Filed Pursuant to Rule 424(b)(3)
Registration No. 333-108650
PROSPECTUS
EL PASO NATURAL GAS COMPANY
OFFER TO EXCHANGE
REGISTERED 7 5/8% SERIES B NOTES DUE 2010
FOR
ALL OUTSTANDING 7 5/8% SERIES A NOTES DUE 2010
($355,000,000 IN PRINCIPAL AMOUNT OUTSTANDING)
We are offering to exchange all of our outstanding 7 5/8% Series A Notes
due 2010 for our registered 7 5/8% Series B Notes due 2010. In this prospectus,
we will call the original Series A notes the "Old Notes" and the registered
Series B notes the "New Notes." The Old Notes and New Notes are collectively
referred to in this prospectus as the "notes."
THE EXCHANGE OFFER
- Expires 5:00 p.m., New York City time, October 17, 2003, unless extended.
- Subject to certain customary conditions, which we may waive, the exchange
offer is not conditioned upon a minimum aggregate principal amount of Old
Notes being tendered.
- All outstanding Old Notes validly tendered and not withdrawn will be
exchanged.
- The exchange offer is not subject to any condition other than that the
exchange offer not violate applicable law or any applicable
interpretation of the staff of the Securities and Exchange Commission.
THE NEW NOTES
- The terms of the New Notes to be issued in the exchange offer are
substantially identical to the Old Notes, except that we have registered
the New Notes with the Securities and Exchange Commission. In addition,
the New Notes will not be subject to certain transfer restrictions.
- Interest on the New Notes will accrue from July 21, 2003 at the rate of
7 5/8% per annum, payable semi-annually in arrears on each February 1 and
August 1, beginning February 1, 2004.
- The New Notes will not be listed on any securities exchange or the NASDAQ
Stock Market.
---------------------
YOU SHOULD CAREFULLY CONSIDER THE RISK FACTORS BEGINNING ON PAGE 10 OF THIS
PROSPECTUS BEFORE PARTICIPATING IN THE EXCHANGE OFFER.
---------------------
NEITHER THE SECURITIES AND EXCHANGE COMMISSION NOR ANY STATE SECURITIES
COMMISSION HAS APPROVED OR DISAPPROVED OF THESE SECURITIES OR DETERMINED IF THIS
PROSPECTUS IS TRUTHFUL OR COMPLETE. ANY REPRESENTATION TO THE CONTRARY IS A
CRIMINAL OFFENSE.
---------------------
Each broker-dealer that receives New Notes for its own account pursuant to
the Exchange Offer must acknowledge that it will deliver a prospectus in
connection with any resale of such New Notes. The letter of transmittal states
that by so acknowledging and by delivering a prospectus, a broker-dealer will
not be deemed to admit that it is an "underwriter" within the meaning of the
Securities Act. This prospectus, as it may be amended or supplemented from time
to time, may be used by a broker-dealer in connection with resales of New Notes
received in exchange for Old Notes where such Old Notes were acquired by such
broker-dealer as a result of market-making activities or other trading
activities. We have agreed that, for a period of 180 days after the Expiration
Date (as defined herein), we will make this prospectus available to any
broker-dealer for use in connection with any such resale. See "Plan of
Distribution."
---------------------
The date of this prospectus is September 18, 2003.
---------------------
TABLE OF CONTENTS
PAGE
----
Prospectus Summary.......................................... 1
Selected Financial Information.............................. 8
Ratio of Earnings to Fixed Charges.......................... 9
Risk Factors................................................ 10
Cautionary Statement Regarding Forward-Looking Statements... 17
Where You Can Find More Information......................... 18
Business.................................................... 20
Management's Discussion and Analysis of Financial Condition
and Results of Operations................................. 23
Quantitative and Qualitative Disclosures About Market
Risk...................................................... 31
Changes in and Disagreements with Accountants on Accounting
and Financial Disclosure.................................. 31
Use of Proceeds............................................. 32
Capitalization.............................................. 32
The Exchange Offer.......................................... 33
Description of the Notes.................................... 41
United States Federal Income Tax Consequences............... 59
ERISA Considerations........................................ 63
Global Securities; Book-Entry System........................ 65
Exchange Offer and Registration Rights...................... 68
Plan of Distribution........................................ 71
Legal Matters............................................... 72
Experts..................................................... 72
Index to Consolidated Financial Statements.................. F-1
------------------
UNTIL OCTOBER 28, 2003, ALL DEALERS THAT EFFECT TRANSACTIONS IN THESE
SECURITIES, WHETHER OR NOT PARTICIPATING IN THIS OFFERING, MAY BE REQUIRED TO
DELIVER A PROSPECTUS. THIS IS IN ADDITION TO THE DEALERS' OBLIGATION TO DELIVER
A PROSPECTUS WHEN ACTING AS UNDERWRITERS AND WITH RESPECT TO THEIR UNUSED
ALLOTMENTS OR SUBSCRIPTIONS.
THIS PROSPECTUS INCORPORATES IMPORTANT BUSINESS AND FINANCIAL INFORMATION
ABOUT EL PASO NATURAL GAS COMPANY THAT IS NOT INCLUDED IN OR DELIVERED WITH THIS
PROSPECTUS. DOCUMENTS INCORPORATED BY REFERENCE ARE AVAILABLE FROM US WITHOUT
CHARGE, EXCLUDING ANY EXHIBITS TO THOSE DOCUMENTS UNLESS THE EXHIBIT IS
SPECIFICALLY INCORPORATED BY REFERENCE AS AN EXHIBIT IN THIS DOCUMENT. YOU CAN
OBTAIN DOCUMENTS INCORPORATED BY REFERENCE INTO THIS PROSPECTUS BY REQUESTING
THEM IN WRITING OR BY TELEPHONE FROM US AT THE FOLLOWING ADDRESS:
EL PASO NATURAL GAS COMPANY
OFFICE OF INVESTOR RELATIONS
EL PASO BUILDING
1001 LOUISIANA STREET
HOUSTON, TEXAS 77002
TELEPHONE NO.: (713) 420-2600
TO OBTAIN TIMELY DELIVERY OF ANY REQUESTED DOCUMENTS, YOU MUST REQUEST THE
INFORMATION NO LATER THAN FIVE BUSINESS DAYS BEFORE YOU MAKE YOUR INVESTMENT
DECISION. PLEASE MAKE ANY SUCH REQUESTS ON OR BEFORE OCTOBER 9, 2003. SEE "WHERE
YOU CAN FIND MORE INFORMATION" FOR MORE INFORMATION ABOUT THESE MATTERS.
i
PROSPECTUS SUMMARY
This summary highlights some basic information appearing in other sections
of this prospectus. It is not complete and does not contain all the information
that you should consider before exchanging Old Notes for New Notes. You should
carefully read this prospectus and the documents incorporated by reference to
understand fully the terms of the exchange offer and the New Notes, as well as
the tax and other considerations that may be important to you. You should pay
special attention to the "Risk Factors" section beginning on page 10 of this
prospectus. You should rely only on the information contained in this document
or to which we have referred you. We have not authorized anyone to provide you
with information that is different. This document may only be used where it is
legal to sell these securities. The information in this document may only be
accurate on the date of this document. For purposes of this prospectus, unless
the context otherwise indicates, when we refer to "El Paso Natural Gas," "us,"
"we," "our," or "ours," we are describing El Paso Natural Gas Company, together
with its subsidiaries. References to "El Paso" mean El Paso Corporation.
Below is a list of terms that are common to our industry and used
throughout this document.
/d = per day Bcf = billion cubic feet
BBtu = billion British thermal units MMcf = million cubic feet
MMDth = million dekatherm
When we refer to cubic feet measurements, all measurements are at a
pressure of 14.73 pounds per square inch.
OUR BUSINESS
We are a Delaware corporation incorporated in 1928, and an indirect wholly
owned subsidiary of El Paso. Our primary business is the interstate
transportation of natural gas. We conduct our business activities through two
pipeline systems, each of which is discussed below.
The EPNG system. The El Paso Natural Gas system consists of approximately
10,600 miles of pipeline with a winter sustainable west-flow capacity of 4,530
MMcf/d and approximately 800 MMcf/d of east-end deliverability. The west-flow
capacity includes approximately 230 MMcf/d of capacity added in November 2002
related to the completion of our Line 2000 project which converted a pipeline
from oil transmission to natural gas transmission. This pipeline extends from
West Texas to the Arizona and California border. During 2002, 2001 and 2000,
average throughput on the EPNG system was 3,799 BBtu/d, 4,253 BBtu/d and 3,937
BBtu/d. This system delivers natural gas from the San Juan, Permian and Anadarko
Basins to California, which is our single largest market, as well as markets in
Arizona, Nevada, New Mexico, Oklahoma, Texas and northern Mexico.
The Mojave system. The Mojave Pipeline system consists of approximately
400 miles of pipeline with a design capacity of approximately 400 MMcf/d. During
2002, 2001 and 2000, average throughput on the Mojave system was 266 BBtu/d, 283
BBtu/d and 407 BBtu/d. This system connects with the EPNG and Transwestern
transmission systems at Topock, Arizona, the Kern River Gas Transmission Company
transmission system in California and extends to customers in the vicinity of
Bakersfield, California.
Our principal executive offices are in the El Paso Building, located at
1001 Louisiana Street, Houston, Texas 77002, and our telephone number at that
address is (713) 420-2600.
1
RECENT EVENTS
On August 26, 2003, we announced the purchase of Copper Eagle Gas Storage,
L.L.C. from APACS Holdings LLC and Arizona Gas Storage, L.L.C., an entity that
is partially owned by our affiliate, GulfTerra Energy Partners, L.P. The
purchase price was approximately $12 million, of which we paid $2.5 million in
cash and will pay the remaining amount in four equal quarterly installments
beginning on January 1, 2004. Copper Eagle Gas Storage is developing a natural
gas storage project located outside of Phoenix, Arizona. We also acquired
additional land for approximately $9 million that will allow for further
development of this project.
2
SUMMARY OF THE TERMS OF THE EXCHANGE OFFER
The Exchange Offer............ We are offering to exchange up to $355,000,000
of the New Notes for up to $355,000,000 of the
Old Notes. Old Notes may be exchanged only in
$1,000 increments.
The terms of the New Notes are identical in all
material respects to the Old Notes except that
the New Notes will not contain terms with
respect to transfer restrictions, registration
rights and payments of additional interest that
relate to the Old Notes. The New Notes and the
Old Notes will be governed by the same
indenture.
Registration Rights
Agreement..................... We sold the Old Notes on July 21, 2003 to
Citigroup Global Markets Inc., Credit Suisse
First Boston LLC, Banc of America Securities
LLC, Tokyo-Mitsubishi International plc and SG
Cowen Securities Corporation, the initial
purchasers, under a purchase agreement dated
July 16, 2003. Pursuant to the purchase
agreement, we and the initial purchasers
entered into a registration rights agreement
that granted the holders of the Old Notes
certain exchange and registration rights.
Specifically, we agreed to file, on or prior to
90 days after the closing of the offering of
the Old Notes, this exchange offer registration
statement with respect to a registered offer to
exchange the Old Notes for the New Notes. We
also agreed to use our commercial reasonable
efforts to have this exchange offer
registration statement declared effective by
the SEC within 210 days after the closing of
the offering of the Old Notes and to consummate
the exchange offer within 30 business days
thereafter. If we fail to fulfill our
obligations under the registration rights
agreement, additional interest will accrue on
the Old Notes at an annual rate of 0.25% for
the first 90 days and will increase by an
additional 0.25% for each subsequent 90-day
period up to a maximum additional annual rate
of 1.00%. See "Exchange Offer and Registration
Rights."
Resale........................ We believe that you will be able to freely
transfer the New Notes without registration or
any prospectus delivery requirement; however,
certain broker-dealers and certain of our
affiliates may be required to deliver copies of
this prospectus if they resell any New Notes.
Expiration Date............... 5:00 p.m., New York City time, on October 17,
2003, unless the exchange offer is extended.
You may withdraw Old Notes you tender pursuant
to the exchange offer at any time prior to
October 17, 2003. See "The Exchange
Offer -- Expiration Date; Extensions;
Termination; Amendments."
Conditions to the Exchange
Offer......................... The exchange offer is not subject to any
conditions other than that it does not violate
applicable law or any applicable interpretation
of the staff of the SEC.
Procedures for Tendering Old
Notes......................... If you wish to accept the exchange offer, sign
and date the letter of transmittal that was
delivered with this prospectus in accordance
with the instructions, and deliver the letter
of transmittal, along with the Old Notes and
any other required
3
documentation, to the exchange agent.
Alternatively, you can tender your outstanding
Old Notes by following the procedures for
book-entry transfer, as described in this
prospectus. By executing the letter of
transmittal or by transmitting an agent's
message in lieu thereof, you will represent to
us that, among other things:
- the New Notes you receive will be acquired in
the ordinary course of your business;
- you are not participating, and you have no
arrangement with any person to participate,
in the distribution of the New Notes;
- you are not our "affiliate," as defined in
Rule 405 under the Securities Act, or a
broker-dealer tendering Old Notes acquired
directly from us for resale pursuant to Rule
144A or any other available exemption under
the Securities Act; and
- if you are not a broker-dealer, that you are
not engaged in and do not intend to engage in
the distribution of the New Notes.
Effect of Not Tendering....... Old Notes that are not tendered or that are
tendered but not accepted will, following the
completion of the exchange offer, continue to
be subject to the existing restrictions upon
transfer thereof.
Special Procedures for
Beneficial Owners............. If you are a beneficial owner whose Old Notes
are registered in the name of a broker, dealer,
commercial bank, trust company or other nominee
and wish to tender such Old Notes in the
exchange offer, please contact the registered
holder as soon as possible and instruct them to
tender on your behalf and comply with our
instructions set forth elsewhere in this
prospectus.
Guaranteed Delivery
Procedures.................... If you wish to tender your Old Notes, you may,
in certain instances, do so according to the
guaranteed delivery procedures set forth
elsewhere in this prospectus under "The
Exchange Offer -- Procedures for Tendering Old
Notes -- Guaranteed Delivery."
Withdrawal Rights............. You may withdraw Old Notes that you tender
pursuant to the exchange offer by furnishing a
written or facsimile transmission notice of
withdrawal to the exchange agent containing the
information set forth in "The Exchange
Offer -- Withdrawal of Tenders" at any time
prior to the expiration date.
Acceptance of Old Notes and
Delivery of New Notes......... We will accept for exchange any and all Old
Notes that are properly tendered in the
exchange offer prior to the expiration date.
See "The Exchange Offer -- Procedures for
Tendering Old Notes." The New Notes issued
pursuant to the exchange offer will be
delivered promptly following the expiration
date.
Broker-Dealers................ Each broker-dealer that receives New Notes for
its own account pursuant to the Exchange Offer
must acknowledge that it will deliver a
prospectus in connection with any resale of
such New Notes. The letter of transmittal
states that by so
4
acknowledging and by delivering a prospectus, a
broker-dealer will not be deemed to admit that
it is an "underwriter" within the meaning of
the Securities Act. This prospectus, as it may
be amended or supplemented from time to time,
may be used by a broker-dealer in connection
with resales of New Notes received in exchange
for Old Notes where such Old Notes were
acquired by such broker-dealer as a result of
market-making activities or other trading
activities. We have agreed that, for a period
of 180 days after the Expiration Date (as
defined herein), we will make this prospectus
available to any broker-dealer for use in
connection with any such resale. See "Plan of
Distribution."
5
SUMMARY OF TERMS OF NEW NOTES
Issuer........................ El Paso Natural Gas Company
New Notes..................... $355,000,000 aggregate principal amount of
7 5/8% Series B Notes due 2010.
Maturity Date................. August 1, 2010.
Interest Rate................. 7 5/8% per annum, accruing from July 21, 2003.
Interest Payment Dates........ February 1 and August 1 of each year, beginning
February 1, 2004.
Optional Redemption........... We may redeem some or all of the New Notes, at
any time or from time to time, at the
redemption price described in the section
entitled "Description of the Notes -- Optional
Redemption of Notes."
Ranking....................... As of June 30, 2003, we had total capital
market debt of approximately $960 million. We
also had guarantees of approximately $11
million and letters of credit of approximately
$4 million. The New Notes will rank equally
with approximately $975 million of our debt,
guarantees and letters of credit.
We are a designated borrower under El Paso's $3
billion revolving credit facility, which
matures in June 2005. We are only liable for
the amounts we borrow under the $3 billion
facility. As of June 30, 2003, $1.5 billion was
outstanding and $1.1 billion in letters of
credit were issued under the $3 billion
facility, none of which was borrowed by or
issued on behalf of us.
Our direct subsidiary, Sabine River Investors
V, L.L.C. (Sabine), is one of 17 subsidiary
guarantors of El Paso's $3 billion facility. In
connection with its guarantee of the $3 billion
facility, Sabine pledged its equity interests
in each of EPNG Mojave, Inc. and El Paso Mojave
Pipeline Co. (Mojave Pipeline Company's
partners), to collateralize that facility. In
addition, in connection with its guarantee of
El Paso's $3 billion facility, our direct
parent El Paso EPNG Investments, L.L.C. pledged
its equity interest in us to collateralize that
facility. As a result, our ownership is subject
to a change in control if El Paso's lenders
under the $3 billion facility are required to
exercise rights over their collateral. El Paso
EPNG Investments' equity in us and Sabine's
equity interests in EPNG Mojave, Inc. and El
Paso Mojave Pipeline Co. also collateralize
approximately $1 billion of other financing
arrangements, including leases, letters of
credit and other facilities. At June 30, 2003,
the assets of Sabine represented approximately
$375 million, or 11%, of our total consolidated
assets and Sabine's operating income of
approximately $9 million was included in our
consolidated operating loss of $14 million for
the six months ended June 30, 2003.
In connection with the agreement in principle
by us and our affiliates to resolve the
principal litigation, claims and regulatory
6
proceedings against us and our affiliates
relating to the sale or delivery of natural gas
and/or electricity to or in the Western United
States (the Western Energy Settlement), as of
June 30, 2003, El Paso had incurred total
settlement obligations of approximately $1,045
million, of which approximately $400 million is
classified as long-term. Of this amount, we
have agreed to pay to the settling parties (i)
an aggregate cash payment of $343.5 million and
(ii) a separate cash payment in an amount equal
to the proceeds from the issuance by El Paso of
approximately 26.4 million shares of El Paso
common stock, such proceeds to be contributed
or advanced to us by El Paso. We have also
guaranteed the remaining balance of El Paso's
total settlement obligations. Therefore,
holders of the New Notes will rank equally with
the settling claimants to the extent of our
obligations under the Western Energy
Settlement.
Certain Covenants............. The indenture governing the New Notes contains
covenants, including covenants limiting, in
some cases, (1) the creation of liens securing
indebtedness, (2) sale-leaseback transactions,
(3) incurrence of debt, (4) mergers and asset
sales, (5) dividends and other restricted
payments, (6) our participation in El Paso's
cash management program and (7) transactions
with affiliates. The covenants referenced under
clauses (3), (5), (6) and (7) will be of no
force or effect from and after the time the
notes are first rated at least Baa3 by Moody's
and at least BBB- by Standard & Poor's.
Use of Proceeds............... We will not receive any proceeds from the
exchange of the New Notes for the outstanding
Old Notes.
Risk Factors.................. You should read the "Risk Factors" section
beginning on page 10, as well as the other
cautionary statements throughout this
prospectus, to ensure you understand the risks
involved with the exchange of the New Notes for
the outstanding Old Notes.
7
SELECTED FINANCIAL INFORMATION
The following selected financial information was obtained from and should
be read in conjunction with our consolidated financial statements and related
notes included in this prospectus beginning on page F-1. This historical
information is not necessarily indicative of the results to be expected in the
future.
SIX MONTHS
ENDED
JUNE 30, YEAR ENDED DECEMBER 31,
------------ ------------------------------------------
2003 2002 2002 2001 2000 1999 1998
----- ---- ------ ------ ------ ------ ------
(UNAUDITED)
(IN MILLIONS)
OPERATING RESULTS DATA:
Operating revenues................. $266 $296 $ 564 $ 572 $ 508 $ 501 $ 480
Depreciation, depletion and
amortization.................... 33 30 63 70 66 63 61
Operating income (loss)(1)......... (14) 164 (105) 186 223 214 213
Income (loss) before income
taxes........................... (45) 142 (154) 155 206 170 150
Income taxes....................... (17) 54 (55) 60 78 64 58
Net income (loss) from continuing
operations...................... (28) 88 (99) 95 128 106 92
AS OF AS OF DECEMBER 31,
JUNE 30, ------------------------------------------
2003 2002 2001 2000 1999 1998
----------- ------ ------ ------ ------ ------
(UNAUDITED)
(IN MILLIONS)
FINANCIAL POSITION DATA:
Total assets.......................... $3,355 $3,189 $3,344 $2,993 $3,100 $2,793
Short-term debt (including current
maturities of long-term debt)...... 200 200 654 280 567 268
Long-term debt, less current
maturities......................... 758 758 659 873 873 980
Western Energy Settlement
Current Portion.................... 556 100 -- -- -- --
Noncurrent Portion................. -- 312 -- -- -- --
Stockholder's equity.................. 1,128 1,153 1,298 1,227 1,126 1,044
---------------
(1) In March 2003, we entered into an agreement in principle to settle claims
associated with the western energy crisis from September 1996 to the date of
the proposed settlement. We accrued a charge of $412 million in December
2002 related to this settlement and an additional charge of $154 million
during the second quarter of 2003. In 2001, we incurred merger-related costs
of $98 million related to El Paso's merger with The Coastal Corporation. For
a further discussion of these matters, see our financial statements included
in this prospectus beginning on page F-1.
