the date they occurred or were generated to the latest balance sheet
date. Accordingly, all relevant non-monetary assets and liabilities and
shareholders' equity accounts and all components of the statements of income,
changes in financial position and changes in shareholders' equity and the notes
thereto were monetarily restated to reflect changes in the inflation index to
the latest balance sheet date.
The gains and losses on monetary assets and liabilities attributable to changes
in index, calculated on a monthly basis, were allocated to the corresponding
income or expense components in the statement of operations (see Note 25).
b. Changes in Legislation Affecting Financial
Statements After December 31, 1995
On December 26, 1995, the Brazilian government enacted Law no. 9,249 which
eliminated inflation accounting for the effects of inflation as from January 1,
1996 for tax and financial reporting purposes. However, Brazilian GAAP continued
to require inflation accounting up to December 31, 2000.
On March 19, 1996, the CVM issued Instruction no. 248 stating that quarterly and
annual financial statements should be prepared in accordance with the Corporate
Law method (which did not account for the effects of inflation). However,
companies were allowed to present supplemental price-level adjusted financial
information, in accordance with the standards previously adopted. If a company
elected to prepare price-leveladjusted financial statements for use outside
Brazil, such statements should also be filed with the CVM in Brazil.
With the change in legislation, the CVM did not define a specific index to be
used for the preparation of optional price-level adjusted financial statements.
The Brazilian Institute of Independent Public Accountants ("IBRACON")
recommended that either the IGP-M or the IGP-DI indices computed by the Getulio
Vargas Foundation be used for this purpose.
The Company's management believed that the General Market Price Index, or the
"IGP-M" index was the most appropriate and consistent measure of inflation in
Brazil and elected the IGP-M for purposes of remeasurement of its financial
statements under the constant currency method, as from January 1, 1996, through
December 31, 2000. The inflation rate based on the IGP-M was 20% and 10% for
1999 and 2000, respectively. For 1998, as the inflation rate was less than 2%,
the constant currency method was not applied to the accounts.
In March 2001, the "Conselho Federal de Contabilidade - CFC " issued Resolution
No. 900, which was also approved by the CVM, establishing that inflation
accounting was no longer required under Brazilian GAAP, as of January 1, 2001,
as long as cumulative inflation over a three-year period remains under 100%.
Therefore, since Brazil's cumulative inflation for the three year period ended
December 31, 2001 has been under 100% the financial statements for 2001 are
expressed in nominal reais. Financial statements for periods prior to December
31, 2001 are expressed in constant Brazilian reais of December 31, 2000
purchasing power.
F-15
c. Presentation of Financial Statements
For Brazilian official financial reporting purposes, the Company prepared its
2000 and 1999 financial statements under both the corporate law and constant
currency methods. As explained in letter b above, no inflation effects were
recognized after December 31, 2000. The accompanying financial statements are a
translation and adaptation of the financial statements previously published in
the Portuguese language. Certain reclassifications and changes in terminology
have been made in relation to the previously published financial statements, and
additionally these notes have been expanded to conform more closely to the
reporting practices prevailing in the United States.
The reconciliation of shareholders' equity and net income reported under the
corporate law method and the amounts reflected in the accompanying consolidated
financial statements for 2001, 2000 and 1999 are as follows:
(i) Shareholders' Equity
-------------------------------
2001 2000
-------------- ---------------
As reported in the corporate law financial statements 731,403 775,617
Price-level adjustments to December 31, 2000 - -
-------------- ---------------
Amounts restated to December 31, 2000 price-level (through
December 31, 2000 only) 731,403 775,617
Accounting for 2000 and 1999 inflation not allowed
Under corporate law method-
Investments 333 785
Goodwill 56,801 57,185
Property, plant and equipment 617,802 677,253
Special liabilities (79,623) (79,623)
Income tax and social contribution effect (177,709) (197,473)
Minority interest (55,182) (61,765)
-------------- ---------------
As reported in the accompanying financial statements (adjusted for
price-level changes through December 31, 2000) 1,093,825 1,171,979
============== ===============
(ii) Net Income
December 31,
-------------------------------------------
2001 2000 1999
------------- -------------- --------------
As reported in the corporate law financial statements (26,136) 3,752 (131,111)
Price-level adjustment to December 31, 2000 - - (13,046)
------------- -------------- --------------
Amounts restated to December 31, 2000 price-level (through December
31, 2000 only) (26,136) 3,752 (144,157)
Accounting 2000 and 1999 for inflation not allowed-
Under corporate law method-
Investments (452) 244 821
Goodwill - net of amortization (384) 38,268 83,439
Property, plant and equipment - net of depreciation (59,451) 108,407 298,472
Special liabilities - (16,471) (33,947)
Shareholders' equity - (78,122) (199,790)
Income tax and social contribution effect 19,764 (4,639) (21,634)
Minority interest 6,583 1,208 (484)
------------- -------------- --------------
As reported in the accompanying financial statements (adjusted for
price-level changes through December 31, 2000) (60,076) 52,647 (17,280)
============= ============== ==============
F-16
3. SUMMARY OF ACCOUNTING POLICIES
The Company's accounting policies comply with Brazilian GAAP, which include the
accounting principles specifically applicable to electric utility companies in
Brazil as required by ANEEL. Certain accounting policies differ from US GAAP.
See Note 25 for further discussions of the differences and the reconciliation of
shareholders' equity and net income to US GAAP.
3.1 - Regulated Accounting Policies
(a) Regulation -- As a result of various actions taken by the Federal
Government and ANEEL in 2001 (see note 1.c.), the Company capitalizes
incurred allowable costs as deferred regulatory assets when there is a
probable expectation that future revenue equal to the costs incurred will
be billed and collected as a direct result of the inclusion of the costs in
an increased rate set by the regulator. The deferred regulatory asset is
eliminated when the Company collects the related costs through billings to
customers. ANEEL performs a rate review on an annual basis. If ANEEL
excludes all or part of a cost from recovery, that portion of the deferred
regulatory asset is impaired and is accordingly reduced to the extent of
the excluded cost. The Company has recorded deferred regulatory assets of
R$392,352 at December 31, 2001, that it expects to pass through to its
customers in accordance with and subject to regulatory provisions. The
regulatory assets include R$213,934 and R$93,818 at December 31, 2001, for
recovery of lost revenues due to rationing and Parcel A costs incurred in
2001, respectively. Additionally, the Company recorded deferred regulatory
assets for the cost of energy traded on the spot market (energy not traded
pursuant to contracts during the rationing period) ("free energy") in the
amount of R$84,600, which will be recovered from consumers through an
extraordinary rate increase authorized by ANEEL.
During 2001, the electricity markets in significant portions of Brazil
experienced rationing, or reduced availability of electricity to customers,
due to low rainfall, reduced reservoir levels and that country's
significant dependence on electricity generated from hydrological
resources. These factors resulted in lower sales for the Company. In
December 2001, electricity concessionaires including the Company reached an
industry-wide agreement (the "agreement") with the Federal Government that
provided resolution to all rationing related issues as well as to certain
other electricity rate-related issues. The rate increase set forth in the
agreement will remain in effect until all recoverable amounts are
collected, which the Company estimates will take approximately 4 years.
The agreement also comprised the Parcel A costs which are certain costs
that each distribution company is permitted to defer and pass through to
its customers via a future rate adjustment. Parcel A costs are limited by
the concession contracts to the cost of purchased power and certain other
costs and taxes. ANEEL had granted rate increases to recover a portion of
previously deferred Parcel A costs. However, due to uncertainty surrounding
the Brazilian economy, ANEEL had delayed approval of some Parcel A rate
increases. The agreement provided a tracking account mechanism, previously
created in October 2001 through Executive Order No. 296 to record the
variation in the Parcel A costs for rate adjustment calculation purposes.
Parcel A costs incurred previous to January 1, 2001 are not recoverable
though the tracking account. As a result, the Company has not recognized
any regulatory asset for Parcel A costs incurred prior to 2001 (see Note
7).
(b) Property, Plant and Equipment--These assets are stated at acquisition or
construction cost, monetarily restated under the constant currency method
through December 31, 2000. Depreciation is computed on the straight-line
basis over the estimated useful lives of the assets. On January 1, 1998,
the Company adopted the new depreciation rates established by ANEEL in
Resolutions no. 2/97 and 44/99, using an average rate of 4.5% and 4.6% in
Escelsa and Enersul, respectively. The interest charges, monetary
variations and foreign exchange differences accrued on loans and financing
relating to construction work in progress are capitalized. Interest on the
shareholders' equity portion of the financing of electric energy-related
construction work in progress is also capitalized based on the "Taxa de
Juros de Longo Prazo" - the Brazilian long-term interest rate (the "TJLP"),
but limited to 10% per year through December 31, 1997. In 1999 and 2001,
the Company capitalized interest on its own capital; the actual TJLP was
used, without any limit. The corresponding amount is credited directly to a
capital reserve. During 2000, the Company and its subsidiaries did not
capitalize interest on shareholders' equity.
F-17
(c) Special Liabilities--The balance is represented by contributions received
from customers exclusively for investment in the electric energy
distribution network to facilitate connection and by the reserve for
reversion of concessionaire assets directly related to the concessions
granted to the Company.
(d) Materials and Supplies--Materials and supplies are stated at acquisition
cost. Materials and supplies to be used in construction are included in
property, plant and equipment.
3.2 - General Accounting Policies
(a) Cash and Cash Equivalents--This account includes highly liquid temporary
cash investments (with original maturity dates of three months or less),
which are stated at cost plus income accrued to the balance sheet date.
(b) Marketable Securities--Are stated at the lower of cost plus income accrued
to the balance sheet date, or market.
(c) Accounts Receivable--Accounts receivable includes the supply of electric
energy both billed and unbilled to customers as of December 31, accounted
for on an accrual basis, and includes charges for late payments by
customers as well as accounts receivables related to the extraordinary
tariff recovery related to revenue losses during the electric energy
rationing period, and energy sales on the spot market ("MAE").
(d) Allowance for Doubtful Accounts--The allowance for doubtful accounts is
recognized at an amount considered sufficient to cover eventual losses on
the realization of accounts receivable.
(e) Investment -- The investments are stated at cost plus monetarily restated
under the constant currency method through December 31, 2000, net of
provision for loss, when applicable.
(f) Goodwill--Goodwill represents the excess of the purchase price over the
book value of Enersul, acquired as of November 25, 1997 by Magistra, and is
being amortized over the term of the concession of Enersul - thirty years,
since January 1, 1999 (ten years in 1998), based on the proportion of
projected net income for each of those years. The Company changed the
amortization period of the goodwill based on changes in the regulations
issued by ANEEL.
(g) Assets and Liabilities Denominated in Foreign Currencies or Subject to
Indexation--Assets and liabilities denominated in foreign currencies are
translated into reais at the exchange rate reported by the Central Bank of
Brazil at each balance sheet date. Those denominated in reais, and
contractually or legally subject to indexation, are restated to the balance
sheet date applying the corresponding index. Exchange gains and losses and
monetary variation gains and losses are recognized in income on a current
basis, except those related to construction work in progress, which are
capitalized.
(h) Income Tax and Social Contribution--Income tax is accrued based on taxable
income at the applicable income tax (25%) and social contribution tax (8%
or 9%, depending on the year) rates. Deferred tax arising from temporary
differences is accounted for under the liability method.
(i) Pension Plans--Escelsa maintains a separate entity, Fundacao Escelsa de
Seguridade Social - Escelsos ("Escelsos"), to administer defined benefit
and contribution pension funds for its employees (see Note 22). The costs
associated with pension plans are accrued when the contributions to the
fund become due and are based on mathematical reserves determined by
independent actuaries. As per CVM Rule 371 of 12/13/2000, starting in
fiscal year 2002, publicly listed companies are required to disclose and
recognize all liabilities related to pension and other post-retirement
benefits. The CVM rule gives companies the option to recognize the initial
transition obligation as of December 31, 2001, directly to
shareholders' equity. This option has been adopted by both Escelsa and
Enersul.
(j) Net Income (Loss) per Share--These amounts are calculated based on the
number of shares outstanding at the balance sheet date.
F-18
(k) Revenue Recognition--Revenue for all services is recognized when earned.
Billing for residential, industrial and commercial customers is performed
monthly. Unbilled revenues from the billing date to month-end are estimated
and recognized as revenue during the month service was provided. Revenues
from electricity sales to the final consumers are recognized when earned.
Billings for these sales are made on a monthly basis throughout the month.
Unbilled revenues from the billing cycle up to the end of each month are
estimated based on the prior month's billing and are accrued at the end of
the month. Differences between estimated and actual unbilled revenues,
which have not been significant, are recognized in the following month.
Value added tax ("VAT", which is a state tax due on the sales to the final
consumers, is billed to the consumers and recorded as part of gross
revenue. The VAT payable to the state is recorded as deduction of the gross
revenue in a separate line in the statement of operations to disclose the
net operating revenues.
(l) Use of Estimates--In preparing financial statements in accordance with
generally accepted accounting principles, the Company's management is
required to make certain assumptions and estimates with respect to the
recording of assets, liabilities and transactions. Actual results in the
future may differ from the estimates included in these financial
statements.
(m) Consolidated Financial Statements--The consolidated financial statements
comprise the balance sheet, the statement of operations and changes in
financial position of Escelsa and its subsidiaries, Magistra Participacoes
S.A. ("Magistra"), (holder of Enersul shares which were purchased on
November 25, 1997 and Costa Rica Energetica Ltda.), TV a Cabo Vitoria S.A.
("TVIX") and Escelsapar. Magistra was formed on November 19, 1997, TVIX was
formed on July 4, 1997 and Escelsapar was formed on August 31, 1999. Costa
Rica Energetica Ltda. was organized as a result of a project carried out by
a consortium formed by Enersul (51%) and DM Constutora de Obras Ltda (49%)
in 1999. The financial statements of the subsidiaries have been included in
the consolidated statements beginning the date of formation or purchase.
All significant intercompany transactions and balances have been eliminated
in consolidation, including investments in investees that were
consolidated.
3.3 - Constant Currency Presentation
In addition to the accounting practices described above, the following practices
under Brazilian GAAP were adopted in the preparation of constant currency
financial statements up to December 31, 2000:
(a) Index--Up to December 31, 1995, the financial statements were
price-level adjusted based on the variation of the UFIR. As from
January 1, 1996 through December 31, 2000, the IGP-M was used.
(b) Non-monetary Assets and Liabilities--Investments, property, plant and
equipment, special liabilities and shareholders' equity accounts were
restated from the date the original transaction occurred to December
31, 2000. Other non-monetary assets and liabilities and certain
receivables and payables for which the interest rates include a fixed
inflation factor were not inflation adjusted because the net effect of
the adjustments were considered immaterial to the financial position
or results of operations.
(c) Income Tax and Social Contribution--The deferred tax effects of the
restatement of non-monetary assets and liabilities were accrued and
recognized in results of operations. The deferred tax credit related
to the restatement of shareholders' equity has been reclassified and
charged to retained earnings since the credit does not represent an
actual tax benefit.
(d) Statements of Income, Changes in Shareholders' Equity and Changes in
Financial Position--These statements were prepared as follows:
o All components of these statements were price-level adjusted from the
date or month they were first recorded through December 31, 2000.
o Gains/losses on monetary items - those attributed to the variation in
index, calculated on a monthly average basis, were allocated to the
corresponding income or expense components in the statement of
operations.
(e) Prior Years' Financial Statements--All amounts in the financial
statements for prior years were adjusted for price-level changes
through December 31, 2000.
F-19
4. MARKETABLE SECURITIES
December 31,
-------------------------------
2001 2000
------------ -------------
Bank deposits certificates 31 1,129
Debt securities 256,678 262,252
Other 150 8,664
------------ -------------
Total 256,859 272,045
============ =============
Debt securities are comprised of bonds issued by the Brazilian Government
("Notas do Tesouro Nacional") and the Central Bank of Brazil ("Notas do Banco
Central"), with interest rates ranging from 9.99% per annum to 10.46% per annum
plus exchange variation, (from 15.00% per annum to 15.55% per annum plus
exchange variation, in 2000) and maturity dates from March of 2004 to November
of 2006 (from March of 2001 to September 2001, in 2000).
5. ACCOUNTS RECEIVABLE
This account includes both amounts billed to customers and accrued revenue
relating to unbilled energy supplied to customers as of the balance sheet date.
Fines arising from late payments to Escelsa and Enersul by other electricity
companies are also included.
December 31,
-----------------------------------------------------------------
2001
-----------------------------------------------------------------
Current Past-due Past-due Total
-----------------------
up to 90 days over 90 days 2001 2000
----------- --------------- ------------- ----------- -----------
CURRENT ASSETS
FINAL CUSTOMERS:
Residential 34,010 22,637 1,935 58,582 71,233
Industrial 33,168 6,011 3,199 42,378 40,214
Commercial, services and other activities 21,726 8,991 3,993 34,710 30,434
Rural 4,902 3,724 479 9,105 8,576
Public authority:
Federal 559 355 418 1,332 1,690
State 1,532 1,273 6,776 9,581 2,894
Municipal 2,215 1,049 1,303 4,567 3,682
Public lighting 3,241 2,594 4,863 10,698 7,609
Public service 2,909 686 90 3,685 3,552
Regulatory asset 76,485 - - 76,485 -
Other credits - 1,027 447 1,474 2,873
----------- --------------- ------------- ----------- -----------
180,747 48,347 23,503 252,597 172,757
----------- --------------- ------------- ----------- -----------
WHOLESALE 66,278 4,586 180 71,044 18,894
----------- --------------- ------------- ----------- -----------
TOTAL 247,025 52,933 23,683 323,641 191,651
=========== =============== ============= =========== ===========
LONG-TERM ASSETS
FINAL CUSTOMERS:
Regulatory asset 226,171 - - 226,171 -
Other credits 17,122 - 15,169 32,291 24,902
----------- --------------- ------------- ----------- -----------
TOTAL 243,293 - 15,169 258,462 24,902
=========== =============== ============= =========== ===========
F-20
Regulatory Asset
According to clauses in Provisional Measure no. 14, in Resolution no. 91 from
the Energy Crisis Management Chamber - GCE of December 21, 2001, Resolution no.
31 from the Brazilian Electric Energy Regulatory Agency - ANEEL of January 24,
2002 and ANEEL Resolution no. 72 of February 7, 2002, the Company calculated the
amount of the extraordinary tariff recovery to be applied to all of the
concession areas for electric energy distribution, to be recognized as the basis
for re-establishing the financial and economic equilibrium of the concession
contracts, with the recovery of the revenue losses, which were incurred as a
result of the Emergency Program for Reducing Electric Energy Consumption - PRE
from June 1, 2001 through December 31, 2001.
On December 27, 2001, ANEEL Resolutions no. 637 and no. 646 were published
(dated December 21, 2001), through which new tariffs for final customers were
approved for ESCELSA and ENERSUL for extraordinary tariff recovery, increasing
tariffs by:
o 2.9% for residential and rural clients (except low-income customers);
o 7.9% for all other clients.
An extraordinary tariff recovery of R$ 302,656 was recorded as Accounts
Receivable regulatory asset, for fiscal year 2001 as per the following:
a) As revenue from energy sales: R$213,934 related to the difference between the
estimated revenue (without the effects of the reduced consumption as a result of
the Emergency Program for Reducing Electric Energy Consumption) and the revenue
derived by the Company for the above-mentioned period, as per parameters defined
in Resolution no. 91 of the GCE and ANEEL Resolution no. 31;
b) As revenue from energy sales: R$84,600 related to the amount to be recovered
as a result of reimbursement to electric energy generation companies for free
energy as communicated to agents and disclosed on March 13, 2002 by MAE (
Wholesale Energy Market ); and,
c) R$4,122, related to recoverable PIS/COFINS taxes charged on free energy
offset against Others under long-term liabilities;
In a memorandum on March 21, 2002, MAE informed the Company of an additional
amount of R$604, related to the difference in free energy, for which the amount
recorded is currently under negotiation between the electric energy generation
companies and the MAE (Wholesale Energy Market). The Company did not recognize
this amount in its accounts since it is still subject to analysis and
determination by ANEEL.
As the information is an estimate, the amount recorded as free energy is subject
to change. The final amounts to be disclosed will be validated by ANEEL, as per
Resolution no.72 of February 7, 2002 through an approval request presented to
ANEEL by the Company.
The extraordinary tariff recovery will extend for a period necessary to recover
the amount calculated. The Company estimates that the recovery period will be
approximately four years.
The Brazilian Economic and Social Development Bank (BNDES) extended an advance
to the Company for extraordinary tariff compensation corresponding to
approximately 90% of the amount to be reimbursed. The funds raised through
billing the extraordinary tariff recovery to customers by the Company will be
used to repay this obligation (Note 26).
Wholesale Energy Sales
Of the total amount recorded as wholesale, R$71,044 (R$18,894 in 2000)
correspond to short-term energy sales executed in the MAE, which began
operations in January 1999.
The above-mentioned as of December 31, 2001 total includes:
F-21
a) R$3,851, related to the period between September 2000 and December 2000, and
recorded based on estimates disclosed by the MAE on October 15, 2001, which are
estimated and subject to subsequent changes;
b) R$62,230, related to the period between January 2001 and December 2001, and
recorded based on estimates disclosed by the MAE on March 13, 2002, which are
estimated and subject to subsequent changes;
Future decisions made by the regulating entities in the electric energy sector,
as well as amounts recorded for the regulatory asset and receivables from MAE
transactions, are subject to changes.
6. BONUS PAID TO CONSUMERS, COSTS INCURRED AND SURTAX CHARGED TO CONSUMERS -
EMERGENCY RATIONING PROGRAM
According to Provisional Measure no. 2,147 of May 15, 2001 and prior amendments,
as well as regulations from the Energy Crisis Management Chamber - GCE, ESCELSA
and Enersul charged a surtax to customers who exceeded their consumption quotas
and granted bonuses to consumers who reduced consumption to levels below their
quotas.
The subsequent financial accounting for these events, defined as per ANEEL
Resolution no. 299 of July 27, 2001, will not affect the Company's results of
operations since the net amount due will be recovered through a special tariff.
December 31, 2001
-----------------------
ASSET
Current Assets (accounts receivable)
Bonus balance (invoiced (-) received) (7,026)
Surtax - accounts receivable 5,554
Surtax installment 638
-----------------------
(834)
-----------------------
Long term assets
Invoiced Bonus 38,877
Costs incurred by Company to be reimbursed 8,787
-----------------------
47,664
-----------------------
TOTAL 46,830
=======================
LIABILITY
Surtaxes Charged 16,819
(-) VAT tax on surcharges (3,552)
(-) 2% to cover costs (119)
-----------------------
TOTAL 13,148
-----------------------
BALANCE RECEIVABLE - Ministry of Mines and Energy 33,682
=======================
7. DEFERRED REGULATORY ASSETS - PARCEL A COSTS
As a portion of the tariffs charged by the Electric Utilities, distribution
concession agreements establish amounts related to certain costs, which are not
within the control of the Company. These include:
o Pass-through of tariff related to energy purchased from Itaipu
Binacional;
o Pass-through of transport costs for electric energy from Itaipu
Binacional;
o Quota for the Fuel Consumption Account - CCC;
o Costs for transmission infrastructure usage on the basic grid;
o Compensation for usage of water resources;
o System Service Charges - ESS;
o Energy Purchased as established in the initial contracts;
o Quota for the Global Reversion Reserve - RGR;
F-22
o Electric energy service enforcement fee; and,
o Connection charges.
With the introduction of Provisional Measure no. 2,227 and no. 14 of September
4, 2001 and December 21, 2001, respectively, and ANEEL Resolution no. 90 of
February 18, 2002, a tracking account was established in order to compensate for
monthly variances in these non-controllable costs, which occur between tariff
adjustment dates. The balance will be financially compensated and adjusted to
the SELIC rate.
As a result, starting in fiscal year 2001, with the introduction of the Parcel A
Cost Variations Compensation Account - CVA, the Company recognized long-term
prepaid expenses in the amount of R$66,310 related to the period from January 1,
2001 through October 25, 2001, which will be recovered together with the other
regulatory assets through the extraordinary tariff recovery (Note 5).
The differences generated from October 25, 2001 through December 31, 2001 that
will be utilized for the tariff adjustment in August 2002 were recorded as
prepaid expenses under current assets in the amount of R$7,816 and under
long-term assets in the amount of R$19,692.
The negative variation, which is related to energy transport from Itaipu in the
amount of R$679, is recorded as Current Liabilities - Others in the amount of
R$226 and Long-Term Liabilities - Others in the amount of R$453, as per Bulletin
nos. 60 and 91/2002-SFF/ANEEL of January 24, 2002 and February 14, 2002,
respectively.
8. ACCOUNTS RECEIVABLE - UTE CAMPO GRANDE
As per Resolution No. 64, of April 15, 1999, ANEEL authorized ENERSUL to declare
itself an "Independent Power Producer," as a result of the construction of the
first phase of the Campo Grande Modular Thermoelectric Plant, with an installed
capacity of up to 151,800 kW. The plant's construction was partially financed by
Deutsche Bank.
In fiscal year 2000, the plant was sold to Gerasul, in exchange for payment
corresponding to the total balance of the loan with Deutsche Bank, which was
transferred to GERASUL during fiscal year 2001.
9. AFFILIATES AND SUBSIDIARIES
December 31,
---------------------
COMPANIES TRANSACTION 2001 2000
- ---------------------- ------------------------------ --------- ----------
ESC90 Loan 52,501 45,666
Other Pass-through of costs 348 -
--------- ----------
52,849 45,666
========= ==========
The consolidated financial statements show primarily the balance of
inter-company loans with the affiliate ESC90, as detailed below, which were made
at similar terms to those practiced in the Brazilian financial market.
1) Interest Rate: TJLP + 4% per annum;
Maturity: November 2004;
Balance as of December 31, 2001: R$ 4,678.
2) Interest Rate: 100% de CDI;
Maturity: several dates through December 31, 2002;
Balance as of December 31, 2001: R$ 47,823.
Guarantees: Promissory notes corresponding to 125% of principal.
ESC90 is a 48.51% equity investee of ESCELSA, which is in the development stage.
Up to December 31, 2000 the results of operations of ESC90 were not significant
to the consolidated results of operations. MAGISTRA's interest income from the
above loans to ESC 90 totalling R$6,048 (R$2,633 in 2000) in the consolidated
statements of operations is recorded as other financial income.
F-23
10. PROPERTY, PLANT AND EQUIPMENT
December 31,
--------------------------------------
2001 2000
----------------- -------------------
IN SERVICE:
Generation 321,714 296,406
Transmission 18,343 17,646
Distribution 2,658,621 2,560,512
Administration 307,075 285,231
----------------- -------------------
3,305,753 3,159,795
----------------- -------------------
(-) Accumulated depreciation (1,274,834) (1,155,047)
----------------- -------------------
2,030,919 2,004,748
----------------- -------------------
UNDER CONSTRUCTION:
Generation 46,660 24,876
Transmission 1,126 1,490
Distribution 195,262 209,096
Administration 19,588 29,839
----------------- -------------------
262,636 265,301
----------------- -------------------
Total 2,293,555 2,270,049
================= ===================
On February 13, 1995, Law no. 8,987 was enacted, changing the regulations for
public service concessions for generation, transmission and distribution of
electric energy. On July 7, 1995, Law no. 9,074 was enacted, establishing rules
for the renewal and approval of concessions. The principal aspect of such laws
which may affect the Company is the fact that concessions for the generation,
transmission and distribution of electric energy will last a sufficient period
to amortize the investments, limited to 35, 30 and 30 years, respectively. These
concessions may be extended for one period of up to the same duration, at the
discretion of the regulatory authorities.