8
RATIO OF EARNINGS TO FIXED CHARGES
The following table presents the ratio of earnings to fixed charges for El
Paso Natural Gas and its consolidated subsidiaries for the periods indicated:
SIX MONTHS
ENDED
YEAR ENDED DECEMBER 31, JUNE 30,
------------------------------------ ------------
1998 1999 2000 2001 2002 2002 2003
---- ---- ---- ---- ---- ---- ----
Ratio of earnings to fixed charges....... 2.1x 2.5x 2.8x 2.5x --(1) 4.8x --(1)
------------------
(1) Earnings were inadequate to cover fixed charges by $160 million for the year
ended December 31, 2002 and $46 million for the six months ended June 30,
2003.
For the purposes of computing these ratios, earnings means income (loss)
from continuing operations before income taxes and fixed charges, less
capitalized interest. Fixed charges means the sum of the following:
- interest costs, not including interest on rate refunds;
- amortization of debt costs; and
- that portion of rental expense which we believe represents an interest
factor.
9
RISK FACTORS
Before you decide to participate in the exchange offer, you should read the
following risks, uncertainties and factors that may adversely affect us.
RISKS RELATED TO OUR BUSINESS
OUR SUCCESS DEPENDS ON FACTORS BEYOND OUR CONTROL.
Our business is the transportation of natural gas for third parties. As a
result, the volume of natural gas involved in these activities depends on the
actions of those third parties, and is beyond our control. Further, the
following factors, most of which are beyond our control, may unfavorably impact
our ability to maintain or increase current transmission volumes and rates, to
renegotiate existing contracts as they expire, or to remarket unsubscribed
capacity:
- future weather conditions, including those that favor alternative energy
sources;
- price competition;
- drilling activity and supply availability;
- expiration and/or turn back of significant contracts;
- service area competition;
- changes in regulation and actions of regulatory bodies;
- credit risk of customer base;
- increased cost of capital; and
- natural gas and liquids prices.
THE REVENUES OF OUR PIPELINE BUSINESSES ARE GENERATED UNDER CONTRACTS THAT MUST
BE RENEGOTIATED PERIODICALLY.
Our revenues are generated under transportation contracts which expire
periodically and must be renegotiated and extended or replaced. We cannot assure
that we will be able to extend or replace our contracts when they expire or that
the terms of any renegotiated contracts will be as favorable as the existing
contracts. For a further discussion of these matters, see "Business -- Markets
and Competition" beginning on page 21 and Note 5 to the Condensed Consolidated
Financial Statements beginning on page F-34.
In particular, our ability to extend and/or replace transportation
contracts could be adversely affected by factors we cannot control, including:
- the proposed construction by other companies of additional pipeline
capacity in markets served by us;
- changes in state regulation of local distribution companies, which may
cause them to negotiate short-term contracts or turn back their capacity
when their contracts expire;
- reduced demand and market conditions;
- the availability of alternative energy sources or gas supply points;
- obligations in connection with the settlement of litigation; and
- regulatory actions.
If we are unable to renew, extend or replace these contracts or if we renew
them on less favorable terms, we may suffer a material reduction in our revenues
and earnings.
10
WE FACE COMPETITION THAT COULD ADVERSELY AFFECT OUR OPERATING RESULTS.
Our competitors include other pipeline companies, as well as participants
in other industries supplying and transporting alternative fuels. If we are
unable to compete effectively, our future profitability may be negatively
impacted.
FLUCTUATIONS IN ENERGY COMMODITY PRICES COULD ADVERSELY AFFECT OUR BUSINESS.
Revenues generated by our contracts depend on volumes and rates, both of
which can be affected by the prices of natural gas. Increased natural gas prices
could result in loss of load from our customers, such as power companies not
dispatching gas fired power plants, industrial plant shutdown or load loss to
competitive fuels and local distribution companies' loss of customer base due to
conversion from natural gas. The success of our operations is subject to
continued development of additional oil and natural gas reserves in the vicinity
of our facilities and our ability to access additional suppliers from
interconnecting pipelines to offset the natural decline from existing wells
connected to our systems. A decline in energy prices could precipitate a
decrease in these development activities and could cause a decrease in the
volume of reserves available for transmission on our system. Fluctuations in
energy prices are caused by a number of factors, including:
- regional, domestic and international supply and demand;
- availability and adequacy of transportation facilities;
- energy legislation;
- federal and state taxes, if any, on the transportation of natural gas;
- abundance of supplies of alternative energy sources; and
- political unrest among oil-producing countries.
THE AGENCIES THAT REGULATE US AND OUR CUSTOMERS AFFECT OUR PROFITABILITY.
Our pipeline businesses are regulated by the Federal Energy Regulatory
Commission (FERC), the U.S. Department of Transportation, and various state and
local regulatory agencies. Regulatory actions taken by those agencies have the
potential to adversely affect our profitability. In particular, the FERC
regulates the rates we are permitted to charge our customers for our services.
If our tariff rates were reduced in a future rate proceeding, if our volume of
business under our currently permitted rates was decreased significantly or if
we were required to substantially discount the rates for our services because of
competition, our profitability could be reduced and our ability to repay the
notes could be affected adversely.
Further, state agencies that regulate our local distribution company
customers could impose requirements that could impact demand for our services.
COSTS OF ENVIRONMENTAL LIABILITIES, REGULATIONS AND LITIGATION COULD EXCEED OUR
ESTIMATES.
Our operations are subject to various environmental laws and regulations.
These laws and regulations obligate us to install and maintain pollution
controls and to clean up various sites at which regulated materials may have
been disposed of or released. We are also party to legal proceedings involving
environmental matters pending in various courts and agencies.
It is not possible for us to estimate reliably the amount and timing of all
future expenditures related to environmental matters because of:
- the uncertainties in estimating clean up costs;
- the discovery of new sites or information;
- the uncertainty in quantifying liability under environmental laws that
impose joint and several liability on all potentially responsible
parties;
- the nature of environmental laws and regulations; and
- the possible introduction of future environmental laws and regulations.
11
Although we believe we have established appropriate reserves for
liabilities, including clean up costs, we could be required to set aside
additional reserves in the future due to these uncertainties. For additional
information, see Note 5 to the Condensed Consolidated Financial Statements
beginning on page F-34.
OUR OPERATIONS ARE SUBJECT TO OPERATIONAL HAZARDS AND UNINSURED RISKS.
Our operations are subject to the inherent risks normally associated with
those operations, including pipeline ruptures, explosions, pollution, release of
toxic substances, fires and adverse weather conditions, and other hazards, each
of which could result in damage to or destruction of our facilities or damages
to persons and property. In addition, our operations face possible risks
associated with acts of aggression on our assets. If any of these events were to
occur, we could suffer substantial losses.
While we maintain insurance against many of these risks, our financial
condition and operations could be adversely affected if a significant event
occurs that is not fully covered by insurance.
ONE CUSTOMER CONTRACTS FOR A SUBSTANTIAL PORTION OF OUR FIRM TRANSPORTATION
CAPACITY.
For 2002, contracts with Southern California Gas Company were substantial.
For additional information on our relationship with Southern California Gas
Company, see "Business -- Markets and Competition" beginning on page 21 and Note
12 to the Consolidated Financial Statements beginning on page F-27. The loss of
this customer or a decline in its credit-worthiness could adversely affect our
results of operations, financial position and cash flow.
TERRORIST ATTACKS AIMED AT OUR FACILITIES COULD ADVERSELY AFFECT OUR BUSINESS.
On September 11, 2001, the U.S. was the target of terrorist attacks of
unprecedented scale. Since the September 11th attacks, the U.S. government has
issued warnings that energy assets, including our nation's pipeline
infrastructure, may be a future target of terrorist organizations. These
developments have subjected our operations to increased risks. Any future
terrorist attack on our facilities, those of our customers and, in some cases,
those of other pipelines, could have a material adverse effect on our business.
RISKS RELATED TO OUR AFFILIATION WITH EL PASO
El Paso files reports, proxy statements and other information with the SEC
under the Securities Exchange Act of 1934, as amended. Each prospective investor
should consider this information and the matters disclosed therein in addition
to the matters described in this report. Such information is not incorporated by
reference herein.
OUR RELATIONSHIP WITH EL PASO AND ITS FINANCIAL CONDITION SUBJECTS US TO
POTENTIAL RISKS THAT ARE BEYOND OUR CONTROL.
Due to our relationship with El Paso, adverse developments or announcements
concerning El Paso could adversely affect our financial condition, even if we
have not suffered any similar development. The outstanding senior unsecured
indebtedness of El Paso has been downgraded to below investment grade, currently
rated Caa1 by Moody's and B by Standard & Poor's (with a developing outlook by
Moody's and a negative outlook by Standard & Poor's), which in turn resulted in
a similar downgrading of our outstanding senior unsecured indebtedness to B1 by
Moody's and B+ by Standard & Poor's (with a developing outlook by Moody's and a
negative outlook by Standard & Poor's). These downgrades increased our cost of
capital and collateral requirements, and could impede our access to capital
markets. As a result of these downgrades, El Paso realized substantial demands
on its liquidity. These downgrades may subject El Paso to additional liquidity
demands in the future. These downgrades are a result, at least in part, of the
outlook generally for the consolidated businesses of El Paso and its needs for
liquidity.
In order to meet its short term liquidity needs, El Paso embarked on its
2003 Operational and Financial Plan. Pursuant to the plan, El Paso has
substantially reduced its capital expenditures for 2003,
12
announced, signed purchase and sale agreements for or closed approximately $2.6
billion in asset sales, retired and/or restructured two of its financing
vehicles, entered into a new $3 billion revolving credit facility, resolved
significant litigation and regulatory matters, and achieved cost reductions for
2003. To fully achieve the plan's objectives, El Paso must complete an
additional $0.8 billion in non-core asset sales during 2003 and continue to
recover substantial amounts of the cash collateral committed to its trading,
petroleum and other businesses. There can be no assurance that the remaining
actions contemplated under the plan will be consummated on favorable terms, if
at all, or even if consummated, that such remaining actions will be successful
in satisfying El Paso's liquidity needs. In the event that El Paso's liquidity
needs are not satisfied, El Paso could be forced to seek protection from its
creditors in bankruptcy. Such a development could materially adversely affect
our financial condition.
Pursuant to El Paso's cash management program, surplus cash is made
available to El Paso in exchange for an affiliated receivable. Until the escrow
account is established by the settling parties in the Western Energy Settlement,
we intend to maintain the net proceeds from this offering for working capital
purposes; however, we are not contractually prohibited from including these
proceeds in El Paso's cash management program. If the Western Energy Settlement
is not approved, or if the escrow account to be established by the settling
parties is not so established, the net proceeds from this offering will be used
for our other working capital and general corporate purposes.
In addition, we conduct commercial transactions with some of our
affiliates. As of June 30, 2003, we have receivables of approximately $1,049
million from El Paso and its affiliates and payables of approximately $20
million to El Paso and its affiliates. El Paso provides cash management and
other corporate services for us. If El Paso is unable to meet its liquidity
needs, there can be no assurance that we will be able to access cash under the
cash management program, or that our affiliates would pay their obligations to
us. However, we might still be required to satisfy affiliated company payables.
Our inability to recover any intercompany receivables owed to us could adversely
affect our ability to repay our outstanding indebtedness. For a further
discussion of our related party transactions, see Note 11 to the Consolidated
Financial Statements beginning on page F-26 and Note 6 to the Condensed
Consolidated Financial Statements beginning on page F-43.
OUR EQUITY INTERESTS AND THE EQUITY INTERESTS OF TWO OF OUR INDIRECT
SUBSIDIARIES ARE PLEDGED AS COLLATERAL UNDER EL PASO'S $3 BILLION REVOLVING
CREDIT FACILITY AND APPROXIMATELY $1 BILLION OF OTHER EL PASO FINANCING
ARRANGEMENTS.
We are a designated borrower under El Paso's $3 billion revolving credit
facility, which matures in June 2005. We are only liable for the amounts we
borrow under the $3 billion facility. As of June 30, 2003, $1.5 billion was
outstanding and $1.1 billion in letters of credit were issued under the $3
billion facility, none of which was borrowed by or issued on behalf of us.
Our direct subsidiary, Sabine, is one of 17 subsidiary guarantors of El
Paso's $3 billion facility. In connection with its guarantee of this facility,
Sabine pledged its equity interests in each of EPNG Mojave, Inc. and El Paso
Mojave Pipeline Co., its sole assets, to collateralize that facility. In
addition, in connection with its guarantee of El Paso's $3 billion facility, our
direct parent El Paso EPNG Investments, L.L.C. pledged its equity interests in
us to collateralize that facility. As a result, our ownership is subject to a
change in control if El Paso's lenders under the $3 billion facility are
required to exercise rights over their collateral. El Paso EPNG Investments'
equity in us and Sabine's equity interest in EPNG Mojave, Inc. and El Paso
Mojave Pipeline Co. also collateralize approximately $1 billion of other
financing arrangements, including leases, letters of credit and other
facilities.
WE ARE JOINTLY AND SEVERALLY LIABLE FOR EL PASO'S AND EL PASO MERCHANT ENERGY'S
OBLIGATIONS IN CONNECTION WITH THE WESTERN ENERGY SETTLEMENT.
We have guaranteed the payment of certain obligations of El Paso and El
Paso Merchant Energy in connection with the Western Energy Settlement in the
event that they fail to pay these amounts or if pledged collateral does not
otherwise satisfy these obligations. If, for any reason, either El Paso or El
Paso Merchant Energy does not pay any of these obligations, or if pledged
collateral does not otherwise satisfy
13
these obligations, and we are required to pay such amounts, our financial
condition and liquidity could be materially adversely affected.
WE COULD BE SUBSTANTIVELY CONSOLIDATED WITH EL PASO IF EL PASO WERE FORCED TO
SEEK PROTECTION FROM ITS CREDITORS IN BANKRUPTCY.
If El Paso were the subject of voluntary or involuntary bankruptcy
proceedings, El Paso and its other subsidiaries and their creditors could
attempt to make claims against us, including claims to substantively consolidate
our assets and liabilities with those of El Paso and its other subsidiaries. The
equitable doctrine of substantive consolidation permits a bankruptcy court to
disregard the separateness of related entities and to consolidate and pool the
entities' assets and liabilities and treat them as though held and incurred by
one entity where the interrelationship between the entities warrants such
consolidation. We believe that any effort to substantively consolidate us with
El Paso and/or its other subsidiaries would be without merit. We would
aggressively defend against any attempt to substantively consolidate us with El
Paso and/or its other subsidiaries. However, we cannot assure you that El Paso
and/or its other subsidiaries or their respective creditors would not attempt to
advance such claims in a bankruptcy proceeding or, if advanced, how a bankruptcy
court would resolve the issue. If a bankruptcy court were to substantively
consolidate us with El Paso and/or its other subsidiaries, there could be a
material adverse effect on our financial condition and liquidity and thus on our
ability to make payments on the notes.
ONGOING LITIGATION AND INVESTIGATIONS REGARDING US AND EL PASO COULD
SIGNIFICANTLY ADVERSELY AFFECT OUR BUSINESS.
On March 20, 2003, we and our affiliates entered into an agreement in
principle (the Western Energy Settlement) to resolve the principal litigation,
claims, and regulatory proceedings against us and our affiliates relating to the
sale or delivery of natural gas and/or electricity to or in the Western United
States. On June 26, 2003, El Paso entered into two definitive settlement
agreements with various public and private claimants, including the states of
California, Washington, Oregon and Nevada, to resolve this litigation. For
further information on these matters, see Notes 2 and 8 to the Consolidated
Financial Statements beginning on pages F-10 and F-15, and Notes 2 and 5 to the
Condensed Consolidated Financial Statements beginning on pages F-32 and F-34.
The definitive settlement agreements are subject to approval by the California
Superior Court for San Diego County and the structural settlement is subject to
approval by the FERC. We currently expect final approval of these settlement
agreements in late 2003 or early 2004. If the settlement is not approved by the
court or the FERC, the proceedings and litigation will continue. We cannot
assure you that the results of any such continued proceedings and litigation
would be on terms as favorable as those of the current settlement agreements.
Since July 2002, twelve purported shareholder class action suits alleging
violations of federal securities laws have been filed against El Paso and
several of its officers. Eleven of these suits are now consolidated in federal
court in Houston before a single judge. The suits generally challenge the
accuracy or completeness of press releases and other public statements made
during 2001 and 2002. The twelfth shareholder class action lawsuit was filed in
federal court in New York City in October 2002 challenging the accuracy or
completeness of El Paso's February 27, 2002 prospectus for an equity offering
that was completed on June 21, 2002. It has since been dismissed, in light of
similar claims being asserted in the consolidated suits in Houston. Four
shareholder derivative actions have also been filed. One shareholder derivative
lawsuit was filed in federal court in Houston in August 2002. This derivative
action generally alleges the same claims as those made in the shareholder class
action, has been consolidated with the shareholder class actions pending in
Houston and has been stayed. A second shareholder derivative lawsuit was filed
in Delaware State Court in October 2002 and generally alleges the same claims as
those made in the consolidated shareholder class action lawsuit. A third
shareholder derivative suit was filed in state court in Houston in March 2002,
and a fourth shareholder derivative suit was filed in state court in Houston in
November 2002. The third and fourth shareholder derivative suits both generally
allege that manipulation of California gas supply and gas prices exposed El Paso
to claims of antitrust conspiracy, FERC penalties
14
and erosion of share value. At this time, El Paso's legal exposure related to
these lawsuits and claims is not determinable.
Another action was filed against El Paso in December 2002, on behalf of
participants in El Paso's 401(k) plan.
If we and El Paso do not prevail in these cases (or any of the other
litigation, administrative or regulatory matters disclosed in El Paso's Form
10-Q for the quarter ended June 30, 2003 to which El Paso, is or may be, a
party), and if the remedy adopted in these cases substantially impairs our and
El Paso's financial position, the long-term adverse impact on our and El Paso's
credit rating, liquidity and our ability to raise capital to meet ongoing and
future investing and financing needs could be substantial.
WE ARE AN INDIRECT WHOLLY OWNED SUBSIDIARY OF EL PASO.
El Paso has substantial control over:
- our payment of dividends;
- decisions on our financings and our capital raising activities;
- mergers or other business combinations;
- our acquisitions or dispositions of assets; and
- our participation in El Paso's cash management program.
El Paso may exercise such control in its interests and not necessarily in
the interests of us or the holders of our long-term debt.
RISKS RELATED TO OUR DEBT
OUR SUBSTANTIAL LONG-TERM DEBT AND OTHER OBLIGATIONS COULD IMPAIR OUR FINANCIAL
CONDITION AND OUR ABILITY TO SATISFY THESE OBLIGATIONS.
We have substantial long-term debt. As of June 30, 2003, we had total
capital market debt of approximately $960 million, all of which was senior
unsecured long-term indebtedness. We also had obligations of $556 million
related to the Western Energy settlement.
We are a designated borrower under El Paso's $3 billion revolving credit
facility, which matures in June 2005. We are only liable for the amounts we
borrow under the $3 billion facility. As of June 30, 2003, $1.5 billion was
outstanding and $1.1 billion in letters of credit were issued under the $3
billion facility, none of which was borrowed by or issued on behalf of us.
Our direct subsidiary, Sabine, is one of 17 subsidiary guarantors of El
Paso's $3 billion facility. In connection with its guarantee of this facility,
Sabine pledged its equity interests in each of EPNG Mojave, Inc. and El Paso
Mojave Pipeline Co., its sole assets, to collateralize that facility. In
addition, in connection with its guarantee of El Paso's $3 billion facility, our
direct parent El Paso EPNG Investments, L.L.C. pledged its equity interests in
us to collateralize that facility. As a result, our ownership is subject to a
change in control if El Paso's lenders under the $3 billion facility are
required to exercise rights over their collateral. El Paso EPNG Investments'
equity in us and Sabine's equity interests in EPNG Mojave, Inc. and El Paso
Mojave Pipeline Co. also collateralize approximately $1 billion of other
financing arrangements, including leases, letters of credit and other
facilities.
In connection with the Western Energy Settlement, El Paso has incurred
total settlement obligations of approximately $1,045 million, of which
approximately $400 million is classified as long-term. Of this amount, we have
agreed to pay to the settling parties (i) an aggregate cash payment of $343.5
million and (ii) a separate cash payment in an amount equal to the proceeds from
the issuance by El Paso of approximately 26.4 million shares of El Paso common
stock, such proceeds to be contributed or advanced to us by El Paso. We have
also guaranteed the remaining balance of El Paso's total settlement obligations.
15
Therefore, holders of the New Notes will rank equally with the settling
claimants to the extent of our obligations under the Western Energy Settlement.
Our substantial long-term debt and other obligations could have important
consequences. For example, it could:
- make it more difficult for us to satisfy our obligations with respect to
our long-term debt, which could in turn result in an event of default on
any or all of such long-term debt;
- impair our ability to obtain additional financing in the future for
working capital, capital expenditures, acquisitions, general corporate
purposes or other purposes;
- diminish our ability to withstand a downturn in our business or the
economy generally;
- require us to dedicate a substantial portion of our cash flow from
operations to debt service payments, thereby reducing the availability of
cash for working capital, capital expenditures, acquisitions, general
corporate purposes or other purposes;
- limit our flexibility in planning for, or reacting to, changes in our
business and the industry in which we operate; and
- place us at a competitive disadvantage compared to our competitors that
have proportionately less debt.
If we are unable to meet our debt service obligations or satisfy our
guarantees, we could be forced to restructure or refinance our long-term debt,
seek additional equity capital or sell assets. We may be unable to obtain
financing or sell assets on satisfactory terms, or at all.
Covenants applicable to our long-term debt allow us to incur significant
amounts of additional indebtedness. Our incurrence of significant additional
indebtedness would exacerbate the negative consequences mentioned above, and
could adversely affect our ability to repay our long-term debt.
SOME OF OUR LONG-TERM DEBT IS SUBJECT TO CROSS-ACCELERATION PROVISIONS.
It is an event of default in the indenture governing one issue of our
long-term debt if we default in compliance with the terms of any of our other
indebtedness with an outstanding principal amount that exceeds $25 million, and
the default results in the acceleration of such indebtedness. If this were to
occur, this issue of long-term debt would be subject to possible acceleration,
and we may not be able to repay such long-term debt upon such acceleration.
16
CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS
We have made statements in this document and the documents that are
incorporated by reference into this document that constitute forward-looking
statements, as that term is defined in the Private Securities Litigation Reform
Act of 1995. These statements are subject to risks and uncertainties.
Forward-looking statements include information concerning our possible or
assumed future results of operations. These statements may relate to, but are
not limited to, information or assumptions about earnings per share, capital and
other expenditures, dividends, financing plans, capital structure, cash flow,
pending legal and regulatory proceedings and claims, including environmental
matters, future economic performance, operating income, cost savings,
management's plans, goals and objectives for future operations and growth and
markets for our stock. These forward-looking statements generally are
accompanied by words such as "intend," "anticipate," "believe," "estimate,"
"expect," "should" or similar expressions. You should understand that these
forward-looking statements are estimates that reflect the best judgment of our
senior management and are not guarantees of future performance. They are subject
to a number of assumptions, risks and uncertainties that could cause actual
results to differ materially from those expressed or implied in the
forward-looking statements.
For a description of certain risks relating to us and our business, see
"Risk Factors" beginning on page 10 of this document and "Management's
Discussion and Analysis of Financial Condition and Results of Operations"
beginning on page 23 of this document. In addition, we can give you no assurance
that:
- we have correctly identified and assessed all of the factors affecting
our businesses;
- the publicly available and other information with respect to these
factors on which we have based our analysis is complete or correct;
- our analysis is correct; or
- our strategies, which are based in part on this analysis, will be
successful.
Accordingly, you should not place undue reliance on forward-looking
statements, which speak only as of the date of this document, or, in the case of
documents incorporated by reference, the date of those documents.
All subsequent written and oral forward-looking statements attributable to
us or any person acting on our behalf are expressly qualified in their entirety
by the cautionary statements contained or referred to in this section and any
other cautionary statements that may accompany such forward-looking statements.
We do not undertake any obligation to release publicly any revisions to these
forward-looking statements to reflect events or circumstances after the date of
this document or to reflect the occurrence of unanticipated events, unless the
securities laws require us to do so.
17
WHERE YOU CAN FIND MORE INFORMATION
We have filed a registration statement with the SEC under the Securities
Act of 1933 that registers the securities offered by this prospectus. The
registration statement, including the attached exhibits, contains additional
relevant information about us. The rules and regulations of the SEC allow us to
omit some information included in the registration statement from this
prospectus.
In addition, we file reports, proxy statements and other information with
the SEC under the Securities Exchange Act of 1934. You may read and copy this
information at the SEC's public reference room, Room 1024, 450 Fifth Street,
N.W., Washington, D.C. 20549. Please call the SEC at 1-800-SEC-0330 for further
information on the public reference rooms. The SEC also maintains an Internet
world wide web site that contains reports, proxy statements and other
information about issuers, including El Paso Natural Gas, who file
electronically with the SEC. The address of that site is http://www.sec.gov.
We "incorporate by reference" information into this prospectus, which means
that we disclose important information to you by referring you to another
document filed separately with the SEC. This important information is not
included in or delivered with this prospectus. The information incorporated by
reference is deemed to be part of this prospectus, except for any information
superseded by information contained directly in this prospectus. The documents
listed below and incorporated by reference into this prospectus contain
important information about El Paso Natural Gas and its financial condition.
- Annual Report on Form 10-K and Amendment No. 1 on Form 10-K/A for the
year ended December 31, 2002;
- Quarterly Report on Form 10-Q and Amendment No. 1 on Form 10-Q/A for
the quarter ended March 31, 2003 and Quarterly Report on Form 10-Q for
the quarter ended June 30, 2003; and
- Current Reports on Form 8-K filed March 21, 2003, April 18, 2003,
April 23, 2003, June 5, 2003, July 9, 2003, July 24, 2003 and
September 8, 2003.
We also disclose information about us through current reports on Form 8-K
that are furnished to the SEC to comply with Regulation FD. This information
disclosed in these reports is not considered to be "filed" for purposes of
Section 18 of the Securities Exchange Act of 1934, is not subject to the
liabilities of that section and is not incorporated by reference herein.
All documents filed by us with the SEC from the date of this prospectus to
the end of the offering of the notes under this prospectus shall also be deemed
to be incorporated herein by reference.
You can obtain any of the documents listed above or any additional
documents that we may file with the SEC, including Annual Reports on Form 10-K,
Quarterly Reports on Form 10-Q and Current Reports on Form 8-K, as well as proxy
statements, through us or from the SEC through the SEC's web site at the address
provided above. Documents incorporated by reference are available from us
without charge, excluding any exhibits to those documents unless the exhibit is
specifically incorporated by reference as an exhibit in this document. You can
obtain documents incorporated by reference into this prospectus by requesting
them in writing or by telephone from us at the following address:
El Paso Natural Gas Company
Office of Investor Relations
El Paso Building
1001 Louisiana Street
Houston, Texas 77002
Telephone No.: (713) 420-2600
TO OBTAIN TIMELY DELIVERY OF ANY REQUESTED DOCUMENTS, YOU MUST REQUEST THE
INFORMATION NO LATER THAN FIVE BUSINESS DAYS BEFORE YOU MAKE YOUR INVESTMENT
DECISION. PLEASE MAKE ANY SUCH REQUESTS ON OR BEFORE OCTOBER 9, 2003.
18
WE HAVE NOT AUTHORIZED ANYONE TO GIVE ANY INFORMATION OR MAKE ANY
REPRESENTATION THAT DIFFERS FROM, OR ADDS TO, THE INFORMATION IN THIS DOCUMENT
OR IN OUR DOCUMENTS THAT ARE PUBLICLY FILED WITH THE SEC. THEREFORE, IF ANYONE
DOES GIVE YOU DIFFERENT OR ADDITIONAL INFORMATION, YOU SHOULD NOT RELY ON IT.
IF YOU ARE IN A JURISDICTION WHERE IT IS UNLAWFUL TO OFFER TO EXCHANGE OR
SELL, OR TO ASK FOR OFFERS TO EXCHANGE OR BUY, THE SECURITIES OFFERED BY THIS
DOCUMENT, OR IF YOU ARE A PERSON TO WHOM IT IS UNLAWFUL TO DIRECT THESE
ACTIVITIES, THEN THE OFFER PRESENTED BY THIS DOCUMENT DOES NOT EXTEND TO YOU.
THE INFORMATION CONTAINED IN THIS DOCUMENT SPEAKS ONLY AS OF ITS DATE
UNLESS THE INFORMATION SPECIFICALLY INDICATES THAT ANOTHER DATE APPLIES.
19
BUSINESS
GENERAL
We are a Delaware corporation incorporated in 1928, and an indirect wholly
owned subsidiary of El Paso. Our primary business is the interstate
transportation of natural gas. We conduct our business activities through two
pipeline systems, each of which is discussed below.
The EPNG system. The El Paso Natural Gas system consists of approximately
10,600 miles of pipeline with a winter sustainable west-flow capacity of 4,530
MMcf/d and approximately 800 MMcf/d of east-end deliverability. The west-flow
capacity includes approximately 230 MMcf/d of capacity added in November 2002
related to the completion of our Line 2000 project which converted a pipeline
from oil transmission to natural gas transmission. This pipeline extends from
West Texas to the Arizona and California border. During 2002, 2001 and 2000,
average throughput on the EPNG system was 3,799 BBtu/d, 4,253 BBtu/d and 3,937
BBtu/d. This system delivers natural gas from the San Juan, Permian and Anadarko
Basins to California, which is our single largest market, as well as markets in
Arizona, Nevada, New Mexico, Oklahoma, Texas and northern Mexico.
The Mojave system. The Mojave Pipeline system consists of approximately
400 miles of pipeline with a design capacity of approximately 400 MMcf/d. During
2002, 2001 and 2000, average throughput on the Mojave system was 266 BBtu/d, 283
BBtu/d and 407 BBtu/d. This system connects with the EPNG and Transwestern
transmission systems at Topock, Arizona, the Kern River Gas Transmission Company
transmission system in California and extends to customers in the vicinity of
Bakersfield, California.
REGULATORY ENVIRONMENT
Our interstate natural gas transmission systems are regulated by the FERC
under the Natural Gas Act of 1938 and the Natural Gas Policy Act of 1978. Our
systems operate under FERC-approved tariffs that establish rates and terms and
conditions for service to our customers. Generally, the FERC's authority extends
to:
- rates and charges for natural gas transportation;
- certification and construction of new facilities;
- extension or abandonment of facilities;
- maintenance of accounts and records;
- relationships between pipeline and marketing affiliates;
- terms and conditions of services;
- depreciation and amortization policies;
- acquisition and disposition of facilities; and
- initiation and discontinuation of services.
The fees or rates established under our tariffs are a function of our costs
of providing service to our customers, including a reasonable return on our
invested capital. Approximately 94 percent of our transportation services
revenue is attributable to a capacity reservation, or demand charge, paid by
firm customers. These firm shippers are obligated to pay a monthly demand
charge, regardless of the amount of natural gas they transport, for the term of
their contracts. The remaining 6 percent of our transportation services revenue
is attributable to charges based solely on the volumes of gas actually
transported on our pipeline systems. Consequently, our financial results have
historically been relatively stable; however, they can be subject to volatility
due to factors such as weather, changes in natural gas prices and market
conditions, regulatory actions, competition and the credit-worthiness of our
customers.
20
Our interstate pipeline systems are also subject to federal, state and
local pipeline safety and environmental statutes and regulations. We have
continuing programs designed to keep all of our facilities in compliance with
pipeline safety and environmental requirements. We believe that our systems are
in material compliance with the applicable requirements.
A discussion of significant rate and regulatory matters is included in Note
5 to the Condensed Consolidated Financial Statements beginning on page F-34.
MARKETS AND COMPETITION
We have firm and interruptible customers, including distribution and
industrial companies, electric generation companies, natural gas producers,
other natural gas pipelines and natural gas marketing and trading companies. We
provide transportation services in both our natural gas supply and market areas.
Our pipeline systems connect with multiple pipelines that provide our shippers
with access to diverse sources of supply and various natural gas markets served
by these pipelines. The following table details our markets and competition on
each of our interstate pipeline systems.
PIPELINE
SYSTEM CUSTOMER INFORMATION CONTRACT INFORMATION COMPETITION
----------- ---------------------------- ------------------------------- -----------------------------------
EPNG Approximately 230 firm Approximately 180 firm EPNG faces competition from other
and interruptible transportation contracts pipelines as well as alternative
transportation Contracted capacity:(1) energy sources that generate
customers Weighted average remaining electricity such as hydroelectric
contract term: power, nuclear, coal and fuel oil.
approximately 5 years
Major Customer:
Southern California Gas
Company
(1,235 BBtu/d) Contract term expires in 2006.
(95 BBtu/d) Contract terms expiring
2004-2007.
Mojave Approximately 35 firm Eight firm contracts Mojave faces competition from other
and interruptible Contracted capacity: 98% pipelines as well as alternative
transportation Weighted average remaining energy sources that generate
customers contract term: electricity such as hydroelectric
approximately 4 years power, nuclear, coal and fuel oil.
Major Customers:
Texaco Natural Gas Inc.
(185 BBtu/d) Contract term expires in 2007.
Burlington Resources
Trading Inc.
(76 BBtu/d) Contract term expires in 2007.
Los Angeles Department of
Water and Power
(50 BBtu/d) Contract term expires in 2007.
---------------
(1) A discussion of significant rate and regulatory matters regarding our
capacity is included in Note 5 to the Condensed Consolidated Financial
Statements beginning on page F-34.
In 2002, the combined capacity of all pipeline companies serving the
California market was approximately 7.4 Bcf/d and we provided approximately 44
percent of this capacity. In 2002, the demand for interstate pipeline capacity
to California averaged 5.0 Bcf/d, equivalent to approximately 68 percent of the
total interstate pipeline capacity serving that state. Natural gas shipped to
California across our system represented approximately 34 percent of the natural
gas consumed in the state in 2002.
Electric power generation is one of the fastest growing demand sectors of
the natural gas market. The potential consequences of proposed and ongoing
restructuring and deregulation of the electric power industry are currently
unclear. Restructuring and deregulation benefit the natural gas industry by
creating more demand for natural gas turbine generated electric power, but this
effect is offset, in varying degrees, by increased generation efficiency and
more effective use of surplus electric capacity as a result of open market
access.
21
Our ability to extend our existing contracts or re-market expiring capacity
at maximum rates is dependent on competitive alternatives, the regulatory
environment at the federal, state and local levels and market supply and demand
factors at the relevant dates these contracts are extended or expire. The
duration of new or re-negotiated contracts will be affected by current prices,
competitive conditions and judgments concerning future trends and volatility.
ENVIRONMENTAL
A description of our environmental activities is included in Note 8 to our
Consolidated Financial Statements beginning on page F-15 and Note 5 to our
Condensed Consolidated Financial Statements beginning on page F-34.
EMPLOYEES
As of September 8, 2003, we had approximately 745 full-time employees, none
of whom are subject to collective bargaining agreements.
RELATED PARTY TRANSACTIONS
We participate in El Paso's cash management program which matches
short-term cash surpluses and needs of participating affiliates, thus minimizing
total borrowing from outside sources. Our continued participation in the program
may be dependent on any final rule issued by the FERC in connection with its
cash management notice of proposed rulemaking discussed in Note 5 to the
Condensed Consolidated Financial Statements beginning on page F-34. As of June
30, 2003 and December 31, 2002, we had advanced to El Paso $1,046 million and
$990 million. The market rate of interest at June 30, 2003 and December 31, 2002
was 1.3% and 1.5%. As of June 30, 2003 and December 31, 2002, we have classified
$845 million and $565 million of these advances as non-current notes receivable
from affiliates. These receivables were due upon demand; however, we do not
anticipate settlement within the next twelve months.
At June 30, 2003 and December 31, 2002, we had other accounts receivable
from related parties of $3 million and $7 million. Accounts payable to
affiliates was $20 million and $33 million at June 30, 2003 and December 31,
2002. These balances arose in the ordinary course of business.
On April 3, 2003, El Paso contributed its 500,000 shares of our 8%
preferred stock to us, including the accrued dividends. The total contribution
was approximately $359 million and is reflected as additional paid in capital in
our total stockholders equity.
The following table shows revenues and charges from our affiliates for the
six months ended June 30, 2003 and 2002 and the three years ended December 31,
2002:
SIX MONTHS
ENDED YEARS ENDED
JUNE 30, DECEMBER 31,
------------ -------------------
2003 2002 2002 2001 2000
---- ---- ---- ---- ----
(IN MILLIONS)
Revenues from affiliates............................ $ 9 $26 $46 $72 $35
Operations and maintenance from affiliates.......... 34 30 64 56 64
Reimbursement for operating expenses from
affiliates........................................ 6 4 12 7 --
22
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
The notes to our consolidated financial statements included in this
prospectus beginning on pages F-7 and F-32 contain information that is pertinent
to the following analysis, including a discussion of our significant accounting
policies.
GENERAL
Our business is the interstate transportation of natural gas. Our
interstate natural gas transportation systems face varying degrees of
competition from other pipelines, as well as from alternative energy sources
used to generate electricity, such as hydroelectric power, nuclear, coal and
fuel oil. We are regulated by the FERC which regulates the rates we can charge
our customers. These rates are a function of our costs of providing services to
our customers, and include a return on our invested capital. As a result, our
financial results have historically been relatively stable; however, they can be
subject to volatility due to factors such as weather, changes in natural gas
prices and market conditions, regulatory actions, competition and the
credit-worthiness of our customers. In addition, our ability to extend our
existing customer contracts or re-market expiring contracted capacity at maximum
rates is dependent on competitive alternatives, the regulatory environment and
supply and demand factors at the relevant dates these contracts are extended or
expire.
REVENUE OUTLOOK
Our total revenues were $134 million during the second quarter of 2003 and
$266 million for the six month period ended June 30, 2003. This compares to
revenues of $144 million and $296 million for the same periods of 2002, a
decrease of 7 percent for the second quarter and 10 percent year to date. As
discussed more fully in Note 5 to the Condensed Consolidated Financial
Statements beginning on page F-34, on September 20, 2002, the FERC issued an
order related to the allocation of capacity on our EPNG system. This order
impacted our 2003 revenues and will continue to impact our future results.
Based on the order, we are unable to remarket approximately 471 MMDth/d of
capacity, of which approximately 200 MMDth/d was rejected by Enron Corp. in May
2002 in its bankruptcy proceeding with the remaining 271 MMDth/d related to
contracts that expired within the time frame specified under the order. Prior to
the rejection and expiration of the 471 MMDth/d contracts, we were earning
approximately $3.5 million per month, net of revenue credits, related to this
capacity.
In July 2003, the FERC issued a rehearing order related to our capacity
allocation proceedings discussed more fully in Note 5 to the Condensed
Consolidated Financial Statements beginning on page F-34. In this ruling, the
FERC reaffirmed its decision that our full requirements contracts must be
converted to contract demand contracts effective September 1, 2003, supported
our position relative to the maximum amount of capacity we can make available to
our shippers and confirmed that we have honored our obligations under our
existing rate settlement, our contracts, the FERC's regulations and our
certificates. Pursuant to the July rehearing order, we are required to establish
a pool of 110 MMcf/d for use by our full requirement shippers until Line 2000
power up capacity is phased into service, which is expected in 2004. See Note 5
to the Condensed Consolidated Financial Statements beginning on page F-34 for a
discussion of this rehearing order. The full 110 MMcf/d will be turned back to
us on a permanent basis effective September 1, 2003, and we will be at risk for
remarketing this capacity.
In addition, we have risk sharing mechanisms under our most recent rate
case settlement. Under these risk sharing mechanisms, we collect cash from our
customers, refund a portion of the cash received as required by the mechanism
and then recognize the difference as revenues over the risk sharing period. This
risk sharing period will expire on December 31, 2003. The expiration of the risk
sharing mechanism will decrease our annual revenues by approximately $23
million. See Note 5 to the Condemned Consolidated Financial Statements beginning
on page F-34 for a further discussion of our risk sharing mechanism.
23
RESULTS OF OPERATIONS
We use earnings before interest and income taxes (EBIT) to assess the
operating results and effectiveness of our business. We define EBIT as net
income adjusted for (i) items that do not impact our income from continuing
operations, (ii) income taxes, (iii) interest and debt expense and (iv)
affiliated interest income. We exclude interest and debt expense so that
investors may evaluate our operating results without regard to our financing
methods. As a result, we believe EBIT is useful to our investors because it
allows them to more effectively evaluate the operating performance of our
business. In addition, this is the measure used by El Paso to evaluate the
operating performance of its business segments. This measurement may not be
comparable to measurements used by other companies and should not be used as a
substitute for net income or other performance measures such as operating income
or operating cash flow. The following is a reconciliation of our operating
income to our EBIT and EBIT to our net income for the following periods:
QUARTER ENDED SIX MONTHS
JUNE 30, ENDED JUNE 30, YEAR ENDED DECEMBER 31,
--------------- --------------- ------------------------
2003 2002 2003 2002 2002 2001 2000
------ ------ ------ ------ ------ ------ ------
(IN MILLIONS, EXCEPT VOLUME AMOUNTS)
Operating revenues...................... $ 134 $ 144 $ 266 $ 296 $ 564 $ 572 $ 508
Operating expenses...................... (221) (62) (280) (132) (669) (386) (285)
------ ------ ------ ------ ------ ------ ------
Operating income (loss)............... (87) 82 (14) 164 (105) 186 223
Other income and expense................ 1 -- 2 -- 1 (2) 4
------ ------ ------ ------ ------ ------ ------
EBIT.................................. (86) 82 (12) 164 (104) 184 227
Interest and debt expense............... (20) (18) (40) (34) (72) (87) (96)
Affiliated interest income.............. 4 6 7 12 22 58 75
Income taxes............................ 39 (26) 17 (54) 55 (60) (78)
------ ------ ------ ------ ------ ------ ------
Net income (loss)..................... $ (63) $ 44 $ (28) $ 88 $ (99) $ 95 $ 128
====== ====== ====== ====== ====== ====== ======
Total throughput (BBtu/d)(1)............ 3,925 4,046 3,997 4,124 4,065 4,535 4,310
====== ====== ====== ====== ====== ====== ======
---------------
(1) Excludes Mojave throughput on behalf of EPNG.