On July 11, 1995, the date of Escelsa's privatization, a new concession contract
was signed, which granted the right to generate, transmit and distribute
electric energy in virtually all of the State of Espirito Santo through the year
2025. In the event of a change of control, Escelsa must continue to observe all
the conditions established in the contract (see Note 1).
On November 19, 1997, the date of Enersul's privatization, a new concession
contract was signed, which granted the right to generate, transmit and
distribute electric energy in virtually all of the State of Mato Grosso do Sul
through the year 2027. In the event of a change of control, Enersul must
continue to observe all the conditions established in the contract.
In January 1998, Escelsa and Enersul implemented the new depreciation rates
determined by ANEEL Resolution no. 002/97. Due to the new depreciation rates,
Escelsa's average annual rates changed from 3.4% to 4.5%, and Enersul's average
annual rates changed from 3.3% to 4.6%.
The following amounts of interest expense were capitalized in Property, Plant
and Equipment:
2001 2000 1999
--------- --------- ---------
Interest on loans and financing 176,083 137,354 174,883
(-) Transfer to property, plant and equipment (14,633) (26,469) (18,612)
---------- --------- ---------
Net 161,450 110,885 156,271
========== ========= =========
F-24
11. GOODWILL
On November 25, 1997, the Company paid R$825,937, to acquire a 55.4% controlling
interest (76.5% voting interest) in Enersul. The difference between net assets
acquired and the purchase price was recorded as goodwill totaling R$479,751
monetarily restated from the purchase date.
December 31,
-------------------------------
2001 2000
-------------- ---------------
Goodwill 479,751 479,751
Accumulated amortization (39,981) (36,970)
-------------- ---------------
439,770 442,781
============== ===============
12. SUPPLIERS
December 31,
-------------------------------
2001 2000
------------- -----------------
CURRENT LIABILITES:
Electricity suppliers:
Furnas 53,009 30,602
Itaipu 38,542 30,308
Gerasul 12,786 8,825
Eletrosul 1,172 1,076
MAE 48,259 14,754
Other 10,847 4,600
------------- -----------------
164,615 90,165
Other suppliers 14,361 16,796
------------- -----------------
Total 178,976 106,961
============= =================
LONG TERM:
Electric Energy Supply:
Free energy 84,600 -
------------- -----------------
Total 84,600 -
============= =================
The amount of R$48,259 (R$14,754 in 2000) recorded as electric energy supply
from MAE under Current liabilities, correspond to short-term energy bought from
MAE, which began operating in January 1999.
The amount corresponds to the purchase of short-term energy in the MAE is as
follows:
a) R$7,895 is related to the period between September 2000 and December 2000,
recorded based on estimates disclosed by MAE on October 15, 2001;
b) R$11,372 is related to the period between January 2001 and December 2001,
recorded based on estimates disclosed by MAE on March 13, 2002; and
c) R$28,992 (R$4,640 in 2000), corresponding to grid usage charges.
13. FINANCIAL INSTRUMENTS
CVM Rule 235 of March 23, 1995, established a mechanism for the disclosure of
the market value of financial instruments by way of "notes to the financial
statements," regardless of their recognition on the financial statements.
The Company's business entails the distribution and sale of electric energy for
customers within its concession area - the states of Espirito Santo and Mato
Grosso do Sul - and therefore significant financial instruments are related to
the following transactions:
F-25
o Balances of long-term accounts receivable and accounts payable are related
to the extraordinary tariff recovery and therefore are not subject to
adjustments to market value;
o Investments in short term mutual funds and/or fixed income investments are
recorded at approximate market value as they are recorded with accrued
interest on a pro-rata basis;
o Loans due by the Company are mainly long-term, and are from specific
funding sources.
13.1 Exchange Rate and Interest Rate risks
A portion of the loans and financing is comprised of financing from
government entities ELETROBRAS and BNDES.
As the market rate (or opportunity cost of capital) is set by these
government entities, taking into consideration the risk premium relative to
the sector's activities and that in the absence of other financing sources
or other market options and/or means to estimate the market value of such
options in light of the Company's business or sector-specific
circumstances, the market value for the portion comprised of inter-company
loans shall correspond to their book value, as shall other financial assets
and liabilities.
As mentioned in Note 14, foreign currency financing was obtained (in U.S.
dollars), and the indebtedness and earnings were significantly impacted by
the foreign exchange risk. Such risk may cause the Company to incur losses
due to foreign exchange fluctuations, which may increase liabilities
denominated in foreign currency.
Net exposure to foreign currency risk as of December 31, 2001 and December
31, 2000:
BOOK VALUE FAIR VALUE
---------------------------- ----------------------------
12/31/2001 12/31/2000 12/31/2001 12/31/2000
------------- ------------- ------------- -------------
Senior notes 1,045,828 881,319 910,829 708,567
Other loans and financing 151,008 93,868 151,008 93,868
U.S. dollar assets (256,678) (262,252) (256,678) (262,252)
------------- ------------- ------------- -------------
Net exposure 940,158 712,935 805,159 540,183
============= ============= ============= =============
The method used to determine the fair value of the Senior Notes obligation was
the average market price as per the security's trading activity at the end of
each fiscal period and for U.S. dollar assets, the contract market price at the
end of the fiscal period was utilized, which is equal to the book value.
On a consolidated basis, loans and obligations held by companies within the
ESCELSA System were made at rates and terms generally practiced in the domestic
and international markets to fund investments in the electric energy sector in
its concession areas as a public utility.
The subsidiaries MAGISTRA and ENERSUL maintain liabilities in foreign currency
(US$). To reduce foreign exchange related risk, swap instruments were used to
hedge a portion of these obligations, as mentioned in items g, h, i and j of
Note 14. Indexes used in these instruments are the IGP-M plus interest rates of
11.70% to 12.01% per annum and the CDI (Certificated of Interbank deposit) plus
1.52% per annum.
As the Real appreciated during the fiscal period, the hedging instruments
generated a loss of R$6,905 as follows:
BOOK VALUE FAIR VALUE
-------------- -------------
Loans and Financing 78,183 78,183
Swap balance (85,088) (85,088)
-------------- -------------
Net (6,905) (6,905)
============== =============
For the remaining contracts, given the specific nature of these transactions and
the inability to determine a market value for this type of financial instrument,
and taking into consideration the risk to the company, its strategy and debt
management practices, Management estimates that the market values of the
instruments are similar to their book value.
F-26
13.2 Credit Risk
There is a possibility that the Company will incur losses due to default of its
customers. To mitigate against this risk, the Company maintains the right to
cut-off the supply of electric energy in the event that a customer fails to make
payment in accordance with the time-periods defined by legislation and specific
regulations. A provision for doubtful accounts is established in an amount
deemed sufficient by Management to cover potential accounts receivable risks.
14. LOANS AND FINANCING
14.1 Description
December 31,
---------------------------------------------------------------------------------
2001 2000
--------------------------------------- ----------------------------------------
Interest Interest
and Principal and Principal
Other -------------------------- Other --------------------------
Charges Current Long-term Charges Current Long-term
------------ ------------ ------------ ------------- ------------ ------------
Local Currency:
ELETROBRAS (b) and (l) 547 23,070 53,415 168 22,568 55,899
BNDES-MAGISTRA (c) 1,360 37,818 75,636 1,754 36,592 109,776
BNDES-ESCELSA (d) 1,268 22,056 169,185 518 21,341 103,148
BNDES-ENERSUL (e) 291 13,466 66,123 945 4,923 77,011
Banco do Brasil - FCO (f) 199 - 20,000 - - -
Banco Bilbao Vizcaya - BBVA (m) 249 15,996 - 222 17,926
Banco do Brasil S.A (m) - 10,000 - 34 4,550
Banco Alfa (m) 138 30,550 - 194 14,810
Banco HSBC (m) 21 1,862 - - -
Citibank (m) 1,503 22,546 - - -
Others 274 12,885 20,371 223 1,096 16,658
------------ ------------ ------------ ------------- ------------ ------------
5,850 190,249 404,730 4,058 123,806 362,492
------------ ------------ ------------ ------------- ------------ ------------
Foreign Currency:
Senior Notes (a) 45,833 - 999,995 38,624 - 842,695
Banco B.B.A. FMO (g) 313 22,596 11,049 - - -
BRADESCO (h) 60 11,549 - - - -
UNIBANCO (i) 51 11,318 11,519 - - -
Banco Itau (j) 20 10,219 - - - -
BBA-EIB (g) 196 - 37,591 153 - 29,331
Deutsche Bank - - - 658 3,757 30,054
National Treasury - STN (k) 464 884 33,179 465 745 28,705
------------ ------------ ------------ ------------- ------------ ------------
46,937 56,566 1,093,333 39,900 4,502 930,785
------------ ------------ ------------ ------------- ------------ ------------
52,787 246,815 1,498,063 43,958 128,308 1,293,277
Banco B.B.A. FMO - Long term (g) 234 - - - - -
UNIBANCO - Long term (i) 1,055 - - - - -
------------ ------------ ------------ ------------- ------------ ------------
1,289 - - - - -
------------ ------------ ------------ ------------- ------------ ------------
TOTAL 54,076 246,815 1,498,063 43,958 128,308 1,293,277
============ ============ ============ ============= ============ ============
a) Senior Notes refer to the overseas funding transaction, through the
issuance of "Senior Notes," with a principal balance on December 31, 2001
of R$ 999,995 or US$ 430,958 thousand. The securities mature in 2007, and
carry an interest rate of 10% per annum, which is payable every six months
on January 15 and July 15 of each year. On May 21, 1998, ESCELSA registered
the security with the SEC - Securities and Exchange Commission, in the US,
as per the Securities Act of 1933.
b) The financing from ELETROBRAS is being used to finance the Generation and
Distribution Program. Monthly and quarterly amortization is scheduled
through August 15, 2022 both with and without monetary correction and
interest rates varying between 6% and 12% per annum.
F-27
c) The financing from BNDES for subsidiary MAGISTRA was related to the
acquisition of ENERSUL's controlling shares. The loan interest rate is
based on the Long-term Interest Rate, plus a spread of 4% per annum, and 11
semi-annual amortization payments beginning November 15, 1999 and extending
through November 2004.
d) The BNDES financing obtained by ESCELSA is being used for the transmission
and distribution programs. The loan interest rate is based on the Long-term
Interest Rate (TJLP), plus spread of 3.8% per annum, with a 12-month grace
period and 84 monthly amortization payments beginning November 15, 1999 and
extending through November 2006.
e) The BNDES financing obtained by ENERSUL is being used to finance the
1998-2000 Investment Program. The loan interest rate is based on the
Long-term Interest Rate (TJLP), plus a spread of 3.8% per annum, spread,
with a 24-month grace period and 78 monthly amortization payments beginning
September 2001. The BNDES financing used for the construction of the
Imbirucu Substation has an interest rate of TJLP plus spread of 4.0% per
annum, with 51 monthly amortization payments beginning February 2000 and
extending through February 2008.
f) The Banco do Brasil financing obtained by ENERSUL, with funds from the
Midwest Constitutional Financing Fund (FCO), is being used for the 2001
Investment Program. The interest rate is 11.20% per annum with 108 monthly
amortization payments starting December 2004 and extending through November
2013.
g) Financing from Banco BBA-EIB Creditanstalt S.A for ENERSUL's Distribution
Program carries an interest rate linked to quarterly LIBOR plus a spread of
4% to 5% per annum, with a grace period of 36 months and 11 semi-annual
amortization payments starting June 2003 and ending March 2009. BBA secured
an external line of credit with Netherlands Development Company - FMO,
supported by Resolution 2770 from BACEN. The line carries an interest rate
of 8.90% per annum and is foreign exchange rate indexed to United States
Dollars with amortization payments scheduled to begin March 2002, ending
September 2007. The BBA-FMO financing is hedged against currency
fluctuations by way of swap contracts.
h) Financing from Bradesco for ENERSUL was secured to cover payments to
suppliers at an interest rate of 7.30% to 8.40% per annum, indexed to the
foreign exchange rate to United States Dollars, with liquidation in May and
June of 2002. The financing is hedged against currency fluctuations by way
of swap contracts.
i) Long-term financing from Unibanco for ENERSUL was secured mainly to cover
payments to suppliers at an interest rate of 10.85% to 11.40% per annum,
indexed to the foreign exchange rate to United States Dollars, with a
lump-sum payment in March 2004. Short-term financing from Unibanco was
secured in November 2001 at an interest rate of 3.30%, indexed to the
foreign exchange rate to United States Dollar, with a lump-sum payment in
May 2002. The financing is hedged against currency fluctuations by way of
swap contracts.
j) Financing from ITAU was secured mainly to cover payments to suppliers at an
interest rate of 1.50% per annum, indexed to the foreign exchange rate to
United States Dollars, with a lump-sum payment in October 2002. The
financing is hedged against currency fluctuations by way of swap contracts.
k) Financing from National Treasury STN-DMLP was secured for the Distribution
Lines and Substation Investment Program at an interest rate of 5.2% to 8.2%
per annum, indexed to the foreign exchange rate to United States Dollars.
l) Obligations linked to ELETROBRAS financing for the construction of the
Costa Rica Hydroelectric Plant, in the amount of R$5,487, are being
presented as a reduction to long and short-term debt at ESCELSA, with the
transfer of the obligation to Costa Rica Energetica Ltda.
m) Financing from BBVA, Banco do Brasil, Banco Alfa, HSBC and Citibank was
secured to amortize mutual obligations with MAGISTRA and for investments in
the Campo Grande Hydroelectric Plant, at a rate of 102.5% to 106.5% of CDI.