OPERATING RESULTS -- EBIT
SECOND QUARTER 2003 COMPARED TO SECOND QUARTER 2002
Operating revenues for the quarter ended June 30, 2003, were $10 million
lower than the same period in 2002. A decrease of $12 million was due to
capacity contracts that have expired which we are prohibited from remarketing
due to our September 20, 2002 FERC order. For further discussion of this order,
see our revenue outlook above, as well as Note 5 to the Condensed Consolidated
Financial Statements beginning on page F-34. Also contributing to the decrease
was $3 million of higher natural gas recoveries from customers in excess of
amounts used in operations in 2002 versus 2003. These decreases were partially
offset by $3 million of tax reimbursements related to the construction of
facilities for our customers, and $2 million of lower revenue credits under our
risk sharing mechanism as a result of our inability to remarket the capacity
contracts discussed above. For further discussion of our revenue sharing
provisions and revenue credits see Note 5 to the Condensed Consolidated
Financial Statements beginning on page F-34.
Operating expenses for the quarter ended June 30, 2003, were $159 million
higher than the same period in 2002. An increase of $154 million was due to El
Paso's Western Energy Settlement discussed in Notes 2 and 5 to the Condensed
Consolidated Financial Statements beginning on pages F-32 and F-34, of which
$146 million related to the incremental obligations associated with reaching
definitive settlements of these matters and $8 million of accretion and other
operation and maintenance costs. Also contributing to the increase was $5
million of natural gas used in operations in excess of natural gas recovered
from our customers in 2003, $3 million of gains recognized in 2002 on the sale
of non-pipeline assets, $2 million of
24
higher overhead allocations from El Paso and $2 million of taxes, other than
income taxes, due to a change in an estimated business activity tax settlement
in 2002. These increases were partially offset by a $5 million change in an
estimated settlement in 2002 related to the Carlsbad incident and $3 million due
to bad debt expense recorded in 2002 related to the bankruptcy of Enron Corp.
SIX MONTHS ENDED 2003 COMPARED TO SIX MONTHS ENDED 2002
Operating revenues for the six months ended June 30, 2003, were $30 million
lower than the same period in 2002. A decrease of $28 million was due to
capacity contracts that have expired which we are prohibited from remarketing
due to our September 20, 2002 FERC order. Also contributing to the decrease was
a $6 million fuel settlement related to our Mojave Pipeline rate case settled in
the first quarter of 2002 and $4 million of higher natural gas recoveries from
our customers in excess of amounts used in operations in 2002 versus 2003. This
decrease was partially offset by $3 million of lower revenue credits under our
risk sharing mechanism as a result of our inability to remarket the capacity
contracts discussed above, $3 million of tax reimbursements related to the
construction of facilities for our customers, and $2 million of higher
throughput based revenues from transportation to interconnecting pipelines
serving markets in the Midwest and East.
Operating expenses for the six months ended June 30, 2003, were $148
million higher than the same period in 2002. An increase of $158 million is due
to El Paso's Western Energy Settlement discussed in Notes 2 and 5 to the
Condensed Consolidated Financial Statements beginning on pages F-32 and F-34.
Also contributing to the increase was $7 million of natural gas used in
operations in excess of amounts recovered in 2003, $4 million related to gains
recognized in 2002 on the sale of non-pipeline assets, $4 million of higher
depreciation expense resulting from facilities placed in service after the
second quarter of 2002, $3 million of higher overhead allocations from El Paso
and $3 million of taxes, other than income taxes, due to a change in an
estimated business activity tax settlement in 2002. These increases were
partially offset by a decrease of $12 million due to bad debt expense recorded
in 2002 related to the bankruptcy of Enron Corp., $6 million due to the decrease
in our estimated purchase power costs in 2003 and the conversion of certain
compressors to gas from electric, a $5 million change in an estimated settlement
in 2002 related to the Carlsbad incident and $2 million from the periodic
revaluation of our gas imbalances due to a change in natural gas prices.
YEAR ENDED DECEMBER 31, 2002 COMPARED TO YEAR ENDED DECEMBER 31, 2001
Operating revenues for the year ended December 31, 2002, were $8 million
lower than in 2001. The decrease was due to $13 million from lower fuel
efficiencies and lower natural gas prices, $8 million from lower throughput to
California and other southwestern states due to lower electric generation demand
and milder weather in 2002 and $4 million from lower rates on the Mojave
Pipeline system as a result of a rate case settlement effective October 2001.
The decreases were partially offset by $13 million in higher revenues associated
with a larger portion of our available system capacity earning maximum tariff
rates and $3 million related to higher demand revenues in 2002 resulting from
annual inflation increases as provided in the EPNG tariff.
Operating expenses for the year ended December 31, 2002, were $283 million
higher than in 2001 primarily as a result of a $412 million accrual for our
Western Energy Settlement in December 2002. Also contributing to the increase
were a $10 million contribution to a charitable foundation, a $6 million
increase in corporate allocations, a $6 million increase in bad debt expense
related to the bankruptcy of Enron Corporation and a $3 million increase in
payroll and other costs. These increases were partially offset by the merger
related costs of $98 million incurred in 2001 related to the relocation of our
headquarters from El Paso, Texas to Colorado Springs, Colorado and costs
associated with severed employees as part of El Paso's merger with Coastal. For
a further discussion of these charges, see Note 3 to the Consolidated Financial
Statements beginning on page F-11. Also offsetting the increase was a $22
million reduction associated with the periodic revaluation of natural gas
imbalances as a result of changes in imbalance volumes and gas prices, $10
million of lower compressor operating costs resulting from lower electric usage
and prices in 2002, $8 million of lower property and other taxes due to a change
25
in an estimated business activity tax settlement and property and franchise tax
refunds received in 2002, $7 million of lower legal fees, $7 million of
depreciation adjustments due to the finalization of regulatory issues in 2002
and $6 million in decreased environmental costs.
Other income for the year ended December 31, 2002, was $3 million higher
than in 2001 due to gains on sales of non-pipeline assets of $1 million in 2002
and a 2001 accrual of $3 million for proposed fines from the Department of
Transportation related to the August 2000 pipeline rupture.
YEAR ENDED DECEMBER 31, 2001 COMPARED TO YEAR ENDED DECEMBER 31, 2000
Operating revenues for the year ended December 31, 2001, were $64 million
higher than the same period in 2000. The increase was due to higher reservation
revenues as a result of a larger portion of our capacity earning maximum tariff
rates compared to the same period in 2000 and higher throughput from increased
deliveries to California and other western states. The increase was partially
offset by the impact of lower prices on fuel recoveries.
Operating expenses for the year ended December 31, 2001, were $101 million
higher than the same period in 2000. The increase was primarily due to
merger-related costs incurred related to the relocation of our headquarters as
part of El Paso's merger with Coastal, the impact of price changes on natural
gas imbalances, higher power costs for compression and increases to our reserve
for bad debts during the fourth quarter of 2001 in connection with the
bankruptcy of Enron Corp. The increase was partially offset by unfavorable
shipper and producer settlements in 2000.
Other income (expense), net for the year ended December 31, 2001, was $6
million lower than the same period in 2000 due primarily to the sales of
non-pipeline related assets in 2000.
INTEREST AND DEBT EXPENSE
Below is the analysis of our interest expense:
SIX MONTHS
ENDED YEAR ENDED
JUNE 30, DECEMBER 31,
------------ --------------------
2003 2002 2002 2001 2000
---- ---- ---- ---- ----
(UNAUDITED)
(IN MILLIONS)
Long term debt, including current maturities...... $40 $29 $69 $73 $74
Short term borrowings............................. -- 8 8 23 30
Other............................................. 1 -- 1 -- --
Less: Capitalized interest........................ (1) (3) (6) (9) (8)
--- --- --- --- ---
Total interest and debt expense................. $40 $34 $72 $87 $96
=== === === === ===
SECOND QUARTER 2003 COMPARED TO SECOND QUARTER 2002
Interest and debt expense for the quarter ended June 30, 2003, was $2
million higher than the same period in 2002 primarily due to a $5 million
increase in interest expense resulting from the issuance of $300 million
long-term debt in June 2002. This increase was offset by a $4 million decrease
in commercial paper interest expense due to the discontinuation of commercial
paper activity in the fourth quarter of 2002.
SIX MONTHS ENDED 2003 COMPARED TO SIX MONTHS ENDED 2002
Interest and debt expense for the six months ended June 30, 2003, was $6
million higher than the same period in 2002 primarily due to an $11 million
increase in interest expense resulting from the issuance of $300 million
long-term debt in June 2002 and a $2 million decrease in interest capitalized on
construction projects due to a lower capitalization base in 2003. These
increases were partially offset by an
26
$8 million decrease in commercial paper interest expense due to the
discontinuation of commercial paper activity in the fourth quarter of 2002.
YEAR ENDED DECEMBER 31, 2002 COMPARED TO YEAR ENDED DECEMBER 31, 2001
Interest and debt expense for the year ended December 31, 2002, was $15
million lower than in 2001. The decrease in interest expense was primarily due
to a decrease in average commercial paper balances outstanding of $480 million
in 2001 compared with $296 million in 2002 with the weighted average interest
rate decreasing from 4.61% in 2001 to 2.67% in 2002. Also contributing to the
decrease was a lower weighted average outstanding long-term debt principal
balance in 2002 compared with 2001. In January 2002, we retired $215 million
aggregate principal amount of 7.75% notes and in June 2002, we issued $300
million aggregate principal amount 8.375% notes. Offsetting the decrease was
lower capitalized interest in 2002 compared to 2001 due to lower interest
capitalization rates partially offset by a larger average construction work in
progress balance in 2002.
YEAR ENDED DECEMBER 31, 2001 COMPARED TO YEAR ENDED DECEMBER 31, 2000
Interest and debt expense for the year ended December 31, 2001, was $9
million lower than in 2000. The decrease was primarily due to a decrease in the
weighted average interest rate on commercial paper borrowings. The rate
decreased from 6.46% in 2000 to 4.61% in 2001. There were no maturities of long-
term debt during 2001, resulting in a stable long-term debt balance.
AFFILIATED INTEREST INCOME
SECOND QUARTER 2003 COMPARED TO SECOND QUARTER 2002
Affiliated interest income, net for the quarter ended June 30, 2003, was $2
million lower than the same period in 2002 due to lower short-term interest
rates in 2003 and lower average advances to El Paso under our cash management
program. The average short-term interest rates for the second quarter decreased
from 1.9% in 2002 to 1.3% in 2003. The average advance balance for the second
quarter of $1.2 billion in 2002 decreased to $1 billion in 2003.
SIX MONTHS ENDED 2003 COMPARED TO SIX MONTHS ENDED 2002
Affiliated interest income, net for six months ended June 30, 2003, was $5
million lower than the same period in 2002 due to lower short-term interest
rates in 2003 and lower average advances to El Paso under our cash management
program. The average short-term interest rates for six months ended decreased
from 1.9% in 2002 to 1.3% in 2003. The average advance balance for the six
months ended June 30, 2002 of $1.3 billion decreased to $1 billion in 2003.
YEAR ENDED DECEMBER 31, 2002 COMPARED TO YEAR ENDED DECEMBER 31, 2001
Affiliated interest income for the year ended December 31, 2002, was $36
million lower than in 2001 due to lower short-term interest rates in 2002 and
lower average advances to El Paso under the cash management program. The average
short-term interest rates decreased from 4.3% in 2001 to 1.8% in 2002, and
average advances to El Paso under its cash management program, were $1,227
million in 2002 versus $1,352 million in 2001.
YEAR ENDED DECEMBER 31, 2001 COMPARED TO YEAR ENDED DECEMBER 31, 2000
Affiliated interest income for the year ended December 31, 2001, was $17
million lower than in 2000 due to lower short-term interest rates in 2001. The
average short-term interest rates for the twelve months decreased from 6.4% in
2000 to 4.3% in 2001.
27
INCOME TAXES
SECOND QUARTER AND SIX MONTHS ENDED 2003 COMPARED TO SECOND QUARTER AND SIX
MONTHS ENDED 2002
The income tax benefit for the quarter and six months ended June 30, 2003,
was $39 million and $17 million, resulting in an effective tax rate of 38
percent in both periods. The income tax expense for the quarter and six months
ended June 30, 2002 was $26 million and $54 million, resulting in an effective
tax of 37 percent and 38 percent. Our effective tax rates were different from
the statutory rate of 35 percent in all periods primarily due to state income
taxes.
YEAR ENDED DECEMBER 31, 2002 COMPARED TO YEARS ENDED DECEMBER 31, 2001 AND
DECEMBER 31, 2000
Income tax benefit for the year ended December 31, 2002, was $55 million
and the income tax expense for the years ended December 31, 2001 and 2000 was
$60 million and $78 million, resulting in effective tax rates of 36 percent, 38
percent and 38 percent. Our effective tax rates were different from the
statutory rate of 35 percent in all periods primarily due to state income taxes.
For a reconciliation of the statutory rate to the effective rates, see Note 4 to
the Consolidated Financial Statements beginning on page F-11.
LIQUIDITY AND CAPITAL RESOURCES
LIQUIDITY
Our liquidity needs are provided by cash flow from operating activities and
the use of El Paso's cash management program. Under El Paso's cash management
program, depending on whether we have short-term cash surpluses or requirements,
we either provide cash to El Paso or El Paso provides cash to us. We have
historically provided cash advances to El Paso, and we reflect these net
advances to our parent as investing activities in our statement of cash flows.
As of June 30, 2003, we had net receivables from El Paso and its subsidiaries of
$1,046 million as a result of this program. These receivables are due upon
demand. However, as of June 30, 2003, we have classified $845 million as
non-current because we do not anticipate settlement within twelve months. We
believe that cash flow from operating activities and cash provided by El Paso's
cash management program will be adequate to meet our short-term capital and debt
servicing requirements for existing operations. Our cash flows were as follows:
SIX MONTHS ENDED
JUNE 30, YEAR ENDED DECEMBER 31,
---------------- -----------------------
2003 2002 2002 2001 2000
------ ------ ----- ----- -----
(UNAUDITED)
(IN MILLIONS)
Cash flows from operating activities..... $ 113 $ 149 $ 269 $ 324 $ 160
Cash flows from investing activities..... (116) (210) 120 (455) 155
Cash flows from financing activities..... -- 61 (386) 131 (315)
In a series of credit rating agency actions in late 2002 and early 2003,
and contemporaneously with the downgrades of the senior unsecured indebtedness
of El Paso, our senior unsecured indebtedness was downgraded to below investment
grade and is currently rated B1 by Moody's and B+ by Standard & Poor's (with a
developing outlook at Moody's and a negative outlook at Standard & Poor's).
These downgrades will increase our cost of capital and collateral requirements
and could impede our access to capital markets in the future.
In April 2003, El Paso entered into a new $3 billion revolving credit
facility, with a $1.5 billion letter of credit sublimit, which matures in June
2005. This facility replaces the previous $3 billion, 364-day revolving credit
facility. Approximately $1 billion of other financing arrangements (including
leases, letters of credit and other facilities) were also amended to conform El
Paso's obligations to the new $3 billion revolving credit facility. We, along
with our affiliates, ANR Pipeline Company, Tennessee Gas Pipeline Company (TGP)
and El Paso, are designated borrowers under the $3 billion revolving credit
facility.
28
Our direct subsidiary, Sabine, is one of 17 subsidiary guarantors of El
Paso's $3 billion facility. In connection with its guarantee of the $3 billion
facility, Sabine pledged its equity interests in each of EPNG Mojave, Inc. and
El Paso Mojave Pipeline Co., its sole assets, to collateralize that facility. In
addition, in connection with its guarantee of El Paso's $3 billion facility, our
direct parent El Paso EPNG Investments, L.L.C. pledged its equity interests in
us to collateralize that facility. El Paso EPNG Investments' equity in us and
Sabine's equity interests in EPNG Mojave, Inc. and El Paso Mojave Pipeline Co.
also collateralize approximately $1 billion of other financing arrangements,
including leases, letters of credit and other facilities. We are only liable for
the amounts we borrow under the $3 billion facility other than as described
above.
The revolving credit facility has a borrowing cost of LIBOR plus 350 basis
points and letter of credit fees of 350 basis points. A key financial covenant
of the facility is the requirement for El Paso to maintain debt to total
capitalization, as defined in the revolving credit facility, not to exceed 75
percent. In addition, we and the other pipeline company borrowers cannot incur
incremental debt if the incurrence of debt would cause our debt to EBITDA ratio,
as defined in the revolving credit facilities, to exceed 5 to 1. The proceeds
from the issuance of debt by the pipeline company borrowers can be used only for
maintenance and expansion capital expenditures or investments in other
FERC-regulated assets, to fund working capital and to refinance existing debt.
As of June 30, 2003, $1.5 billion was outstanding and $1.1 billion in letters of
credit were issued under the $3 billion facility, none of which were borrowed by
or issued on behalf of us.
On March 20, 2003, we and our affiliates entered into an agreement in
principle (the Western Energy Settlement) with various public and private
claimants, including the states of California, Washington, Oregon and Nevada, to
resolve the principal litigation, claims and regulatory proceedings against us
and our affiliates relating to the sale or delivery of natural gas and
electricity from September 1996 to the date of the Western Energy Settlement. On
June 26, 2003, El Paso announced that it had executed two definitive settlement
agreements that resolve this litigation. See Notes 2 and 8 to the Consolidated
Financial Statements beginning on pages F-10 and F-15, and Notes 2 and 5 to the
Condensed Consolidated Financial Statements beginning on pages F-32 and F-34.
CAPITAL EXPENDITURES
Our capital expenditures during the periods indicated are listed below:
SIX MONTHS
ENDED JUNE 30, YEAR ENDED DECEMBER 31,
-------------- ------------------------
2003 2002 2002 2001 2000
---- ---- ---- ---- ----
(IN MILLIONS)
Maintenance........................... $ 64 $62 $123 $105 $ 86
Expansion/Other....................... 36 32 70 52 142
---- --- ---- ---- ----
Total............................ $100 $94 $193 $157 $228
==== === ==== ==== ====
Under our current plan, we expect to spend between approximately $100
million and $150 million in each of the next three years for capital
expenditures to maintain the integrity of our pipelines and ensure the reliable
delivery of natural gas to our customers. In addition, we have budgeted to spend
between approximately $70 million and $195 million in each of the next three
years to expand the capacity of our pipeline systems. We expect to fund our
maintenance and expansion capital expenditures using a combination of internally
generated funds and external financing.
DEBT
For a discussion of our debt obligations, see Note 7 to the Consolidated
Financial Statements beginning on page F-13 and Note 4 to the Condensed
Consolidated Financial Statements beginning on page F-33.
29
COMMITMENTS AND CONTINGENCIES
For a discussion of our commitments and contingencies, see Note 8 to our
Consolidated Financial Statements beginning on page F-15 and Note 5 to the
Condensed Consolidated Financial Statements beginning on page F-34.
NEW ACCOUNTING PRONOUNCEMENTS ISSUED BUT NOT YET ADOPTED
None.
30
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Our primary market risk is exposure to changing interest rates. The table
below shows the carrying value and related weighted average interest rates of
our interest bearing securities, by expected maturity dates, and the fair value
of those securities. The fair values of our fixed rate long-term debt securities
have been estimated based on quoted market prices for the same or similar
issues.
DECEMBER 31, 2002 DECEMBER 31, 2001
-------------------------------------------------- ---------------------
EXPECTED FISCAL YEAR OF MATURITY
OF CARRYING AMOUNTS
-------------------------------------------------- CARRYING
2003 2004-2007 THEREAFTER TOTAL FAIR VALUE AMOUNTS FAIR VALUE
---- --------- ---------- ----- ---------- -------- ----------
(DOLLARS IN MILLIONS)
LIABILITIES:
Long-term debt, including
current portion -- fixed
rate...................... $200 -- $758 $958 $739 $874 $891
Average interest rate... 6.8% -- 7.9%
Other than the issuance of the Old Notes, there were no material changes in
our quantitative and qualitative disclosures about market risk from those as of
December 31, 2002.
CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL
DISCLOSURE
None.
31
USE OF PROCEEDS
We received net proceeds of $347 million from the issuance of the Old Notes
after deducting initial purchasers' discounts and estimated offering expenses.
We are required to deposit up to $343.5 million of these net proceeds into
escrow for the benefit of the settling parties in the Western Energy Settlement.
Until the escrow account is established, we intend to maintain the net proceeds
from the issuance of the Old Notes for working capital purposes; however, we are
not contractually prohibited from including these proceeds in El Paso's cash
management program. If the Western Energy Settlement is not approved, or if the
escrow account is not established by the settling parties, the net proceeds from
the issuance of the Old Notes will be used for our other working capital and
general corporate purposes. We will not receive any cash proceeds from the
issuance of the New Notes. We will exchange outstanding Old Notes for New Notes
in like principal amount as contemplated in this prospectus. The terms of the
New Notes are identical in all material respects to the existing Old Notes
except as otherwise described herein under "Description of the Notes." The Old
Notes surrendered in exchange for the New Notes will be retired and canceled and
cannot be reissued. Accordingly, issuance of the New Notes will not result in a
change in our total debt and other financing obligations.
CAPITALIZATION
The following table sets forth our historical capitalization as of June 30,
2003, and our capitalization as adjusted to reflect the original issuance of
$355 million of Old Notes on July 21, 2003, the proceeds of which will be used
as set forth under "Use of Proceeds." The exchange of the Old Notes for the New
Notes will not impact our overall capitalization. This table should be read in
conjunction with our Condensed Consolidated Financial Statements and related
notes contained in our June 30, 2003 Form 10-Q, which are included in this
prospectus beginning on page F-29.