F-28
14. 2 Guarantees:
ESCELSA and ENERSUL obligations to ELETROBRAS, BNDES and FCO are guaranteed by
escrow accounts linked to the companies' receivables. Financing for ENERSUL from
the National Treasury (STN) is guaranteed by a direct withdrawal agreement,
escrow account, the Mato Grosso do Sul Government, and a portion collateralized
with cash. The remaining obligations are guaranteed by promissory notes. The
Magistra obligation with the BNDES is collateralized with ENERSUL equity.
14. 3 The breakdown of loans and financing by currency:
December 31,
------------------------------------
2001 2000
---------------- -----------------
Local currency 594,979 486,298
Foreign currency (US Dollars) 1,149,899 935,287
---------------- -----------------
Total 1,744,878 1,421,585
================ =================
14.4 Percentage variation of the main indicators used for indexing the loans and
financing are as follows:
Currency and indicators 2001 2000
--------------------------------------- ------------ ------------
Exchange rate - US dollars 18.67% 9.30%
IGP-M Inflation rate 10.38% 9.95%
INPC Inflation rate 9.44% 5.27%
TJLP long-term interest rate 10.00% 9.75%
14.5 Maturities of short and long-term installments are due as follows:
December 31, 2001
----------------------------------------
Currency
----------------------------------------
Maturity Local Foreign Total
-------------------------- ----------------------------------------
2002 190,249 56,566 246,815
2003 102,495 11,012 113,507
2004 107,241 24,018 131,259
2005 67,640 12,056 79,696
2006 50,346 10,823 61,169
2007 26,838 1,008,737 1,035,575
2008 14,616 5,578 20,194
2009 9,567 1,952 11,519
2010 8,579 1,489 10,068
2011 5,468 1,489 6,957
After 2011 11,940 16,179 28,119
----------------------------------------
TOTAL 594,979 1,149,899 1,744,878
========================================
F-29
Financial income (expense) consists of the following:
December 31,
---------------------------------
2001 2000 1999
---------- --------- ----------
Interest expense (161,450) (110,885) (156,271)
Net gain (loss) on exchange rate variations
And monetary position (130,955) 11,510 (169,206)
Gain or loss on hedge contracts 1,059 - 15,189
Gain on purchase of senior notes - - 15,411
Interest income 55,515 75,876 175,532
----------- ---------- ----------
Total (235,831) (23,499) (119,345)
=========== ========== ==========
During September, October and December, 1998 and February of 1999, the Company
purchased US$53,625 thousand and US$15,390 thousand, respectively, of its own
senior notes in the open market at a price of US$32,282 thousand and US$8,892
thousand. The notes were formally cancelled and the gain of R$15,411 in 1999 and
R$34,882 in 1998, representing the difference between the carrying value and the
purchase price, was recognized in financial income.
15. REGULATORY CHARGES
a. Regulatory Charges Payable
December 31,
---------------------------
2001 2000
----------- -------------
Global reserve for reversion quota - RGR 6,973 11,235
Fuel usage quota - CCC 6,267 7,207
----------- -------------
Total 13,240 18,442
=========== =============
b. Regulatory Charges Expense
December 31,
-------------------------------
2001 2000 1999
----------- --------- ---------
ANEEL - Fiscalization fee 2,574 2,129 2,185
Global reserve for reversion quota - RGR 26,598 26,049 26,338
Fuel usage quota - CCC 66,680 70,055 35,424
----------- ---------- --------
Total 95,852 98,233 63,947
=========== ========== ========
c. Global Reserve for Reversion Quota - RGR
The global reserve for reversion quota (the RGR Fund) is a reserve fund managed
by Eletrobras, as agent for the Brazilian government, designed to provide funds
for payments to concessionaires upon expiration of their concessions. In these
events, the concessionaire is paid an amount equal to the value of its net
assets. Until December 31, 1995, each concessionaire was required to pay an
amount equal to 3% of its assets in service to the RGR Fund, limited to 12% of
total operating revenues less value-added tax on sales to final consumers.
On January 3, 1996, Decree no. 1,771 decreased the RGR rate to 2.5% of assets in
service, limited to 3% of total operating revenues less value-added tax on sales
to final customers.
F-30
d. Fuel Usage Quota - CCC
The fuel usage quota represents contributions made by the Company to finance the
cost of fuel used in the thermoelectric energy generating process in the
Brazilian energy system.
16. DEFERRED INCOME TAXES
a. Computation of Income Tax Liability
Taxable income is determined by adjusting income before taxes principally for
permanent differences and the effects of temporary differences. Tax loss carry
forwards and social contribution negative basis, when available, do not expire
and may be used to offset up to 30% of the taxable income in each year. Income
tax liability is then determined by applying the statutory rate to taxable
income. In periods when income tax computations result in tax losses, the
Company recognizes tax credits on such tax losses. Brazilian tax law does not
allow filing of consolidated tax returns.
b. Deferred Tax Liability
The balance represents primarily income tax liabilities computed on the income
tax and social contribution in respect of the increase in shareholders' equity
due to the recognition of the effects of inflation on non-monetary assets and is
all long-term.
December 31,
-------------------------
2001 2000
----------- -----------
Inflationary profits 10,108 12,580
Deferred income and social contributions
Tax on price level adjustments up to 2000 203,985 223,749
----------- ------------
Total 214,093 236,329
=========== ============
c. Deferred Tax Asset
December 31,
-----------------------
2001 2000
----------- -----------
Tax loss carry-forwards 140,549 172,317
-Deductible temporary differences 64,484 27,478
Depreciation of compulsory monetary restatement
Law no. 8,200 - 4,224
Deferred income and social contribution tax on
Price-level adjustments up to 2000 26,276 26,276
----------- -----------
Total 231,309 230,295
=========== ===========
F-31
Income tax and social contribution at statutory rates is reconciled to the
amount reported as income tax expense (income) in these financial statements as
follows:
December 31,
---------------------------------------
2001 2000 1999
------------ --------------------------
Income (loss) before tax (60,294) 70,189 (100,292)
Statutory rates 34% 34% 35%
------------ --------------------------
Income tax expense (benefit) at statutory rate (20,500) 23,864 (35,102)
Reversal of tax loss carryforward 4,778 - -
Amortization of goodwill 893 864 825
Remuneration of construction work in progress 1,543 - -
Price-level Adjustment- Goodwill 129 (12,628) (29,203)
Reversal of non-deductible expenses - - 1,085
Others 2,145 2,128 (7,108)
------------ --------------------------
Total expense (benefit) (11,012) 14,228 (69,503)
============ ==========================
17. ACCRUAL FOR CONTINGENCIES
----------------------------------------------------------------------------
2001 2000
----------------------------------------- -----------------------------------
Provision Escrow Provision Escrow
---------------------- -----------------------
Accumulated Deposits Accumulated Deposits
- --------------------------------- ---------------------- ------------------ ----------------------- -----------
Current Liabilities:
Fiscal
COFINS 39,382 39,382 39,382 39,382
---------------- ------------------ ---------------- -----------
TOTAL 39,382 39,382 39,382 39,382
================ ================== ================ ===========
Long Term:
Labor claims 19,999 11,656 20,529 10,348
Civil litigation 31,098 6,206 9,658 351
Fiscal 87,714 58,954 37,900 46,876
---------------- ------------------ ---------------- -----------
TOTAL 139,811 76,816 68,087 57,575
================ ================== ================ ===========
Management believes that the provisions recorded are sufficient to cover
eventual losses from litigations. Based on the opinion of the Companies' legal
counsel, all litigations were provided for where the probability for recovery
was estimated as remote. Furthermore, there is labor, civil and fiscal cases
pending which total R$26,563, for which the probability of a favorable outcome
was estimated as likely and no provisions were recorded on the financial
statements.
COFINS
Provision set up on the basis of amounts deposited from May 1996 to July 1999,
based on a preliminary injunction obtained in May 1996 by way of an immunity
plea for the tax.
With the decision by the Supreme Court - STF in July 1999, upholding the
constitutionality of COFINS tax on electric energy transactions, Escelsa
converted the deposited amounts, normalizing the taxes collected, reclassifying
the provision as Current. The Company awaits the final ruling for a reversion of
the deposits and subsequent payment of the amounts provided for.
F-32
Labor Contingencies
Refer to the various labor claims against the Companies, which claim payment of
overtime, hazardous work conditions, reintegration, among other items.
Civil and Fiscal Contingencies
The civil and fiscal contingencies include suits in which the Companies are a
defendant in cases which are related to alleged moral and material damages, in
addition to challenges to amounts paid by customers for tariff increases based
on DNAEE regulations 38 and 45 of January 27, 1986 and March 4, 1986,
respectively, during the Cruzado Plan.
Escelsa awaits ruling for a suit with the Federal Reserve ("Receita Federal"),
for compensation of amounts overpaid-related to FINSOCIAL, due to the
unconstitutionality of the rules - Law nos. 2,445 and 2,499. There is also a
decision, which guarantees restitution, and/or compensation for amounts overpaid
related to fines on tax collections and contributions made spontaneously and
untimely. Exemption from the fine is being requested based on article 138 of the
National Tax Code - CTN.
Based on legal counsel, Escelsa compensated the amounts related to past-due
contributions (PIS, Cofins, IRPJ and CSLL), as per Article 66 of Law no.
8,383/91. Conservatively, Escelsa maintained provisions for amounts
corresponding to the above mentioned taxes and contributions.
18. SPECIAL LIABILITIES
December 31,
---------------------------------
2001 2000
--------------- ---------------
Consumers' contributions 249,181 234,408
Other 13,139 13,139
--------------- ---------------
Total 262,320 247,547
=============== ===============
Consumers' contributions consist of assets provided to the Company by certain
residential, rural and industrial customers to facilitate connection or in case
of low return on the investment by the Company. Eventual liquidation of these
special liabilities is dependent upon future determinations by ANEEL.
19. SHAREHOLDERS' EQUITY
a. Capital Stock
Escelsa, as stated in its by-laws, is authorized to operate with capital of up
to R$1,000,000, of which R$239,141 (R$153,947 in corporate law) was subscribed
as of December 31, 2001. Capital, as of December 31, 2001, 2000 and 1999, was
represented by 4,550,833 common shares, with no par value. The following table
sets forth information with respect to beneficial ownership of Escelsa's common
shares.
Quantity Quantity % of
Shareholders of shares of shareholders Participation
- ---------------------------------------- ---------------- --------------------- ---------------
Iven S.A. 2,378,673 1 52.27
GTD Participacoes S.A. 1,137,709 1 25.00
Fundacao Banco Central-CENTRUS 275,678 1 6.06
Other 758,773 152 16.67
---------------- --------------------- ---------------
Total 4,550,833 155 100.00
================ ===================== ===============
F-33
In October 1994 Iven acquired 20% of ESCELSA common shares from the State
Government. In July 10, 1995 Iven and GTD entered into a shareholders' agreement
when they purchased, in a consortium, 50% (plus one share) of the voting stock
of Escelsa. Shares purchased by GTD and Iven pursuant to the privatization of
Escelsa may not be sold without the prior authorization of ANEEL. The
shareholders' agreement expires in the year 2002. The joint ownership of a
majority of the voting shares gives Iven and GTD the ability to control the
election of the majority of Escelsa's Board of Directors, as well as the ability
to determine the outcome of major decisions requiring the approval of Escelsa's
shareholders. According to the agreement, the shares of Iven and GTD subject to
the agreement may not be voted unless both parties agree to vote in the same
manner. Accordingly, if Iven and GTD do not agree as to any particular matter, a
deadlock would result. In addition, over a period of time, Iven has acquired
approximately 8% of the ESCELSA shares in the market to increase its total
participation to 52.27%.
b. Capital Reserves
December 31,
-------------------------
2001 2000
-------------------------
Remuneration on construction work in progress 162,880 160,555
Donations and subsidies 28,720 28,720
Recoverable rate deficit - CRC account 607,712 607,712
Other 50,110 127,082
-------------------------
Total 849,422 924,069
=========================
Remuneration on construction work in progress is the value resulting from the
calculation of interest on funds invested in construction work in progress,
which may be used only for capital increases.
Donations and subsidies represent mainly property donated by the Brazilian
government.
Recoverable rate deficit (CRC) represents compensation for a rate of return
lower than the Brazilian national average for years prior to 1993. The CRC was
applied to reduce payables to Furnas, Eletrobras and others, and the remaining
portion was exchanged for government securities. These offsets were credited
directly to shareholders' equity.
c. Income Reserves
December 31,2000
--------------------------
Legal reserve 188
Undistributed profits 3,319
--------------------------
Total 3,507
==========================
Brazilian laws and Escelsa's by-laws require that certain appropriations be
made from retained earnings to reserve accounts on an annual basis. The Legal
reserve is a requirement for all Brazilian corporations and represents the
annual appropriation of 5% of net income up to a limit of 20% of capital stock,
as determined according to Brazilian corporate legislation. This reserve may be
used to increase capital or to absorb losses, but may not be distributed as cash
dividends.
The Company's by-laws guarantee a minimum annual dividend equal to 25% of the
adjusted net income for the year, as required by Brazilian corporate law.
Interest on stockholders' equity as from January 1, 1996 is considered part of
the minimum dividend.
F-34
20. OPERATING REVENUES
Electricity Sales
Year ended December 31,
---------------------------------
Gross revenues
---------------------------------
2001 2000 1999
----------- ----------- ---------
Final customers-
Residential 489,655 508,360 497,612
Industrial 399,578 375,944 340,305
Commercial, service and other activities 250,407 241,466 219,575
Rural 68,622 63,622 62,570
Miscellaneous 111,095 116,817 113,650
Regulatory assets 298,533 - -
----------- ----------- ---------
1,617,890 1,306,209 1,233,712
Unbilled revenues (273) 6,917 4,107
----------- ----------- ----------
1,617,617 1,313,126 1,237,819
Wholesale 83,519 42,723 39,072
----------- ----------- ----------
Other 29,646 32,944 22,149
=========== =========== ==========
1,730,782 1,388,793 1,299,040
=========== =========== ==========
Year ended December 31,
---------------------------------
Quantities (GWh) (a) (unaudited)
---------------------------------
2001 2000 1999
----------- ----------- ---------
Final customers-
Residential 2,055 2,363 2,308
Industrial 3,669 3,979 3,530
Commercial, service and other activities 1,303 1,403 1,286
Rural 584 607 618
Miscellaneous 826 919 906
----------- ----------- ---------
8,437 9,271 8,648
Wholesale 347 345 334
----------- ----------- ---------
8,784 9,616 8,982
=========== =========== =========
(b) Number of customers in thousands 1,495 1,406 1,344
=========== =========== =========
(a) Includes 2,672 GWh in 2001, 2,836 GWh in 2000 and 2,634 GWh in 1999 related
to Enersul.
(b) Includes 572 thousand in 2001, 541 thousand in 2000 and 518 thousand
consumers in 1999 related to Enersul. Escelsa has entered into contracts
with its 26 largest customers and numerous other large customers. Such
contracts contain minimum demand clauses which require the customer to pay
for either contracted demand or, if greater, actual capacity used.
Contracts have durations of three or five years, with automatic renewals
for equal durations, subject to notice of 12 and 18 months, respectively,
prior to expiration of the term. Other contracts have three-year terms,
with perpetual rolling one year renewals.
Each such contract is subject to termination on approximately 1 1/2 years notice
(if the contract is not terminated, it automatically extends for one additional
year). Tariffs are set pursuant to the Escelsa Concession Contract with ANEEL.
While, historically, none of these contracts has been terminated, there can be
no assurance that any of these contracts will be renewed in the future,
particularly given the threat of competition by IPPs for industrial customers.
If any significant customers terminate their contracts or fail to renew a
contract, Escelsa would be entitled, pursuant to the Power Sector Law, to
immediately reduce its purchases from Furnas by a corresponding volume of
electricity. Customers with whom Escelsa maintained such contracts represented
approximately 47% of its sales of electricity (measured in MWh) and 32% of its
revenues during 2001.
F-35
Enersul has entered into similar contracts with its ten largest customers, which
accounted for approximately 9.5% of Enersul's energy sold by volume during 2001.
21. TAXES ON SALES
December 31,
---------------------------------
2001 2000 1999
---------- ---------- ----------
Value-added tax on sales to final consumers 284,722 286,893 262,706
Other taxes on sales 60,575 43,336 45,852
---------- ---------- ----------
Total 345,297 330,229 308,558
========== ========== ==========
Other taxes on sales includes PIS (0.65%) and Cofins (3%) on all revenues.
22. PENSION PLANS AND OTHER BENEFITS TO EMPLOYEES
a) The Parent Company is the sponsor of FUNDACAO ESCELSA DE SEGURIDADE SOCIAL -
ESCELSOS, a nonprofit organization, whose main purpose is to complement the
benefits granted by the official social security to the Company's employees
through two benefit packages: A Defined Benefit Plan (Plan I) and a Defined
Contribution Plan (Plan II). These benefit plans are based on mathematical
reserves calculated actuarially according to the capitalization regime, which is
calculated annually.
A comparison of the Technical Reserves follows:
TECHNICAL RESERVES: Parent Company
------------------------------
2001 2000
-------------- ---------------
Mathematical Reserves:
Vested benefits 72,604 61,476
Nonvested 77,180 74,285
Reserves to be amortized - (853)
-------------- --------------
149,784 134,908
-------------- --------------
Contingency reserve 22,227 20,451
-------------- --------------
Total 172,011 155,359
============== ==============
b) The table below shows the number of participants for each plan type:
PLAN I PLAN II TOTAL
---------- ------------ -----------
Active participants 41 1,455 1,496
---------- ------------ -----------
Non-active participants
Retirees 641 94 735
Pension beneficiaries 101 4 105
---------- ------------ -----------
742 98 840
---------- ------------ -----------
Total 783 1,553 2,336
========== ============ ===========
c) As a sponsor, the Parent Company matches monthly contribution from the
members of ESCELSOS Foundation, corresponding to the amount established in each
plan, limited to 7% of the total payroll. For 2001, the Parent Company
contributed R$2,552 compared to R$2,519 in 2000.
d) As per CVM Rule 371 of 12/13/2000, starting in fiscal year 2002, publicly
listed companies are required to record and disclose all liabilities related to
post-employment benefit payments, based on rules set forth by NPC Pronouncement
26 from IBRACON. Companies have the option to recognize the liabilities in 2001.
If such option is chosen companies must record such effects directly in
Shareholders' equity as an adjustment to prior periods. Alternatively, companies
can
F-36
wait until 2002 to record the liabilities and defer the recognition of the
related pension expense over a five-year period. Escelsa opted to recognize the
pension liabilities in 2001.
To meet this requirement, ESCELSA commissioned an independent actuarial study to
evaluate such benefits. As a result of such actuarial analysis the following was
identified:
o Coverage for medical, dental, pharmaceutical, life insurance and in
approved cases, dependent care expenses, corresponding to 50% of the
company's salary base;
o Retirement Indemnity Program (AIA) is paid to employees hired through
12/31/1981, payable upon termination of employment, either voluntary
or forced. The AIA guarantees a savings reserve for which the amount
is calculated for each employee in proportion to their social security
contribution period through 10/31/1996, salary and social security
benefit on 10/31/1996.
e) The actuarial premises used for the study were:
o Discount rate 6% per annum
o Expected return on assets 6% per annum
o Future salary growth 3% per annum
o Capacity factor - salaries 100%
o Capacity factor - benefits 98%
f) As a result of the actuarial study conducted, and as per article 84 of CVM
Ruling 371/2000, the present value of the actuarial obligations (excess of
projected benefit obligation over the fair value of the plan's assets) was
calculated and recorded in Shareholders' Equity, as an adjustment to prior years
in the amount of R$20,403, composed of the following:
RETIREMENT HEALTH RETIREMENT
ASSETS (LIABILITIES) TO BE RECOGNIZED PLAN PLAN INDEMNITY
PROGRAM
- ------------------------------------------------------------- ------------------- ---------------- ------------------
o Present value of fully or partially exposed actuarial
obligations (70,491)
o Fair value of assets 96,709
o Present value of fully exposed actuarial obligations (22,768) (7,683)
------------------- ---------------- ------------------
o Funded Status 26,218 (22,768) (7,683)
=================== ================ ==================
The balance of the liability recorded against shareholders' equity as an
adjustment to previous years is composed of the following:
Obligations related to ex-employee benefits 30,451
Deferred income tax and social contributions (33%) (10,048)
---------------
Adjustments to prior years 20,403
===============
g) As shown in the actuarial study, in the Retirement Plan the fair value of the
assets exceeds the present value of the partially and fully exposed actuarial
obligations. However, management has conservatively chosen not to record this
surplus as a deduction to exposed obligations.
A breakdown of current and long-term liabilities related to the post-employment
benefits was conducted based on the actuarial calculation described in item "c"
above for costs expected in 2002, as per the following:
Cost of current service 680
Interest costs 1,740
----------------
Obligations related to post-employment benefits - current 2,420
liabilities
================
F-37
ENERSUL is the sponsor of FUNDACAO ENERSUL, a nonprofit organization, whose main
purpose is to complement the benefits granted by the official social security to
the Company's employees. As a sponsor, the Company pays a monthly installment
proportional to that of the members of FUNDACAO ENERSUL, limited to 7% of the
total payroll. For 2001, ENERSUL contributed R$ 1,888 the fund (R$1,884 in
2000).
The sponsor has a commitment to FUNDACAO ENERSUL, represented by the
corresponding supplemental cost to the amortization installment relative to time
of service prior to the founding of the FUNDACAO ENERSUL, considered as
contribution time, and which will be amortized by the supplemental rate during
the next 12 years and nine months. The estimated amount to be accrued during the
period is approximately R$ 22,533.
A comparison of the Technical Reserves follows:
ENERSUL
------------------------------
2001 2000
TECHNICAL RESERVES: -------------- ---------------
MATHEMATICAL RESERVES:
Vested benefits 42,790 35,258
Nonvested benefits 25,080 29,402
Reserves to be amortized (22,533) (24,692)
-------------- --------------
45,337 39,968
-------------- --------------
TECHNICAL SURPLUS
Contingency reserve 77,488 65,737
Funds 2,369 2,037
-------------- --------------
79,857 67,774
-------------- --------------
TOTAL 125,194 107,742
============== ==============
As per CVM Ruling 371 of 12/13/2000, starting in fiscal year 2002, publicly
listed companies are required to record and disclose all liabilities related to
post-employment benefit payments, based on rules set forth by NPC Bulletin 26
from IBRACON. To meet this requirement, ENERSUL commissioned an independent
actuarial study to evaluate such benefits. As a result of this study, it was
determined that the only pension plan offered would be a defined benefit plan.
The actuarial premises used for the study were:
o Discount rate 6% per annum
o Expected return on assets 6% per annum
o Future salary growth 3% per annum
o Capacity factor - salaries 100%
o Capacity factor - benefits 98%
Asset
Plan as of
ASSETS (LIABILITIES) TO BE RECOGNIZED 12/31/2001 December 31, 2001
- -------------------------------------------------------------------------------- -------------------------------
o Present value of fully or partially exposed actuarial obligations (65,237)
o Fair value of assets 101,535
-------------------------------
o Amount to be recorded 36,298
================================
As shown in the actuarial study, in the Retirement Plan the fair value of the
assets exceeds the present value of the partially and fully exposed actuarial
obligations as of December 31, 2001. However, management has conservatively
chosen not to record this as a surplus, particularly as it is currently
implementing a new pension plan - Pension Plan II, which will be based on
defined contribution for funding and defined benefit for distribution of
benefits, so as to guarantee retirement risks in the first stage of the plan.
F-38
23. MANAGEMENT'S REMUNERATION
Personnel expenses include the amount of R$4,663 (R$3,882 in 2000), which refer
to Management's remuneration.
24. CONSTANT CURRENCY METHOD
As described in Note 2, Brazilian GAAP no longer requires accounting for
inflation effects occurred after December 31, 2000. If inflation effects were to
be recorded during the year 2001, based on the IGP_M variation, shareholders'
equity as of December 31, 2001 and the net income for the year then ended would
be as follows:
Net Shareholders'
Income Equity
----------------- ------------------
As originally reported in the corporate law financial statements (26,136) 731,403
Accounting for inflation not allowed
Under corporate law method-
Investments (285) 500
Goodwill - net amortization 45,040 102,225
Property, plant and equipment - net of depreciation 165,401 842,654
Shareholders' equity (121,632) -
Special liabilities (26,140) (105,763)
Income tax and social contribution effect (5,728) (243,339)
Minority interest (15,165) (76,450)
----------------- -------------------
As inflation effects would have been recognized up to December 31, 2001 15,355 1,251,230
================= ===================
F-39
25. SUMMARY OF DIFFERENCES BETWEEN
BRAZILIAN GAAP AND US GAAP
RELATED TO THE COMPANY
25.1 - Description of the GAAP Differences
The Company's accounting policies comply with Brazilian GAAP. A summary of the
differences between Brazilian GAAP and US GAAP is provided below:
a. Regulated Accounting Principles
The Company adopted the accounting principles established by ANEEL for electric
utilities in Brazil.
a.1 - Applicability of SFAS No. 71,
"Accounting for the Effects of Certain Types of Regulation"
As a result of various actions taken by the Federal government and ANEEL in
2001, the Company is subject to the provisions of SFAS No. 71, "Accounting for
the Effects of Certain Types of Regulation" because the rate-setting structure
in Brazil is now designed to recover the Company's allowable costs. Accordingly,
the Company capitalizes incurred costs as deferred regulatory assets when there
is a probable expectation that future revenue equal to the costs incurred will
be billed and collected as a direct result of the inclusion of the costs in an
increased tariff set by the regulator. The deferred regulatory asset is
eliminated when the Company collects the related costs through billings to
customers. ANEEL performs a tariff review on an annual basis. If ANEEL excludes
all or part of a cost from recovery, that portion of the deferred regulatory
asset is impaired and is accordingly reduced to the extent of the excluded cost.
During 2001, the electricity markets in significant portions of Brazil
experienced rationing, or reduced availability of electricity to customers, due
to low rainfall, reduced reservoir levels and that country's significant
dependence on electricity generated from hydrological resources. These factors
resulted in lower sales for the Company. In December 2001, the Companies reached
an industry-wide agreement (the "agreement") with the Brazilian government that
provided resolution to all rationing related issues as well as to certain other
electricity tariff related issues. The tariff increase will remain in effect
until all recoverable amounts are collected which the Company estimates will
take approximately 4 years. The amount of R$103,740 in the Shareholder's equity
and Net loss reconciliations represent the revenues, which have been reversed of
revenues reported for Brazilian GAAP purposes, considering the 24 month period
for recoverability established in the Emerging Issues Task Force ("EITF") No.
92-7, "Accounting by Rate Regulated Utilities for the Effects of Certain
Alternative Revenue Programs" .
a.2 - Capitalization of Interest Costs Relating
to Construction in Progress
Under Brazilian GAAP, the Company capitalizes both interest costs of borrowed
funds and imputed interest on shareholders' funds applied to construction in
progress. For US GAAP reconciliation purposes, the capitalized imputed interest
on shareholders' funds applied to construction in progress was reversed. Only
interest on borrowed funds remains capitalized and the depreciation was computed
using the rates applicable to the corresponding class of property, plant and
equipment. Though the basis of calculation differs from the Brazilian GAAP.