AS OF
JUNE 30,
2003 AS ADJUSTED
------------- -----------
(UNAUDITED)
(IN MILLIONS)
Cash and cash equivalents................................... $ -- $ --
====== ======
Current maturities of long-term debt........................ $ 200 $ 200
------ ------
Long-term debt:
7.625% Notes due 2010..................................... $ -- $ 355
8.625% Debentures due 2022................................ 260 260
7.5% Debentures due 2026.................................. 200 200
8.375% Notes due 2032..................................... 300 300
Less: Unamortized discount................................ (2) (6)
------ ------
Total long-term debt.............................. 758 1,109
------ ------
Total stockholder's equity.................................. 1,128 1,128
------ ------
Total capitalization.............................. $2,086 $2,437
====== ======
32
THE EXCHANGE OFFER
EXCHANGE TERMS
Series A notes (Old Notes) in an aggregate principal amount of $355,000,000
are currently issued and outstanding. The maximum aggregate principal amount of
Series B notes (New Notes) that will be issued in exchange for Old Notes is
$355,000,000. The terms of the New Notes and the Old Notes are substantially the
same in all material respects, except that the New Notes will not contain terms
with respect to transfer restrictions, registration rights and payments of
additional interest.
The New Notes will bear interest at a rate of 7 5/8% per year, payable
semi-annually on February 1 and August 1 of each year, beginning on February 1,
2004. Holders of New Notes will receive interest from the date of the original
issuance of the Old Notes or from the date of the last payment of interest on
the Old Notes, whichever is later. Holders of New Notes will not receive any
interest on Old Notes tendered and accepted for exchange. In order to exchange
your Old Notes for transferable New Notes in the exchange offer, you will be
required to make the following representations, which are included in the letter
of transmittal:
- any New Notes that you receive will be acquired in the ordinary course of
your business;
- you are not participating, and have no arrangement or understanding with
any person or entity to participate, in the distribution of the New
Notes;
- you are not our "affiliate," as defined in Rule 405 under the Securities
Act, or a broker-dealer tendering Old Notes acquired directly from us for
resale pursuant to Rule 144A or any other available exemption under the
Securities Act; and
- if you are not a broker-dealer, that you are not engaged in and do not
intend to engage in the distribution of the New Notes.
Upon the terms and subject to the conditions set forth in this prospectus
and in the letter of transmittal, we will accept for exchange any Old Notes
properly tendered in the exchange offer, and the exchange agent will deliver the
New Notes promptly after the expiration date of the exchange offer.
If you tender your Old Notes, you will not be required to pay brokerage
commissions or fees or, subject to the instructions in the letter of
transmittal, transfer taxes with respect to the exchange of the Old Notes in
connection with the exchange offer. We will pay all charges, expenses and
transfer taxes in connection with the exchange offer, other than the taxes
described below under "-- Transfer Taxes."
WE MAKE NO RECOMMENDATION TO YOU AS TO WHETHER YOU SHOULD TENDER OR REFRAIN
FROM TENDERING ALL OR ANY PORTION OF YOUR EXISTING OLD NOTES INTO THIS EXCHANGE
OFFER. IN ADDITION, NO ONE HAS BEEN AUTHORIZED TO MAKE THIS RECOMMENDATION. YOU
MUST MAKE YOUR OWN DECISION WHETHER TO TENDER INTO THIS EXCHANGE OFFER AND, IF
SO, THE AGGREGATE AMOUNT OF OLD NOTES TO TENDER AFTER READING THIS PROSPECTUS
AND THE LETTER OF TRANSMITTAL AND CONSULTING WITH YOUR ADVISORS, IF ANY, BASED
ON YOUR FINANCIAL POSITION AND REQUIREMENTS.
EXPIRATION DATE; EXTENSIONS; TERMINATION; AMENDMENTS
The exchange offer expires at 5:00 p.m., New York City time, on October 17,
2003, unless we extend the exchange offer, in which case the expiration date
will be the latest date and time to which we extend the exchange offer.
We expressly reserve the right, so long as applicable law allows:
- to delay our acceptance of Old Notes for exchange;
- to terminate the exchange offer if any of the conditions set forth under
"-- Conditions of the Exchange Offer" exist;
- to waive any condition to the exchange offer;
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- to amend any of the terms of the exchange offer; and
- to extend the expiration date and retain all Old Notes tendered in the
exchange offer, subject to your right to withdraw your tendered Old Notes
as described under "-- Withdrawal of Tenders."
Any waiver or amendment to the exchange offer will apply to all Old Notes
tendered, regardless of when or in what order the Old Notes were tendered. If
the exchange offer is amended in a manner that we think constitutes a material
change, or if we waive a material condition of the exchange offer, we will
promptly disclose the amendment or waiver by means of a prospectus supplement
that will be distributed to the registered holders of the Old Notes, and we will
extend the exchange offer to the extent required by Rule 14e-1 under the
Exchange Act.
We will promptly follow any delay in acceptance, termination, extension or
amendment by oral or written notice of the event to the exchange agent, followed
promptly by oral or written notice to the registered holders. Should we choose
to delay, extend, amend or terminate the exchange offer, we will have no
obligation to publish, advertise or otherwise communicate this announcement,
other than by making a timely release to an appropriate news agency.
In the event we terminate the exchange offer, all Old Notes previously
tendered and not accepted for payment will be returned promptly to the tendering
holders.
In the event that the exchange offer is withdrawn or otherwise not
completed, New Notes will not be given to holders of Old Notes who have validly
tendered their Old Notes.
RESALE OF NEW NOTES
Based on interpretations of the SEC staff set forth in no action letters
issued to third parties, we believe that New Notes issued under the exchange
offer in exchange for Old Notes may be offered for resale, resold and otherwise
transferred by you without compliance with the registration and prospectus
delivery requirements of the Securities Act, if:
- you are acquiring New Notes in the ordinary course of your business;
- you are not participating, and have no arrangement or understanding with
any person to participate, in the distribution of the New Notes;
- you are not our "affiliate" within the meaning of Rule 405 under the
Securities Act;
- you are not a broker-dealer who purchased Old Notes directly from us for
resale pursuant to Rule 144A or any other available exemption under the
Securities Act; and
If you tender Old Notes in the exchange offer with the intention of
participating in any manner in a distribution of the New Notes:
- you cannot rely on those interpretations by the SEC staff, and
- you must comply with the registration and prospectus delivery
requirements of the Securities Act in connection with a secondary resale
transaction and that such a secondary resale transaction must be covered
by an effective registration statement containing the selling security
holder information required by Item 507 or 508, as applicable, of
Regulation S-K.
Only broker-dealers that acquired the Old Notes as a result of
market-making activities or other trading activities may participate in the
exchange offer. Each broker-dealer that receives New Notes for its own account
in exchange for Old Notes, where such Old Notes were acquired by such
broker-dealer as a result of market-making activities or other trading
activities, must acknowledge that it will deliver a prospectus in connection
with any resale of the New Notes. Please read the section captioned "Plan of
Distribution" for more details regarding the transfer of New Notes.
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ACCEPTANCE OF OLD NOTES FOR EXCHANGE
We will accept for exchange Old Notes validly tendered pursuant to the
exchange offer, or defectively tendered, if such defect has been waived by us.
We will not accept Old Notes for exchange subsequent to the expiration date of
the exchange offer. Tenders of Old Notes will be accepted only in denominations
of $1,000 and integral multiples thereof.
We expressly reserve the right, in our sole discretion, to:
- delay acceptance for exchange of Old Notes tendered under the exchange
offer, subject to Rule 14e-1 under the Exchange Act, which requires that
an offeror pay the consideration offered or return the securities
deposited by or on behalf of the holders promptly after the termination
or withdrawal of a tender offer, or
- terminate the exchange offer and not accept for exchange any Old Notes
not theretofore accepted for exchange, if any of the conditions set forth
below under "-- Conditions of the Exchange Offer" have not been satisfied
or waived by us or in order to comply in whole or in part with any
applicable law. In all cases, New Notes will be issued only after timely
receipt by the exchange agent of certificates representing Old Notes, or
confirmation of book-entry transfer, a properly completed and duly
executed letter of transmittal, or a manually signed facsimile thereof,
and any other required documents. For purposes of the exchange offer, we
will be deemed to have accepted for exchange validly tendered Old Notes,
or defectively tendered Old Notes with respect to which we have waived
such defect, if, as and when we give oral, confirmed in writing, or
written notice to the exchange agent. Promptly after the expiration date,
we will deposit the New Notes with the exchange agent, who will act as
agent for the tendering holders for the purpose of receiving the New
Notes and transmitting them to the holders. The exchange agent will
deliver the New Notes to holders of Old Notes accepted for exchange after
the exchange agent receives the New Notes.
If, for any reason, we delay acceptance for exchange of validly tendered
Old Notes or we are unable to accept for exchange validly tendered Old Notes,
then the exchange agent may, nevertheless, on our behalf, retain tendered Old
Notes, without prejudice to our rights described under "-- Expiration Date;
Extensions; Termination; Amendments", "-- Conditions of the Exchange Offer" and
"-- Withdrawal of Tenders", subject to Rule 14e-1 under the Exchange Act, which
requires that an offeror pay the consideration offered or return the securities
deposited by or on behalf of the holders thereof promptly after the termination
or withdrawal of a tender offer.
If any tendered Old Notes are not accepted for exchange for any reason, or
if certificates are submitted evidencing more Old Notes than those that are
tendered, certificates evidencing Old Notes that are not exchanged will be
returned, without expense, to the tendering holder, or, in the case of Old Notes
tendered by book-entry transfer into the exchange agent's account at a
book-entry transfer facility under the procedure set forth under "-- Procedures
for Tendering Old Notes -- Book-Entry Transfer", such Old Notes will be credited
to the account maintained at such book-entry transfer facility from which such
Old Notes were delivered, unless otherwise requested by such holder under
"Special Delivery Instructions" in the letter of transmittal, promptly following
the expiration date or the termination of the exchange offer.
Tendering holders of Old Notes exchanged in the exchange offer will not be
obligated to pay brokerage commissions or transfer taxes with respect to the
exchange of their Old Notes other than as described in "Transfer Taxes" or in
Instruction 7 to the letter of transmittal. We will pay all other charges and
expenses in connection with the exchange offer.
PROCEDURES FOR TENDERING OLD NOTES
Any beneficial owner whose Old Notes are registered in the name of a
broker, dealer, commercial bank, trust company or other nominee or held through
a book-entry transfer facility and who wishes to tender Old Notes should contact
such registered holder promptly and instruct such registered holder to tender
Old Notes on such beneficial owner's behalf.
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TENDER OF OLD NOTES HELD THROUGH DEPOSITORY TRUST COMPANY
The exchange agent and Depository Trust Company ("DTC") have confirmed that
the exchange offer is eligible for the DTC's automated tender offer program.
Accordingly, DTC participants may electronically transmit their acceptance of
the exchange offer by causing DTC to transfer Old Notes to the exchange agent in
accordance with DTC's automated tender offer program procedures for transfer.
DTC will then send an agent's message to the exchange agent.
The term "agent's message" means a message transmitted by DTC, received by
the exchange agent and forming part of the book-entry confirmation, which states
that DTC has received an express acknowledgment from the participant in DTC
tendering Old Notes that are the subject of that book-entry confirmation that
the participant has received and agrees to be bound by the terms of the letter
of transmittal, and that we may enforce such agreement against such participant.
In the case of an agent's message relating to guaranteed delivery, the term
means a message transmitted by DTC and received by the exchange agent which
states that DTC has received an express acknowledgment from the participant in
DTC tendering Old Notes that they have received and agree to be bound by the
notice of guaranteed delivery.
TENDER OF OLD NOTES HELD IN CERTIFICATED FORM
For a holder to validly tender Old Notes held in certificated form:
- the exchange agent must receive at its address set forth in this
prospectus a properly completed and validly executed letter of
transmittal, or a manually signed facsimile thereof, together with any
signature guarantees and any other documents required by the instructions
to the letter of transmittal, and
- the exchange agent must receive certificates for tendered Old Notes at
such address, or such Old Notes must be transferred pursuant to the
procedures for book-entry transfer described below. A confirmation of
such book-entry transfer must be received by the exchange agent prior to
the expiration date of the exchange offer. A holder who desires to tender
Old Notes and who cannot comply with the procedures set forth herein for
tender on a timely basis or whose Old Notes are not immediately available
must comply with the procedures for guaranteed delivery set forth below.
LETTERS OF TRANSMITTAL AND OLD NOTES SHOULD BE SENT ONLY TO THE EXCHANGE
AGENT, AND NOT TO US OR TO DTC.
THE METHOD OF DELIVERY OF OLD NOTES, LETTERS OF TRANSMITTAL AND ALL OTHER
REQUIRED DOCUMENTS TO THE EXCHANGE AGENT IS AT THE ELECTION AND RISK OF THE
HOLDER TENDERING OLD NOTES. DELIVERY OF SUCH DOCUMENTS WILL BE DEEMED MADE ONLY
WHEN ACTUALLY RECEIVED BY THE EXCHANGE AGENT. IF SUCH DELIVERY IS BY MAIL, WE
SUGGEST THAT THE HOLDER USE PROPERLY INSURED, REGISTERED MAIL WITH RETURN
RECEIPT REQUESTED, AND THAT THE MAILING BE MADE SUFFICIENTLY IN ADVANCE OF THE
EXPIRATION DATE OF THE EXCHANGE OFFER TO PERMIT DELIVERY TO THE EXCHANGE AGENT
PRIOR TO SUCH DATE. NO ALTERNATIVE, CONDITIONAL OR CONTINGENT TENDERS OF OLD
NOTES WILL BE ACCEPTED.
SIGNATURE GUARANTEE
Signatures on the letter of transmittal must be guaranteed by an eligible
institution unless:
- the letter of transmittal is signed by the registered holder of the Old
Notes tendered therewith, or by a participant in one of the book-entry
transfer facilities whose name appears on a security position listing it
as the owner of those Old Notes, or if any Old Notes for principal
amounts not tendered are to be issued directly to the holder, or, if
tendered by a participant in one of the book-entry transfer facilities,
any Old Notes for principal amounts not tendered or not accepted for
exchange are to be credited to the participant's account at the
book-entry transfer facility, and
36
neither the "Special Issuance Instructions" nor the "Special Delivery
Instructions" box on the letter of transmittal has been completed, or
- the Old Notes are tendered for the account of an eligible institution.
An eligible institution is a firm that is a member of a registered national
securities exchange or of the National Association of Securities Dealers, Inc.,
a commercial bank or a trust company having an office or correspondent in the
United States or an "eligible guarantor institution" within the meaning of Rule
17Ad-15 under the Exchange Act.
BOOK-ENTRY TRANSFER
The exchange agent will seek to establish a new account or utilize an
existing account with respect to the Old Notes at DTC promptly after the date of
this prospectus. Any financial institution that is a participant in the DTC
system and whose name appears on a security position listing as the owner of the
Old Notes may make book-entry delivery of Old Notes by causing DTC to transfer
such Old Notes into the exchange agent's account. HOWEVER, ALTHOUGH DELIVERY OF
OLD NOTES MAY BE EFFECTED THROUGH BOOK-ENTRY TRANSFER INTO THE EXCHANGE AGENT'S
ACCOUNT AT DTC, A PROPERLY COMPLETED AND VALIDLY EXECUTED LETTER OF TRANSMITTAL,
OR A MANUALLY SIGNED FACSIMILE THEREOF, MUST BE RECEIVED BY THE EXCHANGE AGENT
AT ONE OF ITS ADDRESSES SET FORTH IN THIS PROSPECTUS ON OR PRIOR TO THE
EXPIRATION DATE OF THE EXCHANGE OFFER, OR ELSE THE GUARANTEED DELIVERY
PROCEDURES DESCRIBED BELOW MUST BE COMPLIED WITH. The confirmation of a
book-entry transfer of Old Notes into the exchange agent's account at DTC is
referred to in this prospectus as a "book-entry confirmation." Delivery of
documents to DTC in accordance with DTC's procedures does not constitute
delivery to the exchange agent.
GUARANTEED DELIVERY
If you wish to tender your Old Notes and:
(1) certificates representing your Old Notes are not lost but are not
immediately available,
(2) time will not permit your letter of transmittal, certificates
representing your Old Notes and all other required documents to reach the
exchange agent on or prior to the expiration date of the exchange offer, or
(3) the procedures for book-entry transfer cannot be completed on or
prior to the expiration date of the exchange offer, you may nevertheless
tender if all of the following conditions are complied with:
- your tender is made by or through an eligible institution; and
- on or prior to the expiration date of the exchange offer, the exchange
agent has received from the eligible institution a properly completed
and validly executed notice of guaranteed delivery, by manually signed
facsimile transmission, mail or hand delivery, in substantially the
form provided with this prospectus. The notice of guaranteed delivery
must:
(a) set forth your name and address, the registered number(s) of
your Old Notes and the principal amount of Old Notes tendered;
(b) state that the tender is being made thereby;
(c) guarantee that, within three New York Stock Exchange trading
days after the expiration date, the letter of transmittal or facsimile
thereof properly completed and validly executed, together with
certificates representing the Old Notes, or a book-entry confirmation,
and any other documents required by the letter of transmittal and the
instructions thereto, will be deposited by the eligible institution with
the exchange agent; and
(d) the exchange agent receives the properly completed and validly
executed letter of transmittal or facsimile thereof with any required
signature guarantees, together with certificates
37
for all Old Notes in proper form for transfer, or a book-entry
confirmation, and any other required documents, within three New York
Stock Exchange trading days after the expiration date.
OTHER MATTERS
New Notes will be issued in exchange for Old Notes accepted for exchange
only after timely receipt by the exchange agent of:
- certificates for (or a timely book-entry confirmation with respect to)
your Old Notes,
- a properly completed and duly executed letter of transmittal or facsimile
thereof with any required signature guarantees, or, in the case of a
book-entry transfer, an agent's message, and
- any other documents required by the letter of transmittal.
We will determine, in our sole discretion, all questions as to the form of
all documents, validity, eligibility, including time of receipt, and acceptance
of all tenders of Old Notes. Our determination will be final and binding on all
parties. ALTERNATIVE, CONDITIONAL OR CONTINGENT TENDERS OF OLD NOTES WILL NOT BE
CONSIDERED VALID. WE RESERVE THE ABSOLUTE RIGHT TO REJECT ANY OR ALL TENDERS OF
OLD NOTES THAT ARE NOT IN PROPER FORM OR THE ACCEPTANCE OF WHICH, IN OUR
OPINION, WOULD BE UNLAWFUL. WE ALSO RESERVE THE RIGHT TO WAIVE ANY DEFECTS,
IRREGULARITIES OR CONDITIONS OF TENDER AS TO PARTICULAR OLD NOTES.
Our interpretation of the terms and conditions of the exchange offer,
including the instructions in the letter of transmittal, will be final and
binding.
Any defect or irregularity in connection with tenders of Old Notes must be
cured within the time we determine, unless waived by us. We will not consider
the tender of Old Notes to have been validly made until all defects and
irregularities have been waived by us or cured. Neither we, the exchange agent,
or any other person will be under any duty to give notice of any defects or
irregularities in tenders of Old Notes, or will incur any liability to holders
for failure to give any such notice.
WITHDRAWAL OF TENDERS
Except as otherwise provided in this prospectus, you may withdraw your
tender of Old Notes at any time prior to the expiration date.
For a withdrawal to be effective:
- the exchange agent must receive a written notice of withdrawal at one of
the addresses set forth below under "-- Exchange Agent", or
- you must comply with the appropriate procedures of DTC's automated tender
offer program system.
Any notice of withdrawal must:
- specify the name of the person who tendered the Old Notes to be withdrawn
and
- identify the Old Notes to be withdrawn, including the principal amount of
the Old Notes.
If Old Notes have been tendered pursuant to the procedure for book-entry
transfer described above, any notice of withdrawal must specify the name and
number of the account at DTC to be credited with the withdrawn Old Notes and
otherwise comply with the procedures of DTC.
We will determine all questions as to validity, form, eligibility and time
of receipt of any withdrawal notices. Our determination will be final and
binding on all parties. We will deem any Old Notes so withdrawn not to have been
validly tendered for exchange for purposes of the exchange offer.
Any Old Notes that have been tendered for exchange but that are not
exchanged for any reason will be returned to their holder without cost to the
holder or, in the case of Old Notes tendered by book-entry transfer into the
exchange agent's account at DTC according to the procedures described above,
such Old
38
Notes will be credited to an account maintained with DTC for the Old Notes. This
return or crediting will take place as soon as practicable after withdrawal,
rejection of tender or termination of the exchange offer. You may retender
properly withdrawn Old Notes by following one of the procedures described under
"-- Procedures for Tendering Old Notes" at any time on or prior to the
expiration date.
CONDITIONS OF THE EXCHANGE OFFER
Notwithstanding any other provisions of the exchange offer, if, on or prior
to the expiration date, we determine, in our reasonable judgment, that the
exchange offer, or the making of an exchange by a holder of Old Notes, would
violate applicable law or any applicable interpretation of the staff of the SEC,
we will not be required to accept for exchange, or to exchange, any tendered Old
Notes. We may also terminate, waive any conditions to or amend the exchange
offer or, subject to Rule 14e-1 under the Exchange Act, which requires that an
offeror pay the consideration offered or return the securities deposited by or
on behalf of the holders thereof promptly after the termination or withdrawal of
the exchange offer, or postpone the acceptance for exchange of tendered Old
Notes.
TRANSFER TAXES
We will pay all transfer taxes applicable to the transfer and exchange of
Old Notes pursuant to the exchange offer. If, however:
- delivery of the New Notes and/or certificates for Old Notes for principal
amounts not exchanged, are to be made to any person other than the record
holder of the Old Notes tendered;
- tendered certificates for Old Notes are recorded in the name of any
person other than the person signing any letter of transmittal; or
- a transfer tax is imposed for any reason other than the transfer and
exchange of Old Notes to us or our order,
the amount of any such transfer taxes, whether imposed on the record holder or
any other person, will be payable by the tendering holder prior to the issuance
of the New Notes.