Under U.S. GAAP, in accordance with the provisions of SFAS no. 34 -
Capitalization of Interest Costs, interest incurred on borrowings is capitalized
to the extent that borrowings do not exceed construction in progress. The credit
is a reduction of interest expense. Under U.S. GAAP, the amount of interest
capitalized excludes the monetary gain associated with the borrowings and the
foreign exchange gains and losses on foreign currency borrowings. The U.S. GAAP
differences between the accumulated capitalized interest on disposals and in
accumulated amortization on disposals relate to the differences between
capitalized interest and related accumulated amortization under Brazilian and
U.S. GAAP which is included in the net book value of disposed property, plant
and equipment.
F-40
a.2 - Special Liabilities
Under Brazilian GAAP, the Company records special liabilities, representing
consumers' contributions to the cost of expanding power supply systems, as
liabilities and includes the related asset in property, plant and equipment,
subject to depreciation over the applicable useful lives. Under US GAAP,
contributions received from customers as reimbursement for construction costs
are typically credited against the cost of the related fixed assets. For US GAAP
reconciliation purposes, special liabilities were amortized using the
depreciation rates applicable to the corresponding class of property, plant and
equipment acquired with such consumers' contributions.
b. General Accounting Principles
b.1- Pension and Other Benefits
Under Brazilian GAAP, until December 31, 2001, pension plan and other benefits
were recognized on a cash basis. As per CVM Rule 371 of 12/13/2000, starting in
fiscal year 2002, publicly listed companies may record and are required to
disclose all liabilities related to benefit payments to ex-employees, based on
rules set forth by NPC Pronouncement 26 from IBRACON, which are quite similar to
SFAS 87 and 106 rules. Alternatively, was granted the option to amortize such
initial transition obligation as of December 31, 2001, directly to
shareholders' equity. Escelsa has adopted such option for US GAAP
reconciliation purposes, SFAS no. 87, "Employers' Accounting for Pensions" and
SFAS no. 106, "Employers' Accounting for Post-retirement Benefits Other Than
Pensions" require recognition of costs on a more comprehensive accrual basis. In
addition, US GAAP requires the recognition of either an asset or a liability, as
appropriate, for the difference between projected benefit obligations (as
defined in SFAS no. 87 and SFAS no. 106) and plan assets. Such assets must be
stated at fair value, as adjusted for certain reconciling items.
b.2 - Purchase Accounting
Under Brazilian GAAP, purchases of the majority of the shares of another company
are recorded at the book value, restated for inflation in consolidation up to
December 31, 2000. The difference between the purchased company's net assets and
the purchase price is recorded as goodwill and amortized over the concession
term of the purchased company. The purchaser is permitted to defer amortization
of goodwill for several months until the acquired company is integrated. In
addition, Brazilian GAAP permits amortization of goodwill based on projections
of future profitability.
Under US GAAP, the assets and liabilities of the purchased company must be
recorded at fair value, and the difference between the fair value of net assets
and the purchase price is recorded as goodwill. Although goodwill may be
amortized over up to forty years under US GAAP, the Company will use a
thirty-year amortization period on a straight-line basis for US GAAP, which is
the concession term of Enersul.
Certain adjustments subsequent to the purchase must be recorded as an adjustment
to goodwill under US GAAP. During 1998, Enersul reversed the valuation reserve
related to the deferred tax asset for unused tax loss carry forwards. All of
these loss carry forwards related to periods prior to the purchase date. Under
US GAAP, the reversal of the valuation reserve is a reduction of goodwill.
The goodwill computed using the fair values assigned to assets and liabilities
totaled R$565,349, compared to R$479,751 under Brazilian GAAP (see note 11). The
fair value of fixed assets under US GAAP totaled R$855,705 compared to book
value of R$941,299 under Brazilian GAAP. . The Company adjusted shareholders'
equity and results of operations reported in 2001 for the cumulative effects of
the additional depreciation charged to operations under Brazilian GAAP in the
amount of R$15,406 (or R$6,709, net of income taxes and minority interest). The
amounts previously reported in the US GAAP reconciliation for shareholders'
equity and results of operations were not restated by the Company since the
effects were not deemed to be material to shareholders' equity and the
historical trend of results of operations.
b.3 - Income Taxes
Under Brazilian GAAP, deferred income tax liabilities are recognized based on
the amount of future expected taxes to be paid. Deferred income tax assets
related to deductible temporary differences (expenses that are accrued but not
deductible until future periods) or tax loss carryforwards are recognized when
there is a reasonable certainty the Company will generate profits against which
it can offset such an asset.
F-41
Under US GAAP, deferred income tax assets related to deductible temporary
differences or tax loss carry forwards are recognized and a valuation reserve is
not recorded if it is more likely than not that such assets will be realized.
Under Brazilian GAAP, the deferred tax effects related to the indexing of
permanent assets for financial reporting but not for tax purposes are recorded
in equity. Under US GAAP, this deferred tax liability must be charged to the
statement of operations.
The reversal of the valuation reserve related to deferred tax assets of Enersul
for unused tax loss carry forwards was recorded as a credit to statement of
operations for the year ended December 31, 1998 for Brazilian GAAP. For US GAAP
the reversal of this reserve was recorded as a reduction of the goodwill on the
purchase of Enersul. For Brazilian GAAP, the reversal totaled R$129,933. For US
GAAP, the valuation reserve was R$104,734 (63,479 net of the minority interest),
as the deferred tax asset had been offset by deferred tax liabilities mainly
related to the basis difference between Brazilian GAAP and US GAAP.
b.4 - Dividends Proposed
Under Brazilian corporate law, at each balance sheet date, the board of
directors is required to propose a dividend distribution from earnings and
accrue for this in the financial statements of the Company. Since this proposal
may be ratified or modified at the annual shareholders' meeting, for US GAAP
reconciliation purposes, such dividends were not considered as declared at the
balance sheet date since they were not approved as of that date and were
reversed.
b.5 - Impairment of Long-lived Assets
Under Brazilian GAAP, the carrying value of fixed assets are written down to
realizable values when it is estimated that such assets will not be realized
through normal depreciation without loss to the company.
Under US GAAP, the Statement of Financial Accounting Standards- SFAS ("SFAS")
121 - "Accounting for the Impairment of Long-lived Assets and Long-lived Assets
to be Disposed of". Under SFAS 121, a provision for impairment is recorded
against long-lived assets when there is an indication, based on a review of
undiscounted future cash flows, that the carrying value of an asset or a group
of assets may not be recoverable. No provision was required for US GAAP
reconciliation purposes.
b.6 - Statements of Cash Flows
Brazilian GAAP does not require the presentation of a statement of cash flows as
required by US GAAP. Changes in working capital are presented in the statement
of changes in financial position. US GAAP requires the presentation of a
statement of cash flows describing a company's cash flows from operating,
financing and investing activities.
b.7 - Earnings Per Share
Brazilian GAAP permits earnings per share to be calculated based on the number
of shares outstanding at year end. Under US GAAP, the earnings per share
calculation takes into account share equivalents and the number of shares is
computed on a weighted average basis. In addition, US GAAP requires the
computation of diluted earnings per share, which is not required under Brazilian
GAAP. Since there were no changes in the number of outstanding shares for the
years ended December 31, 2001, 2000 and 1999, the weighted average shares
outstanding for US GAAP purposes was the same as the year end amounts. There
were no dilutive potential common shares. Therefore,diluted earnings per share
are not shown.
b.8 - Financial Statement Note Disclosures
Brazilian GAAP generally requires less information to be disclosed in the notes
to the financial statements than US GAAP.
The additional disclosures required by US GAAP, which are relevant to the
accompanying financial statements, are included in Note 25.3.
F-42
b.9 - Net Income Before Taxes and Minority Interest
Under US GAAP, this line item would not be permitted in the income statement.
The line under Brazilian GAAP is intended to measure operations before these
items.
b.10 - Amortization of Goodwill
As permitted under Brazilian GAAP, the Company is amortizing goodwill over the
30 year concession period based on the proportion of projected net income for
the period subsequent to the purchase of Enersul. Also, no goodwill was
amortized in 1997.
Under US GAAP, the straight-line method of amortization is being used over a
30-year period . In addition, goodwill was amortized for the period from the
purchase date, November 25, 1997, to December 31, 1997 for US GAAP.
b.11 - Gain on repurchased senior notes
Under US GAAP, the repurchase of senior notes is considered an extinguishment of
debt and, therefore, the gain is accounted for as an extraordinary item in the
statement of operations.
b.12 - Accounting and reporting of investments in marketable
securities
Under Brazilian GAAP, the Company has classified investments in marketable
securities as current assets since they are highly liquid and readily available
for sale at any time.
Under US GAAP, these investments would be classified as available for sale in
accordance with SFAS 115, "Accounting for Certain Investments in Debt and Equity
Securities". Unrealized holding gains and losses are excluded from earnings and
reported in other comprehensive income until realized, net of related income tax
effects in accordance with SFAS 109, "Accounting for Income Taxes". Also, under
US GAAP, a company that presents a classified balance sheet should report
individual available for sale securities as either current or long-term, as
appropriate, under the provisions of ARB No. 43, Chapter 3A, "Working Capital -
Current Assets and Current Liabilities". In 2000 all mareketable securities
would be classified as current assets under USGAAP. In 2001, all marketable
securities would be classified as long-term under US GAAP. Unrealized gains and
losses in 2001 are not significant. There were no unrealized gains or losses in
2000 or 1999.
b.14 - Net operating revenue
Net operating revenue under Brazilian GAAP differs from US GAAP on the
recognition of revenues from value added and other sales taxes, as presented
below:
2001 2000 1999
---------------------- ----------------- ----------------
Net revenue under BR GAAP 1,385,485 1,058,564 990,482
Value added and other sales taxes 345,297 330,229 308,558
-----------------------------------------------------------
Net revenue under US GAAP 1,730,782 1,388,793 1,299,040
===========================================================
25.2 - Reconciliation of Differences Between
Brazilian and US GAAP
Net income and restated shareholders' equity adjusted to take into account the
significant differences between Brazilian GAAP and US GAAP, except for the
comprehensive effects of price-level changes (as the Brazilian economy was
inflationary prior to 1998), are as follows:
F-43
a. Shareholders' Equity
As of December 31,
--------------------------------
2001 2000
(As restated)
-------------- -----------------
As reported on the accompanying Brazilian GAAP financial statements 1,093,825 1,171,979
Different criteria for-
Regulatory asset (103,740) -
Capitalization of interest during construction-
Reversal of interest capitalized under-
Brazilian regulated accounting (402,954) (398,415)
Capitalization of interest 321,865 317,326
Depreciation of interest capitalized, net 48,495 46,791
Reversal of depreciation - Fair value fixed asset 15,406 -
Cumulative depreciation of special liabilities 86,398 76,232
Reversal of pension and other postretirement obligations - CVM 371- 30,451
Note21
Pension and postretirement benefits SFAS 87 and
SFAS 106 adjustment (27,120) (35,208)
Reversal of dividends declared - 13,245
Accumulated amortization of goodwill (52,291) (39,498)
Reversal of valuation allowance related to tax loss carryforwards of
Enersul (129,933) (129,933)
Effects of income tax on the adjustment above-
Deferred Income tax liability (165,863) (145,315)
Deferred Income tax and social contribution asset 176,159 143,096
Minority interest 33,205 39,013
-------------- ---------------
Approximate restated shareholders' equity according to US GAAP 923,903 1,059,313
============== ===============
b. Net Income (Loss)
Year ended December 31,
------------------------------------------------
2001 2000 1999
(As restated)
--------------- -------------- -----------------
As reported on the accompanying price-level financial statements (60,076) 52,647 (17,280)
Different criteria for-
Regulatory Asset (103,740)
Capitalization of interest 4,539 - 18,850
Depreciation of capitalized interest 1,704 2,075 2,165
Depreciation - Fixed Asset - Fair Vale 15,406 - -
Amortization of special liabilities 10,166 9,535 9,288
Pension and postretirement benefits SFAS 87 and
SFAS 106 adjustment 8,088 6,834 8,134
Deferred income tax effect from indexation of shareholders' equity - (35,895) (91,998)
Amortization of goodwill (12,793) (13,892) 31,604
Effects of income tax on the adjustment above-
Deferred Income tax liability (11,220) (3,832) (11,491)
Deferred Income tax asset 31,565 (2,255) 5,517
Minority interest (5,808) (3,036) 7,915
Classification of extraordinary item - - (10,325)
--------------- -------------- -------------
Approximate net income (loss) before extraordinary item under US GAAP (122,169) 12,181 (47,621)
Extraordinary item - gain on extinguishment of debt, net of applicable tax
effect of R$5,085 in 1999 - - 10,325
--------------- -------------- -----------------
F-44
--------------- -------------- -----------------
Approximate net income (loss) under US GAAP (122,169) 12,181 (37,296)
=============== ============== =================
US GAAP net income (loss) before extraordinary item - per share (in (26.85) 2.68 (10.46)
Brazilian Reais)
Extraordinary item - per share (in Brazilian Reais) - - 2.26
=============== ============== =================
US GAAP net income (loss) per share (in Brazilian Reais) (26.85) 2.68 (8.20)
=============== ============== =================
Weighted average shares outstanding 4,550,833 4,550,833 4,550,833
=============== ============== =================
(As restated) (As restated)
Shareholders' equity under US GAAP as of beginning of the year 1,059,313 1,047,132 1,156,522
US GAAP net income (loss) for the year (122,169) 12,181 (37,296)
Dividends (13,241) - (72,094)
--------------- -------------- -----------------
Shareholders' paid equity under US GAAP as of the end of the year 923,903 1,059,313 1,047,132
=============== ============== =================
c. Restatement of prior year amounts:
During 2001 the Company determined that differences occurred in the
determination of net income and shareholders' equity under US GAAP in previous
years, relating to the recognition of deferred income tax assets and
liabilities, reversal of valuation allowance recorded in statements of
operations under Brazilian GAAP and the related minority interest effects. The
effect of these differences on previously reported shareholders' equity and Net
income (loss) amounts under US GAAP are as shown as follows:
c.1. Shareholders' equity:
As of December 31
-----------------------------
2000 1999
---------------- ------------
Shareholders' equity under USGAAP as previously reported
1,015,187 1,003,006
Effect of differences related to deferred income tax assets
and liabilities 59,399 59,399
Effect of differences related to reversal of valuation (15,273) (15,273)
allowance
----------- -----------
Shareholders' equity under USGAAP as restated 1,059,313 1,047,132
========== ==========
c.2. Net income (loss) :
As of December 31,
--------------------------------
2000 1999
------------------- ------------
Net income (loss) under USGAAP as previously reported 12,181 (55,816)
Effect of differences related to deferred income tax assets
and liabilities - 8,201
Effect of differences related to reversal of valuation - 10,319
allowance
------- --------
Net income (loss) under USGAAP as restated 12,181 (37,296)
======= ========
F-45
25.3 - Additional Disclosures Required by US GAAP
a. Pension Funds - Escelsa
SFAS 87 was adopted by Escelsa on December 31, 1994. Prior to such date, the
application of SFAS 87 was not feasible due to the lack of sufficient
information for prior years. The unrecognized net transaction obligations for
the pension and retirement plans detailed below are being amortized on a
straight-line basis over 15 years as from December 31, 1988. The amortization
from December, 31, 1988 through December 31, 1994 was recorded directly to
equity in the opening balance sheet under US GAAP and was approximately R$16,486
(funded pension plan) and R$5,711 (retirement indemnity program).
a.1 - Funded Pension Plan
Until May 31, 1998, Escelsa sponsored only a defined benefit pension plan
covering all employees, with benefits based on salary and social security
benefits. On June 1, 1998, Escelsa introduced a defined contribution plan to
which employees could voluntarily transfer. The plan's assets are invested in a
separate fund administered by an independent legal entity called Escelsos.