CONSEQUENCES OF FAILING TO EXCHANGE
If you do not exchange your Old Notes for New Notes in the exchange offer,
you will remain subject to the restrictions on transfer of the Old Notes:
- as set forth in the legend printed on the Old Notes as a consequence of
the issuance of the Old Notes pursuant to the exemptions from, or in
transactions not subject to, the registration requirements of the
Securities Act and applicable state securities laws; and
- otherwise set forth in the offering circular distributed in connection
with the private offering of the Old Notes.
In general, you may not offer or sell the Old Notes unless they are
registered under the Securities Act, or if the offer or sale is exempt from
registration under the Securities Act and applicable state securities laws.
Except as required by the registration rights agreement, we do not intend to
register resales of the Old Notes under the Securities Act.
ACCOUNTING TREATMENT
The New Notes will be recorded at the same carrying value as the Old Notes,
as reflected in our accounting records on the date of the exchange. Accordingly,
we will not recognize any gain or loss for accounting purposes upon the
consummation of the exchange offer. We will amortize the expenses of the
exchange offer over the term of the exchange notes.
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EXCHANGE AGENT
Wilmington Trust Company has been appointed as exchange agent for the
exchange offer. You should direct questions and requests for assistance,
requests for additional copies of this prospectus, the letter of transmittal or
any other documents to the exchange agent. You should send certificates for Old
Notes, letters of transmittal and any other required documents to the exchange
agent addressed as follows:
WILMINGTON TRUST COMPANY
By Overnight Delivery: By Mail: By Hand Delivery:
1100 North Market St. DC 1615 Reorg Services (9:00 a.m. - 5:00 p.m.
Wilmington, DE 19890-1615 P.O. Box 8861 New York City Time)
Attn: Aubrey Rosa Wilmington, DE 19899-8861 1100 North Market St.
Corporate Trust Reorg Services Attn: Aubrey Rosa Wilmington, DE 19890-1615
Corporate Trust Reorg Services Attn: Aubrey Rosa
Corporate Trust Reorg Services
By Facsimile:
(302) 636-4145
Confirm receipt of facsimile
by telephone:
(302) 636-6472
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DESCRIPTION OF THE NOTES
The New Notes will be issued, and the Old Notes were issued, under an
indenture dated as of July 21, 2003 between us and Wilmington Trust Company, as
trustee. This summary is qualified in its entirety by reference to the
indenture, a copy of which is available from the trustee upon request. The terms
of the notes include those stated in the indenture and made a part thereof by
reference to the Trust Indenture Act of 1939, as amended, in effect on the date
of the indenture. This summary of the material terms of the notes and the
indenture does not purport to be complete and is subject to, and is qualified in
its entirety by reference to, the indenture, including the definitions of
certain terms therein, and the Trust Indenture Act. We have included at the end
of this section a summary of capitalized terms used in this section. Terms used
in this section and not otherwise defined in this section have the respective
meanings assigned to them in the indenture.
For purposes of this "Description of the Notes" section, when we refer to
"El Paso Natural Gas," "us," "we," "our," or "ours," we are describing El Paso
Natural Gas Company and not its subsidiaries.
GENERAL
The notes:
- are our unsecured indebtedness ranking equally in right of payment with
all of our existing and future unsecured and unsubordinated indebtedness;
- are senior in right of payment to any future subordinated indebtedness;
- are effectively junior to our secured indebtedness to the extent of
assets securing such indebtedness;
- are effectively junior to all existing and future indebtedness and other
liabilities of our subsidiaries; and
- are not guaranteed by our subsidiaries or our parent.
At June 30, 2003, after giving pro forma effect to the issuance of the Old
Notes, we would have had outstanding approximately $1,315 million of capital
market debt, all of which was senior unsecured indebtedness, $11 million in
guarantees and $4 million in letters of credit.
We are a designated borrower under El Paso's $3 billion revolving credit
facility, which matures in June 2005. We are only liable for the amounts we
borrow under the $3 billion facility. As of June 30, 2003, $1.5 billion was
outstanding and $1.1 billion in letters of credit were issued under the $3
billion facility, none of which were borrowed by or issued on behalf of us.
Our direct subsidiary, Sabine, is one of 17 subsidiary guarantors of El
Paso's $3 billion facility. In connection with its guarantee of this facility,
Sabine pledged its equity interest in each of EPNG Mojave, Inc. and El Paso
Mojave Pipeline Co., its sole assets, to collateralize that facility. In
addition, in connection with its guarantee of El Paso's $3 billion facility, our
direct parent El Paso EPNG Investments, L.L.C. pledged its equity interest in us
to collateralize that facility. As a result, our ownership is subject to a
change in control if El Paso's lenders under the $3 billion facility are
required to exercise rights over their collateral. El Paso EPNG Investments'
equity in us and Sabine's equity interest in EPNG Mojave, Inc. and El Paso
Mojave Pipeline Co. also collateralize approximately $1 billion of other
financing arrangements, including leases, letters of credit and other
facilities. For purposes of this "Description of the Notes," this $1 billion of
other financings is referred to as the "Other Financings."
PRINCIPAL, MATURITY AND INTEREST
The notes will mature on August 1, 2010. We may issue additional notes of
this series from time to time in the future which would contain the same terms
and the same CUSIP numbers as the notes offered hereby, without the consent of
the holders of the notes, in compliance with the covenants of the indenture.
41
Interest on the notes will:
- accrue at the rate of 7 5/8% per year;
- be payable semiannually on each February 1 and August 1, commencing
February 1, 2004;
- be payable to the person in whose name the notes are registered at the
close of business on the relevant January 15 and July 15 preceding the
applicable interest payment date;
- be computed on the basis of a 360-day year comprised of twelve 30-day
months; and
- be payable on overdue interest to the extent permitted by law at the same
rate as interest is payable on principal.
If any interest payment date, maturity date or redemption date falls on a
day that is not a business day, the payment will be made on the next business
day (and without any interest or other payment in respect of such delay) with
the same force and effect as if made on the relevant interest payment date,
maturity date or redemption date. Unless we default on a payment, no interest
will accrue for the period from and after the applicable maturity date or
redemption date.
DENOMINATIONS
The notes will be issued in registered form in denominations of $1,000 each
or integral multiples thereof.
OPTIONAL REDEMPTION OF NOTES
The notes will be redeemable, in whole or in part, at our option at any
time in whole, or from time to time in part, prior to August 1, 2007, at the
Make-Whole Price, in accordance with the provisions of the indenture.
The notice of redemption will set forth the manner of calculation of the
Make-Whole Price but not necessarily its amount. We will notify the trustee of
the amount of the Make-Whole Price and the trustee shall not be responsible for
the accuracy of the calculation.
The notes will be redeemable, in whole or in part, at our option at any
time in whole, or from time to time in part, on or after August 1, 2007, at the
following redemption prices (expressed as percentages of principal amount), plus
accrued and unpaid interest and liquidated damages, if any, to the applicable
redemption date, if redeemed during the 12-month period commencing on each
August 1 of the years indicated below:
REDEMPTION YEAR PERCENTAGE
--------------- ----------
2007..................................................... 103.813%
2008..................................................... 101.906%
2009 and thereafter...................................... 100.000%
We will mail a notice of redemption by first class mail at least 30 but not
more than 60 days before the redemption date to each holder of notes to be
redeemed at the holder's registered address.
In the case of any partial redemption, selection of the notes for
redemption will be made by the trustee on a pro rata basis, by lot or by any
other method that the trustee in its sole discretion will deem to be fair and
appropriate, although no note of less than $1,000 in original principal amount
will be redeemed in part. If any note is to be redeemed in part only, the notice
of redemption relating to that note will state the portion of the principal
amount of that note to be redeemed. A new note in principal amount equal to the
unredeemed portion of that note will be issued in the name of the holder of the
note upon cancellation of the original note.
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SINKING FUND
We are not required to make mandatory redemption or sinking fund payments
with respect to the notes.
CONSOLIDATION, MERGER OR SALE OF ASSETS
Under the indenture, we may not consolidate with or merge into any other
person or sell, lease or transfer all or substantially all of our properties and
assets to any other person unless:
- in the case of a merger, we are the surviving entity, or the person
formed by the consolidation or into which we are merged expressly
assumes, by execution and delivery to the trustee of a supplemental
indenture, the due and punctual payment of the principal, any premium and
interest on the notes and the performance of every covenant and condition
in the indenture;
- in the case of the sale, lease or transfer of all or substantially all of
our properties and assets, the person which acquires our properties and
assets expressly assumes, by execution and delivery to the trustee of a
supplemental indenture, the due and punctual payment of the principal,
any premium and interest on the notes and the performance of every
covenant and condition in the indenture;
- immediately after giving effect to the transaction, no default or event
of default under the indenture exists; and
- we have delivered to the trustee an officer's certificate and an opinion
of counsel each stating that the consolidation, merger, sale, transfer or
lease and the supplemental indenture required in connection with the
transaction comply with the terms of the indenture and that we have
complied with all conditions precedent.
Notwithstanding the foregoing, any of our restricted subsidiaries may
consolidate with, merge into or transfer all or part of its properties and
assets to us or any other of our restricted subsidiaries.
After any consolidation or merger or any sale, lease or transfer of all or
substantially all our properties and assets, the successor person formed by such
consolidation or into which we are merged or to which such sale, lease or
transfer is made shall succeed to and be substituted for us under the indenture
as if the successor person had been originally named in the indenture and may
exercise every one of our rights and powers under the indenture. Thereafter,
except in the case of a lease, we shall be relieved of all obligations and
covenants under the indenture and the notes.
COVENANTS
Limitation on Liens. The indenture provides that we will not, nor will we
permit any restricted subsidiary to, create, assume, incur or suffer to exist
any lien upon any Principal Property, whether owned or leased on the date of the
indenture or thereafter acquired, to secure any of our Indebtedness or of any
other person (other than the notes), without causing all of the notes
outstanding under the indenture to be secured equally and ratably with, or prior
to, the new Indebtedness so long as the new Indebtedness is so secured. This
restriction does not, however, prohibit us from creating the following:
- liens existing on the date of the indenture or created under an
"after-acquired property" clause;
- purchase price liens created within one year after purchase;
- liens already existing on newly acquired property or assets;
- liens already existing on the property or assets of a new restricted
subsidiary;
- liens already on property or assets when acquired by us or a restricted
subsidiary, or when we or a restricted subsidiary acquire the owner of
the property or asset;
- liens securing construction or improvements incurred prior to or up to
one year after completion;
43
- liens on oil, gas, mineral and processing and other plant properties to
secure costs associated with the properties and their exploration,
development, maintenance or operation;
- liens connected with our conveyance (including conveyances by our
restricted subsidiaries) of a production payment relating to oil, gas,
natural gas or other natural resources;
- liens in favor of us or our restricted subsidiaries;
- liens connected to the issuance of a tax-exempt debt to acquire or
construct property or assets;
- liens of a foreign restricted subsidiary to secure its Indebtedness;
- Permitted Liens;
- liens upon additions, improvements, replacements, repairs, fixtures,
appurtenances or component parts attaching to or required to be attached
to property or assets under the terms of any mortgage, pledge agreement,
security agreement or other similar instrument, creating a lien upon such
property or assets permitted above; or
- any extension, renewal, refinancing, refunding or replacement (or
successive extensions, renewals, refinancing, refundings or replacements)
of any lien, in whole or in part, that is referred to above, or of any
Indebtedness which it secures; provided, that the principal amount of the
Indebtedness secured shall not exceed the greater of the principal amount
of Indebtedness secured at the time of such extension, renewal,
refinancing, refunding or replacement and the original principal amount
of Indebtedness secured (plus in each case the aggregate amount of
premiums, other payments, costs and expenses required to be paid or
incurred in connection with such extension, renewal, refinancing,
refunding or replacement); and further provided, that such extension,
renewal, refinancing, refunding or replacement shall be limited to all or
a part of the property (including improvements, alterations and repairs
on such property) subject to the encumbrance so extended, renewed,
refinanced, refunded or replaced (plus improvements, alterations and
repairs on such property).
In addition, this limitation on liens does not apply to other liens, not
otherwise excepted above, provided that the aggregate principal amount of all
Indebtedness then outstanding secured by such other liens together with all net
sale proceeds from Sale-Leaseback Transactions (other than the permitted Sale-
Leaseback Transactions discussed below) does not exceed 15% of our Consolidated
Net Tangible Assets.
Limitation on Sale-Leaseback Transactions. The indenture also provides
that we will not, nor will we permit any restricted subsidiary to, engage in a
Sale-Leaseback Transaction, unless:
- such Sale-Leaseback Transaction occurs within one year from the date of
acquisition of the Principal Property subject thereto or the date of the
completion of construction or commencement of full operations on such
Principal Property, whichever is later;
- the Sale-Leaseback Transaction involves a lease for a period, including
renewals, of not more than three years;
- we or such restricted subsidiary would be entitled to incur Indebtedness
secured by a lien on the Principal Property subject thereto in a
principal amount equal to or exceeding the net sale proceeds from such
Sale-Leaseback Transaction without securing the notes; or
- we or such restricted subsidiary, within a one-year period after such
Sale-Leaseback Transaction, applies or causes to be applied an amount not
less than the net sale proceeds from such Sale-Leaseback Transaction to
(1) the repayment, redemption or retirement of our Funded Debt or Funded
Debt of such restricted subsidiary, or (2) investment in another
Principal Property.
In addition, this limitation on Sale-Leaseback Transactions does not apply
to other Sale-Leaseback Transactions, not otherwise excepted above, provided
that the net sale proceeds from such other Sale-Leaseback Transactions together
with the aggregate principal amount of outstanding Indebtedness secured
44
by liens upon any Principal Property (other than that Indebtedness secured by
liens excepted from the limitation on liens as discussed above) does not exceed
15% of our Consolidated Net Tangible Assets.
Limitation on Restricted Payments. The indenture also provides that we
will not, and will not cause or permit any of our restricted subsidiaries to,
directly or indirectly, make any Restricted Payment if at the time of that
Restricted Payment and immediately after giving effect to that Restricted
Payment:
(1) a default or event of default will have occurred and be continuing
or would result from that Restricted Payment;
(2) we are not able to incur an additional $1.00 of Debt pursuant to
the Consolidated Debt to EBITDA Ratio test under "Covenants - Limitation on
Incurrence of Debt"; or
(3) the aggregate amount of the Restricted Payment and all other
Restricted Payments declared or made subsequent to the date the notes are
first issued would exceed the sum of:
(a) 100% of our Operating Cash Flow accrued subsequent to January
1, 2003 to the most recent date for which financial information is
available to us, taken as one accounting period (or if the aggregate
amount of Operating Cash Flow for such period shall be a deficit, minus
100% of such deficit); plus
(b) 100% of the aggregate net proceeds, including the net fair
market value of property or securities other than cash as determined by
our board of directors in good faith, received subsequent to the date
the notes are first issued from any person, other than one of our
subsidiaries, from (x) the issue or sale of our Equity Interests (other
than Disqualified Capital Stock) (including, without limitation, in a
merger, consolidation, acquisition of property or any other form of
transaction to the extent the consideration involved consists of Capital
Stock (other than Disqualified Capital Stock)) or (y) the issue or sale
of our Disqualified Capital Stock or debt securities of ours or those of
any of our restricted subsidiaries that have been converted into or
exchanged for our Equity Interests (other than Disqualified Capital
Stock) (including, without limitation, in a merger, consolidation,
acquisition of property or any other form of transaction to the extent
the consideration involved consists of Capital Stock (other than
Disqualified Capital Stock)) subsequent to the date the notes are first
issued; plus
(c) an amount equal to the sum, without duplication, of:
(i) the net reduction in Investments (other than Permitted
Investments) made by us or any of our restricted subsidiaries in any
person resulting from repurchases, repayments or redemptions of that
Investment by that person;
(ii) proceeds realized on the sale of that Investment to an
unaffiliated purchaser; and
(iii) proceeds representing the return of capital (excluding
dividends and distributions),
in each case received by us or any of our subsidiaries; plus
(d) an amount equal to the sum without limitation, of any amounts,
including the net fair market value of property other than cash as
determined by our board of directors in good faith, received by us or
any of our subsidiaries as a capital contribution (including, without
limitation, in a merger, consolidation, acquisition of property or any
other form of transaction to the extent the consideration involved
consists of Capital Stock (other than Disqualified Capital Stock))
subsequent to the date the notes are first issued; plus
(e) $150 million.
The provisions of the first paragraph of this "Limitation on Restricted
Payments" covenant will not prohibit:
(1) the payment of any dividend or the making of any distribution
within 60 days after the date of its declaration if the dividend or
distribution would have been permitted on the date it is declared;
45
(2) the purchase, redemption or other acquisition or retirement of any
of our Capital Stock or any warrants, options or other rights to acquire
shares of any of that Capital Stock either:
(a) solely in exchange for shares of Qualified Capital Stock or
other warrants, options or rights to acquire Qualified Capital Stock.
(b) through the application of the net proceeds of a substantially
concurrent sale for cash, other than to one of our subsidiaries, of
shares of Qualified Capital Stock or warrants, options or other rights
to acquire Qualified Capital Stock, or
(c) in the case of Disqualified Capital Stock, solely in exchange
for, or through the application of the net proceeds of a substantially
concurrent sale for cash, other than to one of our subsidiaries, of
Disqualified Capital Stock;
(3) repurchases of Capital Stock, warrants, options or rights to
acquire Capital Stock deemed to occur upon exercise of warrants, options or
rights to acquire Capital Stock if such Capital Stock, warrants, options or
rights represent a portion of the exercise price of such warrants, options
or rights;
(4) payments or distributions, directly or indirectly through any
direct or indirect parent of ours, to dissenting stockholders pursuant to
applicable law or in connection with the settlement or other satisfaction
of legal claims made pursuant to or in connection with a consolidation,
merger or transfer of assets;
(5) cash payments in lieu of the issuance of fractional shares;
(6) payments of dividends, distributions or other amounts by us to
fund the payment by any of our direct or indirect parent companies or other
Affiliates of administrative, legal, financial, accounting or other similar
expenses relating to such parent's direct or indirect ownership of us and
to pay other corporate overhead expenses relating to such ownership
interest, including directors' fees, indemnifications and similar
arrangements, so long as such payments are fair and reasonable and are paid
as and when needed by any such direct or indirect parent company;
(7) any transfers by us or any of our restricted subsidiaries pursuant
to the cash management program of El Paso and its subsidiaries consistent
with past practices;
(8) any payment, guarantee or other similar arrangement by us or any
of our subsidiaries in connection with, related to or arising from the
Western Energy Settlement; and
(9) any payment, guarantee or other similar arrangement by us or any
of our subsidiaries in connection with, related to or arising from El
Paso's $3 billion revolving credit facility and/or the Other Financings;
and any extension, renewal, refinancing, refunding or replacement (or
successive extensions, renewals, refinancing, refundings or replacements)
(a "Refinancing") of El Paso's $3 billion revolving credit facility and/or
the Other Financings; provided, however, that El Paso Natural Gas shall not
make any payment, guarantee or other similar arrangement jointly and
severally with El Paso in connection with a Refinancing of El Paso's $3
billion revolving credit facility subsequent to the date that is the later
of (i) August 19, 2003 and (ii) the date on which we are no longer jointly
and severally liable for any amounts outstanding under El Paso's $3 billion
revolving credit facility.
In determining the aggregate amount of Restricted Payments made subsequent
to the date the notes are first issued, amounts expended pursuant to clauses (1)
and (5) shall be included in such calculation.
The amount of all Restricted Payments (other than cash) shall be the fair
market value on the date of such Restricted Payment of the asset(s) or
securities proposed to be paid, transferred or issued by us or any of our
restricted subsidiaries, as the case may be, pursuant to such Restricted
Payment. The fair market value of any non-cash Restricted Payment shall be
determined conclusively by our board of directors acting in good faith.
46
This covenant will be of no force or effect from and after the time the
notes are first rated at least Baa3 by Moody's and at least BBB- by Standard &
Poor's.
Limitation on Incurrence of Debt. The indenture also provides that we will
not, and will not permit any of our restricted subsidiaries to, directly or
indirectly, create, incur, issue, assume, guaranty or otherwise become directly
or indirectly liable with respect to, contingently or otherwise (collectively,
"incur"), any Debt (including Acquired Debt), unless (1) no default or event of
default would occur after giving effect on a pro forma basis to such incurrence,
and (2) the Consolidated Debt to EBITDA Ratio on the date on which such
additional Debt is incurred would have been less than 6.0 to 1, determined on a
pro forma basis giving effect to such incurrence (including a pro forma
application of the net proceeds therefrom).