Contributions are made both by the sponsor and the participants based on an
actuarial study prepared by an internal actuary. This study is conducted
according to prevailing Brazilian regulations, as determined by the Social
Security authorities, and is aimed to provide enough funds to cover future
benefit payments. The fund's assets comprise principally time deposits, equity
securities, government securities and real estate.
Based on the report prepared by independent actuaries, the funded status and the
amounts recognized in the Company's US GAAP balance sheet for Escelsa only
(excluding Enersul) for the above plan, calculated according to SFAS 87, are as
follows:
As of December 31,
----------------------------------------
2001 2000
----------------- -------------------
Actuarial present value of benefit obligations-
Vested benefit obligation (60,060) (54,555)
Non-vested benefit obligation (3,359) (5,264)
----------------- -------------------
Accumulated benefit obligation (63,419) (59,819)
Effect of future projected salary increases (441) (1,393)
----------------- -------------------
Projected benefit obligation (63,860) (61,212)
Plan assets at fair market value 87,611 88,286
----------------- -------------------
Funded status 23,751 27,074
Unrecognized net transition obligation, being amortized 451 676
over 15 years from December 1988
Unrecognized net (gain) (26,731) (34,839)
----------------- -------------------
Accrued pension cost liability (2,529) (7,089)
================= ===================
F-46
The net periodic pension cost (as defined under SFAS 87) includes the following
elements excluding Enersul:
Year ended December 31,
--------------------------------------
2001 2000 1999
----------- ------------ -------------
Net periodic pension cost-
Service cost-benefits earned during the period 344 505 532
Interest cost on projected benefit obligation 3,523 3,616 7,231
Amortization of net transition obligation 225 225 272
Actual return on assets (4,156) (3,978) (39,166)
Net deferral (1,007) (1,206) 31,904
Amortization of net gains (2,951) (2,939) (733)
Employee contributions (131) (172) (263)
----------- ------------ -------------
Net periodic pension cost under US GAAP (4,153) (3,949) (223)
Additional credit under US GAAP 4,560 4,457 3,143
----------- ------------ -------------
Amount recorded under Brazilian GAAP 407 508 2,920
=========== ============ =============
=========== ============ =============
The assumptions used were (real rates):
Assumptions 2001 2000 1999
------------------------------------------ ------- ------ ------
Discount rate 6% 6% 10%
Rate of increase in compensation 3% 3% 7%
Expected long-term rate of return on assets 6% 6% 10%
a.2 - Retirement Indemnity Program
In addition to benefits provided under Escelsa's funded pension plans, Escelsa
sponsors an unfunded retirement indemnity program called AIA that provides a
lump sum amount at retirement to employees who joined Escelsa before December
31, 1981. The funded status and the net periodic pension cost for this program
under SFAS 87, as identified in the report prepared by the independent
actuaries, are given below. The same assumptions used for the funded pension
plan were used.
As of December 31,
-----------------------------------------
2001 2000 1999
------------- ------------- -------------
Funded status-
Actuarial present value of benefit obligations-
Vested benefit obligation (3,493) (3,559) (2,976)
Non-vested benefit obligation (2,651) (3,588) (3,257)
------------- ------------- -------------
Accumulated benefit obligation (6,144) (7,147) (6,233)
Effect of future projected salary increase (816) (1,092) (2,784)
Projected benefit obligation (6,960) (8,239) (9,017)
------------- ------------- -------------
Projected benefit obligation in excess of plan (6,960) (8,239) (9,017)
assets
Unrecognized net transition obligation, being
amortized over 15 years from December 31, 1988 1,903 2,856 3,807
Unrecognized prior service cost (3,238) (3,690) (4,142)
Unrecognized net (gain) (3,323) (2,787) (2,099)
------------- ------------- -------------
Accrued pension cost liability (11,618) (11,860) (11,451)
============= ============= =============
============= ============= =============
F-47
The net periodic pension cost (as defined under SFAS 87) includes the following
elements:
Year ended December 31,
-----------------------------------------
2001 2000 1999
------------- ------------- -------------
Net periodic pension cost-
Service cost-benefits earned during the period 297 362 420
Interest cost on projected benefit obligation 468 516 817
Amortization of net transition obligation 952 952 1,143
Amortization of net gain (214) (120) (426)
Amortization of prior service cost (452) (452) (543)
------------- ------------- -------------
Net periodic pension cost 1,051 1,258 1,411
Additional credit (expense) under US GAAP 242 409 2,017
------------- ------------- -------------
Amount recorded under Brazilian GAAP 1,293 1,667 3,428
============= ============= =============
Assumptions used were (real rates):
Assumptions 2001 2000 1999
---------------------------------- ---- ---- ----
Discount rate 6% 6% 10%
Expected return on plan assets 6% 6% 10%
Rate of compensation increase 3% 3% 7%
a.3 - Postretirement Benefits Other Than Pension
In terms of postretirement benefits other than pension, Escelsa provides medical
and life insurance benefits to retired employees for the remainder of their
lifetime. The funded status and the net postretirement benefit cost for this
program under SFAS 106, as identified in the report prepared by the independent
actuaries, are given below:
As of December 31,
-----------------------------------------
2001 2000 1999
------------ ------------ -----------
Funded status-
Accumulated postretirement benefit obligation in
excess of plan assets (21,707) (22,793) (22,227)
Unrecognized net loss from experience different than
assumed 6,739 8,083 8,847
Unrecognized net prior service cost (2,081) (2,356) (2,632)
--------------- ---------------- ---------------
Accrued liability (17,049) (17,066) (16,012)
=============== ================ ===============
The net postretirement benefit cost, as defined under SFAS 106, includes the
following elements:
Year ended December 31,
--------------------------------------
2001 2000 1999
------------- ------------- ----------
Net postretirement benefit cost-
Service cost-benefits earned during the period 440 445 545
Interest cost on projected benefit obligation 1,327 1,302 2,439
Net loss 400 439 656
Prior service cost (276) (276) (332)
------------- ------------- ----------
Net postretirement benefit cost 1,891 1,910 3,308
Additional credit (expense) under US GAAP 17 1,054 1,169
------------- ------------- ----------
Amount recorded under Brazilian GAAP 1,908 2,964 4,477
============= ============= ==========
F-48
Assumptions used were (real rates):
Assumptions 2001 2000 1999
------------------------------------------------------ -------- -------- -------
Discount rate 6% 6% 10%
Annual increase in employer annual payment to retirees 0% 0% 4%
Health care cost trend rate on covered changes N/A N/A N/A
On March 31, 1997, Escelsa modified the health care plan to express benefits as
a fixed monthly value indexed for inflation. Therefore, the health care cost
trend rate no longer affects the liabilities of the plan.
a.4 - Additional information
Information required by Financial Accounting Standards Board Statement no. 132
is as follows:
Retirement Other postretirement
Pension plan indemnity Benefit
----------------------- ------------------- --------------------
2001 2000 2001 2000 2001 2000
----------- --------- -------- -------- ---------- -------
Change in benefit obligation-
Benefit obligation at the beginning of 61,212 63,095 8,239 9,017 22,793 22,227
The year
Service cost 344 505 297 362 440 445
Interest cost 3,523 3,616 467 516 1,327 1,302
Actuarial loss (gain) 4,103 (815) (750) (807) (945) (325)
Benefit payments (5,322) (5,189) (1,293) (849) (1,908) (856)
------------ ----------- ------------ ------------ ------------ -----------
Benefit obligation at end of year 63,860 61,212 6,960 8,239 21,707 22,793
Change in plan assets-
Fair value of plan assets at the
beginning of the year 88,286 88,854 - - - -
Actual return on plan assets 4,156 3,978 - - - -
Employer contributions 408 509 - - - -
Plan participants' contribution 83 134 - - - -
Gross benefits paid (5,322) (5,189) - - - -
------------ ----------- ------------ ------------ ------------ -----------
Fair value of plan assets at end of 87,611 88,286 - - - -
year
Funded status-
Funded status at end of year 23,751 27,074 (6,960) (8,239) (21,707) (22,793)
Unrecognized net actuarial (gain) loss (26,731) (34,839) (3,323) (2,787) 6,739 8,083
Unrecognized prior service cost - - (3,238) (3,690) (2,081) (2,356)
Unrecognized transition obligation 451 676 1,903 2,856 - -
------------ ----------- ------------ ------------ ------------ -----------
Net amount recognized at end of year (2,529) (7,089) (11,618) (11,860) (17,049) (17,066)
------------ ----------- ------------ ------------ ------------ -----------
Amounts recognized in the statement
of financial position consist of-
Accrued benefit cost (2,529) (7,089) (11,618) (11,860) (17,049) (17,066)
------------ ----------- ------------ ------------ ------------ -----------
Net amount recognized at end of year (2,529) (7,089) (11,618) (11,860) (17,049) (17,066)
============ =========== ============ ============ ============ ===========
F-49
b. Pension Funds - Enersul
b.1 - Funded Pension Plan
Enersul sponsors a defined benefit pension plan covering all employees, with
benefits based on salary and social security benefits. The plan's assets are
invested in a separate fund administered by an independent legal entity,
Fundacao Enersul. Contributions are made both by the sponsor and the
participants based on an actuarial study prepared by an independent actuary.
This study is conducted according to prevailing Brazilian regulations, as
determined by the Social Security authorities, and is aimed to provide enough
funds to cover future benefit payments. The fund's assets comprise principally
time deposits, equity securities, government securities and real estate,
including 366,706 thousand common shares and 366,706 thousand preferred shares
of Enersul as of December 31, 2001.
Based on the report prepared by independent actuaries, the funded status and the
amounts recognized in Enersul's balance sheet for the above plan, calculated
according to SFAS 87 are presented below.
As of December 31,
------------------------------------------
2001 2000 1999
------------- -------------- -------------
Funded status-
Actuarial present value of benefit obligations-
Vested benefit obligation (36,850) (36,700) (38,222)
Non-vested benefit obligation (14,195) (13,651) (10,935)
------------- -------------- -------------
Accumulated benefit obligation (51,045) (50,351) (49,157)
Effect of future projected salary increase (8,055) (10,480) (14,220)
------------- -------------- -------------
Projected benefit obligation (59,100) (60,831) (63,377)
Plan assets at fair market value (1) 91,983 88,206 92,004
------------- -------------- -------------
Projected benefit obligation less than
plan assets 32,883 27,375 28,627
Unrecognized net transition obligation, being amortized
over 15 years from December 31, 1989 3,844 4,989 6,132
Unrecognized net gain (32,653) (31,557) (37,794)
------------- -------------- -------------
Accrued pension cost liability 4,076 807 (3,035)
============= ============== =============
============= ============== =============
(1) The plan assets shown above correspond to the market value of assets net of
receivable for sponsor contributions, payable benefits and contingency
funds to cover potential cost associated with additional medical, benefits
plan administration and employee loans.