The limitation of the foregoing paragraph shall not prohibit the incurrence
of:
(1) performance bonds, appeal bonds, surety bonds, insurance
obligations or bonds and other similar bonds or obligations incurred in the
ordinary course of business,
(2) Hedging Obligations,
(3) Debt owed by (a) any of our restricted subsidiaries to us or to
any of our other subsidiaries or (b) us to any of our subsidiaries,
(4) Debt outstanding on the date of the indenture, including the notes
and Debt in connection with, related to or arising from El Paso's $3
billion revolving credit facility and/or the Other Financings and any
Refinancing of El Paso's $3 billion revolving credit facility and/or the
Other Financings; provided, however, that El Paso Natural Gas shall not
incur any Debt jointly and severally with El Paso in connection with a
Refinancing of El Paso's $3 billion revolving credit facility subsequent to
the date that is the later of (i) August 19, 2003 and (ii) the date on
which we are no longer jointly and severally liable for any amounts
outstanding under El Paso's $3 billion revolving credit facility,
(5) Debt issued in exchange for, or the proceeds of which are used to
Refinance Debt including, without limitation, Acquired Debt, incurred
pursuant to the Consolidated Debt to EBITDA Ratio test set forth above or
under clause (4) above or this clause (5) (collectively "Refinancing
Debt"); provided, that (a) the principal amount of such Refinancing Debt
does not exceed the principal amount of Debt so Refinanced (plus the
premiums and other amounts to be paid, and the out-of-pocket expenses
reasonably incurred, in connection therewith) and (b) the Refinancing Debt
has a Weighted Average Life to Maturity that is equal to or greater than
the Weighted Average Life to Maturity, of the Debt being Refinanced,
(6) the guarantee by us or one or more of our restricted subsidiaries
of Debt of us or one or more of our restricted subsidiaries that is not
prohibited by another provision of the indenture, or
(7) other Debt in an aggregate principal amount at any one time
outstanding not to exceed $150 million.
In addition, (1) we will not, directly or indirectly, incur any guarantee
with respect to any Debt of any of our Affiliates (other than Debt of El Paso
Natural Gas, one or more subsidiaries of El Paso Natural Gas or of El Paso
Natural Gas and one or more of its subsidiaries) and (2) we will not permit any
of our restricted subsidiaries to, directly or indirectly, incur any guarantee
with respect to any Debt of any of our Affiliates (other than Debt of El Paso
Natural Gas, one or more subsidiaries of El Paso Natural Gas, of El Paso Natural
Gas and one or more of its subsidiaries, Debt in connection with, related to or
arising from El Paso's $3 billion revolving credit facility or any Refinancing
thereof, or Debt outstanding on the date of the indenture in connection with the
Other Financings or any Refinancing thereof).
This covenant will be of no force or effect from and after the time the
notes are first rated at least Baa3 by Moody's and at least BBB- by Standard &
Poor's.
47
Limitation on Participation in El Paso's Cash Management Program. The
indenture also provides that we will not, and will not permit any of our
restricted subsidiaries to, directly or indirectly, participate in El Paso's and
its subsidiaries' cash management program if any default occurs or exists under
any bond, debenture, note or other evidence of Debt for money borrowed or under
any mortgage, indenture or instrument under which there may be issued or by
which there may be secured or evidenced any Debt for money borrowed, in each
case, by El Paso or any of its subsidiaries (or the payment of which is
guaranteed by El Paso or any of its subsidiaries) whether such Debt or guarantee
now exists, or is created after the date of the indenture, if such default:
(1) is caused by a failure to pay principal of, or interest or
premium, if any, on such Debt of El Paso prior to the expiration of the
grace period provided in such Debt of El Paso on the date of such default
(a "Payment Default"); or
(2) results in the acceleration (without cure or revocation within
five business days) of Debt of El Paso prior to its express maturity
and, in each case, the principal amount of any such Debt of El Paso, together
with the principal amount of any other such Debt of El Paso under which there
has been a Payment Default or the maturity of which has been so accelerated,
aggregates $50 million or more, until such acceleration has been cured or
revoked or such payment of such Debt of El Paso has been made in full.
This covenant will be of no force or effect from and after the time the
notes are first rated at least Baa3 by Moody's and at least BBB- by Standard &
Poor's.
Limitation on Transactions with Affiliates. The indenture also provides
that we will not, and will not permit any restricted subsidiary to, directly or
indirectly, enter into or suffer to exist any transaction or series of related
transactions (including the purchase, sale, transfer, assignment, lease,
conveyance or exchange of any property or the rendering of any service) with, or
for the benefit of, any of our Affiliates (an "Affiliate Transaction"), unless:
(1) the terms of such Affiliate Transaction are:
(a) set forth in writing and
(b) no less favorable to us or such restricted subsidiary, as the
case may be, than those that could be obtained in a comparable
arm's-length transaction with a person that is not one of our Affiliates
or, if there is no such comparable transaction, on terms that are fair
and reasonable to us or such restricted subsidiary,
(2) if such Affiliate Transaction involves aggregate payments or value
in excess of $25 million, our board of directors approves such Affiliate
Transaction and, in its good faith judgment, believes that such Affiliate
Transaction complies with clause (1)(b) of this paragraph, and
(3) if such Affiliate Transaction involves aggregate payments or value
in excess of $100 million, we obtain a written opinion from an Independent
Financial Advisor to the effect that the consideration to be paid or
received in connection with such Affiliate Transaction is fair, from a
financial point of view, to us or the applicable restricted subsidiary, as
the case may be.
Notwithstanding the preceding limitation, the following shall not be
Affiliate Transactions:
(1) any transaction or series of related transactions between us and
one or more subsidiaries or between two or more subsidiaries;
(2) any Restricted Payment permitted to be made pursuant to the
covenant described under "Covenants - Limitation on Restricted Payments" or
any Permitted Investment;
(3) any employment agreement or other employee compensation plan or
arrangement entered into by us or any of our restricted subsidiaries in the
ordinary course of business;
48
(4) indemnities of our or any of our restricted subsidiaries'
officers, directors and employees permitted by bylaw or statutory
provisions;
(5) the payment of reasonable and customary regular fees to our or any
of our restricted subsidiaries' directors;
(6) Affiliate Transactions and arrangements in effect on the issue
date of the notes, including any modifications, extensions or renewals
thereof that do not adversely affect us or any of our restricted
subsidiaries;
(7) Affiliate Transactions in connection with, related to or arising
from the Western Energy Settlement, provided, that our board of directors
shall approve any amendment, supplement or modification of the Western
Energy Settlement on terms that are fair and reasonable to us; and
(8) Affiliate Transactions in connection with, related to or arising
from El Paso's $3 billion revolving credit facility and/or the Other
Financings and any Refinancing of El Paso's $3 billion revolving credit
facility and/or the Other Financings.
This covenant will be of no force or effect from and after the time the
notes are first rated at least Baa3 by Moody's and at least BBB- by Standard &
Poor's.
EVENTS OF DEFAULT
"Event of default" when used in the indenture will mean any of the
following:
(1) failure to pay interest or liquidated damages, if any, on any note
for a period of 30 days;
(2) failure to pay the principal of or premium, if any, on any note
when due;
(3) failure to perform any other covenant in the indenture that
continues for 60 days after receiving written notice;
(4) if we (a) commence a voluntary bankruptcy case, (b) consent to the
entry of any order for relief against us in an involuntary case, (c)
consent to the appointment of a custodian of us or for all or substantially
all of our property, or (d) make a general assignment for the benefit of
our creditors;
(5) if a court of competent jurisdiction enters an order or decree
under any bankruptcy law that (a) is for relief against us in an
involuntary case, (b) appoints a custodian of us or for all or
substantially all of our property, or (c) orders the liquidation of us; and
the order or decree remains unstayed and in effect for 90 days; or
(6) if there shall be a default under any bond, debenture, note or
other evidence of debt for money borrowed or under any mortgage, indenture
or other instrument under which there may be issued or by which there may
be secured or evidenced any debt for money borrowed by us or any of our
restricted subsidiaries or under any guarantee of payment by us or any of
our restricted subsidiaries of debt for money borrowed (other than a
default under any debt of El Paso or one or more subsidiaries of El Paso
(other than us or any of our restricted subsidiaries) guaranteed by one or
more of our restricted subsidiaries), whether such debt or guarantee now
exists or shall hereafter be created, and the effect of such default is to
cause such debt to become due prior to its stated maturity; provided,
however, that no default under this clause (6) shall exist if all such
defaults do not relate to such debt or such guarantees with an aggregate
principal amount in excess of $25 million at the time outstanding; and a
default under this clause (6) shall no longer exist after any such default
is cured or waived;
If an event of default (other than an event of default specified in clause
(4) or (5) above) occurs and is continuing, the trustee or the holders of at
least 25% in principal amount of the notes then outstanding may declare the
principal of, premium, if any, on, accrued and unpaid interest on, and
liquidated damages, if any, on all the notes then outstanding (if not then due
and payable) to be due and payable immediately. If an event of default specified
in clause (4) or (5) above occurs, the principal of, premium, if any, on,
49
accrued and unpaid interest on, and liquidated damages, if any, on, all notes
then outstanding shall ipso facto become immediately due and payable without any
declaration or other act on the part of the trustee or any noteholder. Subject
to certain conditions, the holders of a majority in principal amount of the
notes then outstanding by notice to the trustee may void the declaration.
The indenture provides that the holders of the notes will indemnify the
trustee before the trustee exercises any of its rights or powers under the
indenture. This indemnification is subject to the trustee's duty to act with the
required standard of care during a default. The holders of a majority in
aggregate principal amount of the outstanding notes may direct the time, method
and place of:
- conducting any proceeding for any remedy available to the trustee, or
- exercising any trust or power conferred on the trustee.
This right of the holders of the notes is, however, subject to the
provisions in the indenture providing for the indemnification of the trustee and
other specified limitations.
In general, the indenture provides that holders of the notes may only
institute an action against us under the indenture if the following four
conditions are fulfilled:
- the holder previously has given to the trustee written notice of default
and the default continues;
- the holders of at least 25% in principal amount of the notes then
outstanding have both (1) requested the trustee to institute such action
and (2) offered the trustee indemnity satisfactory to it;
- the trustee has not instituted such action within 60 days of receipt of
such request; and
- the trustee has not received direction inconsistent with such written
request by the holders of a majority in principal amount of the notes
then outstanding.
However, the right of any holder of the notes to receive payment of
principal of, and premium, if any, and interest on the notes, on or after the
respective due dates expressed in the notes, or to bring suit for the
enforcement of any such payment on or after such respective dates, is absolute
and unconditional and will not be impaired or affected without the consent of
such holder. The indenture contains a covenant that we will file annually with
the trustee a certificate of no default or a certificate specifying any default
that exists.
MODIFICATION OF INDENTURE
Without the consent of any holder, we and the trustee may amend or
supplement the indenture or the notes to:
- cure any ambiguity, omission, defect or inconsistency;
- comply with the indenture in the case of the merger, consolidation or
sale or other disposition of all or substantially all of our assets;
- provide for uncertificated notes in addition to or in place of
certificated notes;
- add any additional events of default;
- provide for the acceptance of a successor trustee;
- secure the notes pursuant to the requirements under the indenture;
- comply with any requirements in order to effect or maintain the
qualification of the indenture under the Trust Indenture Act of 1939;
- comply with any requirements of the SEC in connection with qualifying the
indenture under the Trust Indenture Act of 1939;
50
- add to our covenants for the benefit of the holders of notes or surrender
any power conferred upon us; or
- make any change that does not adversely affect the rights of any holder
of notes in any material respect.
We and the trustee may amend or supplement the indenture or the notes with
the written consent of the holders of at least a majority in principal amount of
the notes then outstanding. These changes must conform to the Trust Indenture
Act of 1939. In addition, notwithstanding the above, without the consent of each
holder affected, we may not:
- reduce the percentage of principal amount of notes whose holders must
consent to an amendment, supplement or waiver;
- reduce the rate of or change the time for payment of interest, including
default interest, on any note;
- reduce the principal of or change the fixed maturity of any note or alter
the premium or other provisions with respect to redemption;
- make any note payable in money or in a place other than that stated in
the note;
- impair the right to institute suit for the enforcement of any payment of
principal of, or premium, if any, or interest on any note;
- make any change in the percentage of principal amount of notes necessary
to waive compliance with certain provisions of the indenture; or
- waive a continuing default or event of default in the payment of
principal of, or premium, if any, or interest on the notes.
DEFINITIONS
The following are definitions of some terms used in the above covenant
descriptions:
"Acquired Debt" means, with respect to any specified person, (1) Debt of
any other person existing at the time such other person is merged with or into
or became a restricted subsidiary of such specified person, including, without
limitation, Debt incurred in connection with, or in contemplation of, such other
person merging with or into or becoming a restricted subsidiary of such
specified person, and (2) Debt secured by a lien encumbering any asset acquired
by such specified person.
"Affiliate" of any specified person means any other person directly or
indirectly controlling or controlled by or under direct or indirect common
control with such specified person. For the purposes of this definition,
"control" when used with respect to any person means the power to direct the
management and policies of such person, directly or indirectly, whether through
the ownership of voting securities, by contract or otherwise; and the terms
"controlling" and "controlled" have meanings correlative to the preceding.
"Capital Stock" means:
(1) with respect to any person that is a corporation, any and all
shares of corporate stock of that person;
(2) with respect to any person that is an association or business
entity, any and all shares, interests, participations, rights or other
equivalents, however designated, of capital stock of that person;
(3) with respect to any person that is a partnership or limited
liability company, any and all partnership or membership interests, whether
general or limited, of that person; and
(4) with respect to any other person, any other interest or
participation that confers on a person the right to receive a share of the
profits and losses of or distributions of assets of, the issuing person.
51
"Capitalized Lease Obligation" means Debt represented by obligations under
a lease that is required to be capitalized for financial reporting purposes in
accordance with GAAP and the amount of such Debt shall be the capitalized amount
of such obligations determined in accordance with GAAP.
"Commodity Agreement" means, in respect to any person, any forward
contract, commodity swap agreement, commodity option agreement or other similar
agreement or arrangement designed to protect such person against fluctuation in
commodity prices.
"Comparable Treasury Issue" means the United States Treasury security
selected by an Independent Investment Banker as having a maturity comparable to
the remaining term of the notes to be redeemed that would be utilized, at the
time of selection and in accordance with customary financial practice, in
pricing new issues of corporate debt securities of comparable maturity to the
remaining term of the notes.
"Comparable Treasury Price" means, with respect to any redemption date, (1)
the average of four Reference Treasury Dealer Quotations for such redemption
date, after excluding the highest and lowest of such Reference Treasury Dealer
Quotations, or (2) if the trustee obtains fewer than four such Reference
Treasury Dealer Quotations, the average of all such Reference Treasury Dealer
Quotations.
"Consolidated Debt" means, as of any date of determination, the total,
without duplication, of all of our Debt and all Debt of our restricted
subsidiaries outstanding on such date, after eliminating all offsetting debits
and credits between us and our restricted subsidiaries and all other items
required to be eliminated in the course of the preparation of consolidated
financial statements of us and our restricted subsidiaries in accordance with
GAAP.
"Consolidated Debt to EBITDA Ratio" means, with respect to any incurrence
of Debt on any date, the ratio of (1) Consolidated Debt as of such date to (2)
the Consolidated EBITDA of us and our restricted subsidiaries for our most
recently ended four full fiscal quarters for which internal financial statements
are available immediately preceding the date of such incurrence of Debt.
Notwithstanding any other provision, for purposes of making the computation
referred to above, acquisitions that have been made by us or any of our
restricted subsidiaries, including all mergers and consolidations, subsequent to
the commencement of such period shall be calculated on a pro forma basis,
assuming that all such acquisitions, mergers and consolidations had occurred on
the first day of such period.
"Consolidated EBITDA" means, with respect to any person (the referent
person) for any period, Consolidated Net Income of such person for such period,
determined in accordance with GAAP, plus (to the extent such amounts are
deducted in calculating such Consolidated Net Income of such person for such
period, and without duplication) (1) Consolidated Interest Expense of such
person for such period, (2) any provision for taxes based on income or profits
of such person and its restricted subsidiaries to the extent such income or
profits were included in calculating such Consolidated Net Income of such person
for such period, and (3) amortization, depreciation and other non-cash charges
(including, without limitation, amortization of goodwill, deferred financing
fees and other intangibles but excluding (a) cash payments against such non-cash
charges during such period, (b) cash payments against non-cash charges from a
prior period but subsequent to the date of the indenture and (c) normally
recurring accruals such as reserves against accounts receivable); provided,
however, if there is a default under any Debt of El Paso or one or more
subsidiaries of El Paso (other than us or any of our restricted subsidiaries)
guaranteed by one or more of our restricted subsidiaries, and the effect of such
default is to cause, or with the passage of time or the giving of notice or both
would cause such Debt to become due prior to its stated maturity, then our
Consolidated EBITDA shall not include the Consolidated EBITDA of such restricted
subsidiary until such default is cured or waived.
"Consolidated Interest Expense" means, for any period, the total interest
expense of us and our restricted subsidiaries determined on a consolidated basis
in accordance with GAAP.
"Consolidated Net Income" means, with respect to any person for any period,
the aggregate of the Net Income of such person and its restricted subsidiaries
for such period, determined on a consolidated basis in accordance with GAAP;
provided that (1) the Net Income (but not loss) of any person that is not a
restricted subsidiary or that is accounted for by the equity method of
accounting shall be included
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only to the extent of the amount of dividends or distributions paid in cash to
the referent person or a restricted subsidiary thereof, (2) the Net Income of
any restricted subsidiary shall be excluded to the extent that the declaration
or payment of dividends or similar distributions by that restricted subsidiary
of that Net Income is not at the date of determination permitted without any
prior governmental approval (that has not been obtained) or, directly or
indirectly, by operation of the terms of its charter or any agreement,
instrument, judgment, decree, order, statute, rule or governmental regulation
applicable to that restricted subsidiary or its stockholders, (3) the Net Income
of any person acquired in a pooling of interests transaction for any period
prior to the date of such acquisition shall be excluded and (4) the cumulative
effect of a change in accounting principles shall be excluded; provided,
further, if there is a default under any Debt of El Paso or one or more
subsidiaries of El Paso (other than us or any of our restricted subsidiaries)
guaranteed by one or more of our restricted subsidiaries, and the effect of such
default is to cause, or with the passage of time or the giving of notice or both
would cause such Debt to become due prior to its stated maturity, then our
Consolidated Net Income shall not include the Net Income of such restricted
subsidiary until such default is cured or waived.
"Consolidated Net Tangible Assets" means, at any date of determination, the
total amount of assets after deducting therefrom (1) all current liabilities
(excluding (a) any current liabilities that by their terms are extendable or
renewable at the option of the obligor thereon to a time more than 12 months
after the time as of which the amount thereof is being computed, and (b) current
maturities of long-term debt), and (2) the value (net of any applicable
reserves) of all goodwill, trade names, trademarks, patents and other like
intangible assets, all as set forth on the consolidated balance sheet of us and
our consolidated subsidiaries for our most recently completed fiscal quarter,
prepared in accordance with GAAP.
"Currency Agreement" means in respect of a person any foreign exchange
contract, currency swap agreement or other similar agreement as to which such
person is a party or a beneficiary.
"Debt" means (1) any liability of any person (a) for borrowed money, (b)
evidenced by a note, debenture or similar instrument (including a purchase money
obligation) given in connection with the acquisition of any property or assets
(other than inventory or similar property acquired in the ordinary course of
business), including securities, or (c) for the payment of money relating to a
Capitalized Lease Obligation; (2) any guarantee by any person of any liability
of others described in the preceding clause (1); and (3) any amendment, renewal,
extension or refunding of any liability of the types referred to in clauses (1)
and (2) above. Notwithstanding anything to the contrary in the foregoing, Debt
shall not include: (x) any liability of or any guarantee or similar arrangement
by us or any of our subsidiaries of El Paso's or El Paso Merchant Energy's
obligations in connection with, related to or arising out of the Western Energy
Settlement, (y) any of our or any of our subsidiaries' Debt incurred pursuant to
a cash management program of El Paso and its subsidiaries or (z) in order to
avoid double counting, a guarantee described in clause (2) of any liability
described in clause (1) if such liability has been included in the determination
of Debt.
"Disqualified Capital Stock" means any Capital Stock that, by its terms or
by the terms of any security into which it is convertible or for which it is
exchangeable, or upon the happening of any event,
(1) matures (excluding any maturity as the result of an optional
redemption by the issuer of that Capital Stock);
(2) is mandatorily redeemable, pursuant to a sinking fund obligation
or otherwise; or
(3) is redeemable at the sole option of its holder,
in whole or in part, on or prior to the final maturity date of the notes;
provided, however, that only the portion of Capital Stock that so matures or is
mandatorily redeemable or is so redeemable at the sole option of its holder
prior to the final maturity date of the notes will be deemed Disqualified
Capital Stock.
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"Equity Interests" means Qualified Capital Stock and all warrants, options
or other rights to acquire Qualified Capital Stock, but excluding any debt
security that is convertible into, or exchangeable for, Qualified Capital Stock.
"Funded Debt" means all Indebtedness maturing one year or more from the
date of the creation thereof, all Indebtedness directly or indirectly renewable
or extendible, at the option of the debtor, by its terms or by the terms of any
instrument or agreement relating thereto, to a date one year or more from the
date of the creation thereof, and all Indebtedness under a revolving credit or
similar agreement obligating the lender or lenders to extend credit over a
period of one year or more.
"GAAP" means generally accepted accounting principles set forth in the
opinions and pronouncements of the Accounting Principles Board of the American
Institute of Certified Public Accountants and statements and pronouncements of
the Financial Accounting Standards Board or in such other statements by such
other entity as have been approved by a significant segment of the accounting
profession, which are in effect from time to time.
"guarantee" means any obligation, contingent or otherwise, of any person
directly or indirectly guaranteeing any Debt of any other person and any
obligation, direct or indirect, contingent or otherwise, of such person (1) to
purchase or pay (or advance or supply funds for the purchase or payment of) such
Debt of such other person (whether arising by virtue of partnership
arrangements, or by agreement to keep-well, to purchase assets, goods,
securities or services, to take-or-pay, or to maintain financial statement
conditions or otherwise) or (2) entered into for purposes of assuring in any
other manner the obligee of such Debt of the payment thereof or to protect such
obligee against loss in respect thereof (in whole or in part); provided,
however, that the term "guarantee" shall not include endorsements for collection
of deposit in the ordinary course of business or any guarantee, direct or
indirect, contingent or otherwise, in connection with the Western Energy
Settlement.