The net periodic pension cost (as defined under SFAS 87) includes the following
elements:
As of December 31,
-------------------------------------------
2001 2000 1999
------------- --------------- -------------
Net periodic pension cost-
Service cost-benefits earned during the period 1,646 1,743 2,159
Interest cost on projected benefit obligation 3,559 3,718 7,223
Actual return on assets (4,321) (3,032) (34,527)
Amortization of net transition obligation 1,143 1,143 1,373
Net deferral (969) (2,496) 26,915
Net gain (1,508) (1,835) (536)
Employee contributions (1,038) (1,128) (1,388)
------------- --------------- -------------
Net periodic pension cost under US GAAP (1,487) (1,887) 1,219
Additional credit under US GAAP 3,269 2,228 1,802
------------- --------------- -------------
Amount recorded under Brazilian GAAP 1,782 341 3,021
============= =============== =============
F-50
The assumptions used were (real rates):
Assumptions 2001 2000 1999
-------------------------------- ------ ------ -------
Discount rate 6% 6% 10%
Rate of compensation increase 3% 3% 7%
Expected return on plan assets 6% 6% 10%
b.2 - Additional Information
Information required by Financial Accounting Standards Board Statement no. 132
is as follows:
Pension plan
--------------------------------
2001 2000
----------------- --------------
Change in benefit obligation-
Benefit obligation at the beginning of year 60,831 63,377
Service cost 1,646 1,743
Interest cost 3,559 3,718
Actuarial (gain) (3,603) (4,249)
Gross benefit payments (3,333) (3,758)
----------------- --------------
Net benefit obligation at end of year 59,100 60,831
Change in plan assets-
Fair value of plan assets at beginning of year 88,206 92,004
Actual return of plan assets 4,321 (3,032)
Employer contributions 1,782 1,954
Plan participants' contribution 1,008 1,038
Gross benefit paid (3,333) (3,758)
----------------- --------------
Fair value of plan assets at end of year 91,983 88,206
Funded status-
Funded status at end of year 32,883 27,375
Unrecognized net actuarial (gain) (32,653) (31,557)
Unrecognized net transition obligation 3,845 4,989
----------------- --------------
Net amount recognized at end of year 4,076 807
----------------- --------------
Amounts recognized in the statement of financial position
consist of-
Accrued benefit cost 4,076 807
----------------- --------------
Net amount recognized at end of year 4,076 807
================= ==============
c. Realizability of Long-term Assets
The Company continually evaluates the carrying value and the economic useful
life of its long-term assets, including property, plant and equipment, based on
the operating results and anticipated future cash flows. The estimated future
cash flows for each major group of assets owned by the Company are dependent
upon a variety of factors including the condition of the company's plants and
installations, economic and regulatory developments in Brazil, the demand for
electricity in the regions where the Company operates, the effect of
privatization on electric utilities, and the timing and cost of completion of
the plants under construction. The Company will adjust the carrying value and
related amortization period if and when appropriate.
F-51
d. Concentration of Credit Risk
Credit risk with respect to customer accounts receivable is diversified. The
Company continually monitors its customer accounts receivable and limits its
exposure to bad debts by curtailing service if any invoice is one month overdue.
Exceptions comprise supply of electricity that must be maintained for reasons of
safety or national security.
e. Fair Value of Financial Instruments
Except for cash and cash equivalents, which are stated at cost plus accrued
interest and which approximate fair value, the carrying value of Escelsa's other
financial instruments, in reais, approximates fair value at such dates
reflecting the short-term maturity, frequent repricing or estimated market value
(when lower than cost) at December 31, 2001, 2000 and 1999 of these instruments.
With respect to the senior notes issued by the Company, which carrying value as
of December 31, 2001 is R$999,995, their fair value, based on the bid price as
of the same date is R$859,996.
Based on interest rates currently available to Escelsa for others bank loans
with similar terms and average maturities, the fair value of other long-term
debt at December 31, 2001, 2000 and 1999 approximates its carrying value.
Fair value estimates are made at a specific date, based on the financial
instruments. These estimates are subjective in nature and involve uncertainties
and matters of significant judgment and, therefore, cannot be determined with
precision. Changes in assumptions could significantly affect the estimates.
f. Segment reporting
The Company operates in only one segment as its operating revenues are basically
derived from the sale of electricity to the final customers in the states of
Espirito Santo and Mato Grosso do Sul.
g. New accounting pronouncements
SFAS no. 133, "Accounting for Derivative
Instruments and Hedging Activities"
In 1998, the Financial Accounting Standards Board (FASB) issued Statement of
Financial Accounting Standards (SFAS) No.133, "Accounting for Derivative
Instruments and Hedging Activities," which was subsequently amended by SFAS No.
137 and SFAS No. 138. SFAS No. 133 must be applied to all derivative instruments
and certain derivative instruments embedded in hybrid instruments and requires
that such instruments be recorded in the balance sheet either as an asset or
liability measured at its fair value through earnings, with special accounting
allowed for certain qualifying hedges.
If the derivative is designated as a hedge, depending on the nature of the
hedge, changes in the fair value of derivatives that are considered to be
effective, as defined, will either offset the change in fair value of the hedged
assets, liabilities, or firm commitments through earnings or will be recorded in
other comprehensive income until the hedged item is recorded in earnings. Any
portion of a change in a derivative's fair value that is considered to be
ineffective, as defined, may have to be immediately recorded in earnings. Any
portion of a change in a derivative's fair value that the Company has elected to
exclude from its measurement of effectiveness, such as the change in time value
of option contracts, will be recorded in earnings.
... The adoption of SFAS 133 as of January 1, 2001 did not have a significant
impact on the Company's statement of operations. Also, at December 31, 2001 the
fair value of swap instruments was not significant to the Company's financial
position and results of operations.
F-52
SAB no. 101, "Views on Selected Revenue Recognition Issues"
In December 1999, the staff of the US Securities and Exchange Commission issued
Staff Accounting Bulletin no. 101, "Views on Selected Revenue Recognition
Issues" ("SAB 101") that sets forth the staff's views in applying generally
accepted accounting principles to selected revenue recognition issues. SAB 101
is effective for the second quarter of 2000. SAB101 did not have a significant
effect on the financial statements.
SFAS no. 141, "Business Combinations"
During June 2001, the FASB issued SFAS No. 141, "Business Combinations". SFAS
No. 141 addresses financial accounting and reporting for business combinations
and supersedes APB Opinion No. 16 (Opinion 16), "Business Combinations" and SFAS
38, "Accounting for Preacquisition Contingencies of Purchased Enterprises". All
business combinations in the scope of SFAS No. 141 are to be accounted for using
one method, the purchase method. In addition, SFAS No.141 establishes that
intangible assets be recognized as assets apart from goodwill if they meet one
of two criteria the contractual-legal criterion or the separability criterion.
To assist in identifying acquired intangible assets, SFAS No. 141 also provides
a list of intangible assets that meet either of those criteria. In addition to
the disclosure requirements prescribed in Opinion 16, SFAS No. 141 requires
disclosure of the primary reasons for a business combination and the allocation
of the purchase price paid to the assets acquired and liabilities assumed by
major balance sheet caption. SFAS No. 141 also establishes that when the amounts
of goodwill and intangible assets acquired are significant to the purchase price
paid, disclosure of other information about those assets is required, such as
the amount of goodwill by reportable segment and the amount of the purchase
price assigned to each major intangible asset class. The provisions of SFAS No.
141 apply to all business combinations initiated after June 30, 2001. SFAS No.
141 also applies to all business combinations accounted for using the purchase
method for which the date of acquisition is July 1, 2001, or later.
Adoption of SFAS 141 had no effect on the Company's consolidated results of
operations and financial position under U.S.GAAP reporting.
SFAS no. 142, "Goodwill and Other Intangible Assets"
During June 2001, FASB issued SFAS No. 142, "Goodwill and Other Intangible
Assets". SFAS No. 142 addresses financial accounting and reporting for acquired
goodwill and other intangible assets and supersedes APB Opinion 17, Intangible
Assets. SFAS No. 142 also amends SFAS No. 121, "Accounting for the Impairment of
Long Lived Assets and for Long Lived Assets to Be Disposed Of", to exclude from
its scope goodwill and intangible assets that are not amortized. SFAS No. 142
addresses how intangible assets that are acquired individually or with a group
of other assets (but not those acquired in a business combination) should be
accounted for in financial statements upon their acquisition. This Statement
also addresses how goodwill and other intangible assets should be accounted for
after they have been initially recognized in the financial statements. The
provisions of SFAS No. 142 are required to be applied starting with fiscal years
beginning after December 15, 2001. Early application is permitted for entities
with fiscal years beginning after March 15, 2001, provided that the first
interim financial statements have not been issued. An exception to SFAS No. 142
application date is for goodwill and intangible assets acquired after June 30,
2001, which will be immediately subject of the non-amortization and amortization
provisions of this statement.
The Company has commenced the process of evaluating the impact of the provisions
of SFAS No. 142 to its consolidated financial position and results of
operations. A first impact identified is that goodwill on the purchase of
Enersul will no longer be amortized, starting January 1, 2002. Total
amortization during year 2001 was R$3,011. The Company is currently evaluating
if, based on the provisions of SFAS 142, any impairment loss should be
recognized on this goodwill balance, which amounts to R$439,770 as of December
31, 2001. Based on preliminary studies, Management does not expect any
impairment loss to be recognized due to the adoption of SFAS 142 as of January
1, 2002.
F-53
SFAS no. 143, "Accounting for Asset Retirement Obligations"
During June 2001, FASB issued Statement of Financial accounting Standards No.
143 (SFAS No. 143), "Accounting for Asset Retirement Obligations". SFAS No. 143
basically requires that the fair value of a liability for an asset retirement
obligation be recognized in the period in which it is incurred if a reasonable
estimate of fair value can be made. The associated asset retirement costs are
capitalized as part of the carrying amount of the long-lived asset. Under SFAS
No. 143 the liability for an asset retirement obligation is discounted and
accretion expense is recognized using the credit-adjusted risk-free interest
rate in effect when the liability was initially recognized. In addition,
disclosure requirements contained in SFAS No. 143 will provide more information
about asset retirement obligations. SFAS No. 143 is effective for financial
statements issued for fiscal years beginning after June 15, 2002 with earlier
application encouraged. The Company is currently evaluating if the
implementation of SFAS No. 143 will have a material impact in the Company's
financial position and results of operations.
SFAS no. 144, "Accounting for the Impairment or Disposal of Long Lived Assets"
During August 2001 FASB issued Statement of Financial Accounting Standards No.
144 (SFAS No. 144), "Accounting for the Impairment or Disposal of Long Lived
Assets", which supersedes Statement of Financial Accounting Standards No. 121
(SFAS No. 121), "Accounting for the Impairment of Long Lived Assets and for Long
Lived Assets to be Disposed Of " but retains SFAS No. 121 fundamental provisions
for (a) recognition/measurement of impairment of long lived assets to be held
and used and (b) measurement of long lived assets to be disposed of by sale.
SFAS No. 144 also supersedes the accounting and reporting provisions of APB
Opinion No. 30 (APB No. 30),"Reporting the Results of Operations" for segments
of a business to be disposed of but retains APB No. 30's requirement to report
discontinued operations separately from continuing operations and extends that
reporting to a component of an entity that either has been disposed of or it is
classified as held for sale. SFAS No. 144 is effective for fiscal years
beginning after December 15, 2001 and interim periods within those years, with
early application encouraged. Management expects that the adoption of SFAS No.
144 as of January 1, 2002 will not have a material effect on the Company's
consolidated results of operations and financial position.
SFAS no. 145, "Rescission of FASB Statements SFAS 4, 44 and 64, Amendment of
FASB Statement No. 13 and Technical Corrections".
In April 2002, the FASB issued SFAS 145, "Rescission of FASB Statements SFAS 4,
44 and 64, Amendment of FASB Statement No. 13 and Technical Corrections". SFAS
145 rescinds Statement No. 4, "Reporting Gains and Losses from Extinguishments
of Debt", and an amendment of that Statement, FASB Statement No. 64,
"Extinguishments of Debt Made to Satisfy Sinking-Fund Requirements". SFAS 145
also rescinds FASB Statement No. 44, "Accounting for Intangible Assets of Motor
Carriers". SFAS 145 amends FASB Statement No. 13, "Accounting for Leases", to
eliminate an inconsistency between the required accounting for sale-leaseback
transactions and the required accounting for certain lease modifications that
have economic effects that are similar to sale leaseback transactions. SFAS 145
also amends other existing authoritative pronouncements to make various
technical corrections, clarify meanings, or describe their applicability under
changed conditions. The provision of SFAS 145 related to the rescission of
Statement No. 4 shall be applied in fiscal year beginning after May 15, 2002.
The provisions of SFAS 145 related to Statement No. 13 should be for
transactions occurring after May 15, 2002. Early application of the provisions
of this Statement is encouraged. The Company does not expect the adoption of
SFAS 145 will have a significant impact on its consolidated results of
operations, financial position or cash flows.
F-54
26. SUBSEQUENT EVENT
26.1 BNDES Funding
In accordance with the Brazilian Economic and Social
Development Bank's (BNDES) exceptional emergency support program for Electric
Energy Distributors, the Company secured a line of credit on February 19, 2002
in the amount of R$212,381 to cover a portion of a shortfall as part of the
extraordinary tariff recovery resulting from the Emergency Program for Reducing
Electric Energy Consumption.
Conditions of the obligation:
For the first installment:
a) Tenor: 12 months without grace period;
b) Maturity of the first tranche: March 2002;
c) Interest rate: SELIC plus 1% per annum;
d) Guarantee: Billing receivables for electric energy service;
e) Uses of funding:
o First tranche : R$63,823, was credited on February 2002;
o Remaining tranches: Will be withdrawn upon proof of payment of
outstanding debts with agents in the electric energy sector with
funds from the previous tranche, contingent upon validation and
approval of remaining amounts by ANEEL;
o Compliance with deadlines and commitments as defined by
GCE/ANEEL;
o Additional contract to match the amortization of the obligation
with the tariff recovery.
26.2 Special tariff situation
Through Bulletin no. 24 of 01/24/02, published by the Economic Regulatory
Commission and the Brazilian Electric Energy Regulatory Agency - ANEEL, the
Ministry of Mines and Energy approved the pass-through amounts for tariffs as
per paragraph IV of article no. 2 of Resolution no. 65 of 11/06/01 from the
Energy Crisis Management Chamber - GCE.
The pass-through amount, as received on March 1, 2002, is R$17,051 (R$24,972
Consolidated) corresponding to the period from July 2001 through December 2001,
and does not include costs incurred by the Electric Energy Distributors during
the Program.
* * * * * * * * * * *
F-55
SIGNATURES
The registrant hereby certifies that it meets all of the requirements
for filing on Form 20-F and that it has duly caused and authorized the
undersigned to sign this Annual Report on its behalf.
ESPIRITO SANTO CENTRAIS
ELETRICAS S.A.- ESCELSA
By: /s/SERGIO PEREIRA PIRES
--------------------------
Name: Sergio Pereira Pires
Title: Chief Financial Officer
Date: July 12, 2002