"Hedging Obligations" of any person means the obligations of such person
pursuant to any Interest Rate Agreement, Commodity Agreement or Currency
Agreement.
"Indebtedness" means any obligation created or assumed by any person for
the repayment of money borrowed and any purchase money obligation created or
assumed by such person. Notwithstanding the foregoing, Indebtedness shall not
include any of our or any of our subsidiaries' Indebtedness incurred pursuant to
the cash management program of El Paso and its subsidiaries.
"Independent Financial Advisor" means an investment banking firm of
national standing or any third party appraiser that is determined by our board
of directors to be reasonably competent to issue an opinion or valuation with
respect to the matter for which it has been engaged; provided that such firm or
appraiser is not one of our Affiliates.
"Independent Investment Banker" means Citigroup Global Markets Inc. or
Credit Suisse First Boston LLC and their respective successors, at our option,
or, if such firms or the successors, if any, to such firms, as the case may be,
are unwilling or unable to select the Comparable Treasury Issue, an independent
investment banking institution of national standing appointed by us.
"Interest Rate Agreement" means with respect to any person any interest
rate protection agreement, interest rate future agreement, interest rate option
agreement, interest rate swap agreement, interest rate cap agreement, interest
rate collar agreement, interest rate hedge agreement or other similar agreement
or arrangement as to which such person is a party or a beneficiary.
"Investment" in any person means any direct or indirect advance, loan
(other than advances to customers in the ordinary course of business) or other
extension of credit (including by way of guarantee or similar arrangement, but
excluding any debt or extension of credit represented by a bank deposit other
than a time deposit) or capital contribution to (by means of any transfer of
cash or other property to other persons or any payment for property or services
for the account or use of other persons), or any purchase or acquisition of
Capital Stock, Debt or other similar instruments issued by such person.
54
"Make-Whole Price" means an amount equal to the greater of:
(1) 100% of the principal amount of the notes to be redeemed; and
(2) as determined by an Independent Investment Banker, the sum of the
present values of (a) the redemption price of the notes at August 1, 2007
(as set forth below) and (b) the remaining scheduled payments of interest
from the redemption date to August 1, 2007 (not including any portion of
such payments of interest accrued as of the redemption date) discounted
back to the redemption date on a semi-annual basis (assuming a 360-day year
consisting of twelve 30-day months) at the Treasury Rate (as defined below)
plus 75 basis points,
plus, in the case of both (1) and (2), accrued and unpaid interest and
liquidated damages, if any, to the redemption date. Unless we default in payment
of the Make-Whole Price, on and after the applicable redemption date, interest
will cease to accrue on the notes to be redeemed.
"Moody's" means Moody's Investors Service, Inc. or any successor to the
rating agency business of Moody's Investors Service, Inc.
"Net Income" means, with respect to any person, the net income (loss) of
such person, determined in accordance with GAAP and before any reduction in
respect of dividends on Preferred Stock, excluding, however, (1) any gain (but
not loss), together with any related provision for taxes on such gain (but not
loss), realized in connection with (a) any asset sale (except in the ordinary
course of business) (including, without limitation, dispositions pursuant to
Sale-Leaseback Transactions) or (b) the disposition of any securities by such
person or any of its subsidiaries, (2) any extraordinary or nonrecurring gain
(but not loss), together with any related provision for taxes on such
extraordinary or nonrecurring gain (but not loss) and (3) the settlement expense
related to the Western Energy Settlement, together with any related provision
for taxes.
"Operating Cash Flow" means, with respect to any person for any period, the
Consolidated EBITDA of such person for such period, less aggregate maintenance
capital expenditures of such person, and its restricted subsidiaries for such
period determined in accordance with GAAP, less any taxes paid in cash by such
person based on income or profits of such person and its restricted subsidiaries
to the extent such income or profits were included in calculating Consolidated
Net Income for purposes of calculating Consolidated EBITDA of such person for
such period, less Consolidated Interest Expense of such person for such period;
provided, however, if there is a default under any Debt of El Paso or one or
more subsidiaries of El Paso (other than us or any of our restricted
subsidiaries) guaranteed by one or more of our restricted subsidiaries, and the
effect of such default is to cause, or with the passage of time or the giving of
notice or both would cause such Debt to become due prior to its stated maturity,
then our Operating Cash Flow shall not include the Operating Cash Flow of such
restricted subsidiary until such default is cured or waived.
"Permitted Investment" means an Investment by us or any of our restricted
subsidiaries in:
(1) cash or cash equivalents;
(2) an Investment existing on the date of the indenture, including any
Investment in connection with, related to or arising out of the Western
Energy Settlement;
(3) receivables owing to us or any of our restricted subsidiaries, if
created or acquired in the ordinary course of business and payable or
dischargeable in accordance with customary trade terms;
(4) payroll, travel and similar advances to cover matters that are
expected at the time of such advances ultimately to be treated as expenses
for accounting purposes and that are made in the ordinary course of
business;
(5) stock, obligations or securities received in settlement of debts
created in the ordinary course of business and owing to us or any of our
restricted subsidiaries or in satisfaction of judgments or claims or
pursuant to any plan of reorganization or similar arrangement upon the
bankruptcy or insolvency of a debtor;
55
(6) Hedging Obligations;
(7) prepayments and other credits made in the ordinary course of
business;
(8) Investments in connection with pledges, deposits, payments or
performance bonds made or given in the ordinary course of business in
connection with or to secure statutory, regulatory or similar obligations,
including obligations under health, safety or environmental obligations;
(9) us or a subsidiary, including guarantees of our subsidiaries'
Debt;
(10) another person if as a result of such Investment such other
person becomes a subsidiary of us or is merged or consolidated with or
into, or transfers or conveys all or substantially all its assets to, us or
one of our subsidiaries; and
(11) any person engaged in the business of transportation, storage,
gathering, marketing or sale of natural gas and/or petroleum products
and/or businesses reasonably related thereto.
"Permitted Liens" means (1) liens upon rights-of-way for pipeline purposes;
(2) any governmental lien, mechanics', materialmen's, carriers' or similar lien
incurred in the ordinary course of business which is not yet due or which is
being contested in good faith by appropriate proceedings and any undetermined
lien which is incidental to construction; (3) the right reserved to, or vested
in, any municipality or public authority by the terms of any right, power,
franchise, grant, license, permit or by any provision of law, to purchase or
recapture or to designate a purchaser of, any property; (4) liens of taxes and
assessments which are (a) for the then current year, (b) not at the time
delinquent, or (c) delinquent but the validity of which is being contested at
the time by El Paso Natural Gas or any subsidiary in good faith; (5) liens of,
or to secure performance of, leases; (6) any lien upon, or deposits of, any
assets in favor of any surety company or clerk of court for the purpose of
obtaining indemnity or stay of judicial proceedings; (7) any lien upon property
or assets acquired or sold by El Paso Natural Gas or any restricted subsidiary
resulting from the exercise of any rights arising out of defaults on
receivables; (8) any lien incurred in the ordinary course of business in
connection with workmen's compensation, unemployment insurance, temporary
disability, social security, retiree health or similar laws or regulations or to
secure obligations imposed by statute or governmental regulations; (9) any lien
upon any property or assets in accordance with customary banking practice to
secure any Indebtedness incurred by El Paso Natural Gas or any restricted
subsidiary in connection with the exporting of goods to, or between, or the
marketing of goods in, or the importing of goods from, foreign countries; (10)
any lien in favor of the United States of America or any state thereof, or any
other country, or any political subdivision of any of the foregoing, to secure
partial, progress, advance, or other payments pursuant to any contract or
statute, or any lien securing industrial development, pollution control, or
similar revenue bonds; (11) any lien in connection with, related to or arising
out of the Western Energy Settlement or (12) any lien in connection with,
related to or arising out of El Paso's $3 billion revolving credit facility and
any extension, renewal, refinancing, refunding or replacement (or successive
extensions, renewals, refinancing, refundings or replacements) of El Paso's $3
billion revolving credit facility.
"Preferred Stock" means any capital stock or other equity interests of a
person, however designated, which entitles the holder thereof to a preference
with respect to the payment of dividends, or as to the distribution of assets
upon any voluntary or involuntary liquidation or dissolution of such person,
over shares of any other class of capital stock or other equity interests issued
by such person.
"Principal Property" means (1) any pipeline assets of El Paso Natural Gas
or any subsidiary, including any related facilities employed in the
transportation, distribution or marketing of natural gas, that is located in the
United States or Canada, and (2) any processing or manufacturing plant owned or
leased by El Paso Natural Gas or any subsidiary and located within the United
States or Canada, except, in the case of either clause (1) or (2), any such
assets or plant which, in the opinion of the Board of Directors, is not material
in relation to the activities of El Paso Natural Gas and its Subsidiaries as a
whole.
"Qualified Capital Stock" means any Capital Stock that is not Disqualified
Capital Stock.
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"Reference Treasury Dealer" means Citigroup Global Markets Inc. or Credit
Suisse First Boston LLC, at our option, and three additional primary U.S.
government securities dealers in New York City (each a "Primary Treasury
Dealer") selected by us, and their respective successors (provided, however,
that if any such firm or any such successor, as the case may be, shall cease to
be a primary U.S. government securities dealer in New York City, we shall
substitute therefor another Primary Treasury Dealer).
"Reference Treasury Dealer Quotations" means, with respect to each
Reference Treasury Dealer and any redemption date, the average, as determined by
the trustee, of the bid and asked prices for the Comparable Treasury Issue
(expressed in each case as a percentage of its principal amount) quoted in
writing to the trustee by such Reference Treasury Dealer at 5:00 p.m., New York
City time, on the third business day preceding such redemption date.
"Restricted Payment" means:
(1) the declaration or payment of any dividend or the making of any
other distribution (other than dividends or distributions payable solely in
Qualified Capital Stock or in options, rights or warrants to acquire
Qualified Capital Stock) on shares of our Capital Stock;
(2) the declaration or payment of any dividend or the making of any
other distribution on shares of the Capital Stock of a restricted
subsidiary to any person (other than (a) to us or any of our subsidiaries,
(b) dividends or distributions made by a restricted subsidiary on a pro
rata basis to all stockholders of such restricted subsidiary (or owners of
an equivalent interest in the case of a restricted subsidiary that is not a
corporation) or (c) dividends or distributions payable solely in its
Qualified Capital Stock or in options, rights or warrants to acquire our
Qualified Capital Stock);
(3) the purchase, redemption, retirement or other acquisition for
value of any of our Capital Stock held by persons other than us or one of
our subsidiaries (other than in exchange for our Qualified Capital Stock or
options, rights or warrants to acquire Qualified Capital Stock); or
(4) the making of any Investment (other than a Permitted Investment)
in any person.
"restricted subsidiary" means any subsidiary of El Paso Natural Gas owning
or leasing any Principal Property.
"Sale-Leaseback Transaction" means the sale or transfer by El Paso Natural
Gas or any restricted subsidiary of any Principal Property to a person (other
than El Paso Natural Gas or a subsidiary) and the taking back by El Paso Natural
Gas or any restricted subsidiary, as the case may be, of a lease of such
Principal Property.
"Treasury Rate" means, with respect to any redemption date, (1) the yield,
under the heading which represents the average for the immediately preceding
week, appearing in the most recently published statistical release designated
"H.15(519)" or any successor publication that is published weekly by the Board
of Governors of the Federal Reserve System and that establishes yields on
actively traded United States Treasury securities adjusted to constant maturity
under the caption "Treasury Constant Maturities," for the maturity corresponding
to the Comparable Treasury Issue (if no maturity is within three months before
or after the stated maturity, yields for the two published maturities most
closely corresponding to the Comparable Treasury Issue shall be determined, and
the Treasury Rate shall be interpolated or extrapolated from such yields on a
straight-line basis, rounding to the nearest month) or (2) if such release (or
any successor release) is not published during the week preceding the
calculation date or does not contain such yields, the rate per annum equal to
the semi-annual equivalent yield to maturity of the Comparable Treasury Issue,
calculated using a price for the Comparable Treasury Issue (expressed as a
percentage of its principal amount) equal to the Comparable Treasury Price for
such redemption date. The Treasury Rate shall be calculated on the third
business day preceding the redemption date.
"Weighted Average Life to Maturity" means, when applied to any Debt at any
date, the number of years obtained by dividing (1) the sum of the products
obtained by multiplying (a) the amount of each then remaining installment,
sinking fund, serial maturity or other required payments of principal, including
57
payment at final maturity, in respect thereof, by (b) the number of years
(calculated to the nearest one-twelfth) that will elapse between such date and
the making of such payment, by (2) the then outstanding principal amount of such
Debt.
"Western Energy Settlement" means the agreement in principle, dated March
20, 2003, by and among El Paso, its affiliates and various public and private
claimants, including the states of California, Washington, Oregon and Nevada,
and the definitive settlement agreements entered into on June 23, 2003 in
connection therewith, to resolve the principal litigation, claims and regulatory
proceedings against El Paso and its affiliates relating to the sale or delivery
of natural gas and electricity from September 1996 to the date of such
settlement, (i) as in effect on the issue date of the notes and (ii) any
amendment, supplement or modification thereof.
DEFEASANCE
We can discharge or defease our obligations under the indenture as set
forth below.
Pursuant to the terms of the indenture, we may discharge certain
obligations to holders of the notes which have not already been delivered to the
trustee for cancellation. These notes must also:
- have become due and payable;
- be due and payable by their terms within one year; or
- be scheduled for redemption by their terms within one year.
We may discharge the notes by irrevocably depositing an amount certified to
be sufficient to pay at maturity or upon redemption the principal of and
interest on and any liquidated damages with respect to the notes. We may make
the deposit in cash or U.S. government obligations.
We may also, upon satisfaction of the conditions listed below, discharge
certain obligations to holders of the notes at any time ("Defeasance"). Pursuant
to the terms of the indenture, we may be released from the obligations imposed
by the restrictive covenants described above. Also under terms set forth in the
indenture, we may omit to comply with these sections without creating an event
of default ("Covenant Defeasance"). Defeasance or Covenant Defeasance may be
effected only if, among other things:
- we irrevocably deposit with the trustee cash or U.S. government
obligations as trust funds in an amount certified to be sufficient to pay
at maturity or upon redemption the principal of and interest on all
outstanding notes; and
- we deliver to the trustee an opinion of counsel to the effect that the
holders of the notes will not recognize income, gain or loss for United
States federal income tax purposes as a result of such Defeasance or
Covenant Defeasance. The opinion must further state that these holders
will be subject to United States federal income tax on the same amounts,
in the same manner and at the same times as would have been the case if
Defeasance or Covenant Defeasance had not occurred. In the case of a
Defeasance, this opinion must be based on a ruling of the Internal
Revenue Service or a change in United States federal income tax law
occurring after the date of the indenture, since this result would not
occur under current tax law.
METHODS OF RECEIVING PAYMENTS ON THE NOTES
If a holder has given wire transfer instructions to us, we will make all
payments of principal of, premium, if any, and interest and liquidated damages
(as defined below under the caption "Exchange Offer and Registration Rights"),
if any, on the notes in accordance with those instructions. All other payments
on these notes will be made at the office or agency of the paying agent and
registrar within the City and State of New York unless we elect to make interest
payments by check mailed to the holders at their address set forth in the
security register.
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PAYING AGENT AND REGISTRAR FOR THE NOTES
The trustee will initially act as paying agent and registrar. We may change
the paying agent or registrar without prior notice to the holders of the notes,
and we may act as paying agent or registrar.
SAME-DAY SETTLEMENT AND PAYMENT
Settlement for the notes will be made by the initial purchasers in
immediately available funds. So long as DTC continues to make its settlement
system available to us, all payments of principal of and premium, if any,
interest and liquidated damages, if any, on the global securities will be made
by us in immediately available funds.
TRANSFER AND EXCHANGE
Subject to the restrictions set forth under the caption "Transfer
Restrictions," a holder may transfer or exchange notes in accordance with the
indenture. The registrar and the trustee may require a holder, among other
things, to furnish appropriate endorsements and transfer documents and we may
require a holder to pay any taxes and fees required by law or permitted by the
indenture. In addition, we are not required to transfer or exchange any note
between a record date and the next succeeding interest payment date.
The registered holder of a note will be treated as its owner for all
purposes.
GOVERNING LAW
The indenture and the notes will be governed by and construed in accordance
with the laws of the State of New York.
NOTICES
Notices to holders of the notes will be given by mail to the addresses of
such holders as they appear in the security register.
NO PERSONAL LIABILITY OF OFFICERS, DIRECTORS, EMPLOYEES OR STOCKHOLDERS
No director, officer, employee or stockholder, as such, of us or any of our
affiliates will have any personal liability in respect of our obligations under
the indenture or the notes by reason of his, her or its status as such.
CONCERNING THE TRUSTEE
Wilmington Trust Company is the trustee under the indenture. In the
ordinary course of business, Wilmington Trust Company and its affiliates have
provided and may in the future continue to provide trust services and other
financial services to us and our subsidiaries for which they have received and
will receive compensation.
UNITED STATES FEDERAL INCOME TAX CONSEQUENCES
Except where otherwise stated, the following discussion constitutes the
opinion of Locke Liddell & Sapp LLP as to the material United States federal
income tax consequences of exchanging Old Notes for New Notes and owning and
disposing of New Notes. This discussion is not a complete discussion of all the
potential tax consequences that may be relevant to you. This discussion is based
upon the Internal Revenue Code of 1986, as amended (the Code), its legislative
history, existing and proposed regulations thereunder, published rulings, and
court decisions, all as in effect on the date of this document, and all of which
are subject to change, possibly on a retroactive basis. Unless otherwise
indicated, this discussion
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deals only with notes held as a capital asset by a holder who is a United States
person and purchased the Old Notes upon original issuance at their original
issue price. A "United States person" is:
- a citizen or resident of the United States or any political subdivision
thereof;
- a corporation, or a partnership or other entity that is treated as a
corporation or partnership for United States federal income tax purposes,
that is created or organized in the United States or under the laws of
the United States or of any state thereof including the District of
Columbia;
- an estate whose income is subject to United States federal income
taxation regardless of its source; or
- a trust if a United States court 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 or it was in existence on August 19, 1996, and has elected to be
treated as a United States person.
Your tax treatment may vary depending on your particular situation. This
discussion does not address all of the tax consequences that may be relevant to
holders that are subject to special tax treatment, such as:
- dealers in securities or currencies;
- financial institutions;
- tax-exempt investors;
- traders in securities that elect to use a mark-to-market method of
accounting for their securities holdings;
- persons liable for alternative minimum tax;
- insurance companies;
- real estate investment trusts;
- regulated investment companies;
- persons holding notes as part of a hedging, conversion, integrated or
constructive sale transaction or a straddle;
- United States persons whose functional currency is not the United States
dollar;
- partners in a partnership, or other entity treated as a partnership for
United States federal income tax purposes, that holds notes;
- controlled foreign corporations;
- foreign personal holding companies;
- corporations that accumulate earnings to avoid United States federal
income tax; or
- United States expatriates.
We urge you to consult your own tax advisors regarding your particular
United States federal tax consequences of exchanging, holding and disposing of
notes, as well as any tax consequences that may arise under the laws of any
relevant foreign, state, local, or other taxing jurisdiction or under any
applicable tax treaty.
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RECEIPT OF NEW NOTES
Your exchange of Old Notes for New Notes under the exchange offer will not
constitute a taxable exchange of the Old Notes. As a result:
- you will not recognize taxable gain or loss when you receive New Notes in
exchange for Old Notes;
- your holding period in the New Notes will include your holding period in
the Old Notes; and
- your basis in the New Notes will equal your adjusted basis in the Old
Notes at the time of the exchange.
TAXATION OF INTEREST
Interest paid on the New Notes generally will be taxable to you as ordinary
interest income at the time payments are accrued or received in accordance with
your regular method of accounting for United States federal income tax purposes.
SALE OR OTHER TAXABLE DISPOSITION OF NEW NOTES
You must recognize taxable gain or loss on the sale, exchange, redemption,
retirement or other taxable disposition of a New Note. The amount of your gain
or loss equals the difference between the amount you receive for the New Note in
cash or other property, valued at the fair market value, minus the amount
attributable to accrued qualified stated interest on the New Note, if any, and
your adjusted tax basis in the New Note. Your initial tax basis in a New Note
equals the price you paid for the Old Note that you exchanged for the New Note
reduced by any payments other than payments of qualified stated interest made on
the notes.
Your gain or loss will generally be a long-term capital gain or loss if
your holding period in the New Note is more than one year. Otherwise, it will be
a short-term capital gain or loss. Payments attributable to accrued qualified
stated interest that you have not yet included in income will be taxed as
ordinary interest income.
NON-UNITED STATES HOLDERS
The following discussion applies to Non-United States Holders. You are a
"Non-United States Holder" if you are not a United States person.
Exchange of Old Notes
Your exchange of Old Notes for New Notes under the exchange offer will not
constitute a taxable exchange of the Old Notes, and the consequences of the
exchange to you will be the same as those of a United States person described
above under the heading "-- Receipt of New Notes."
Interest
Interest that we pay to you will not be subject to United States federal
income tax and withholding of United States federal income tax will not be
required on interest payments if you:
- do not actually or constructively own 10% or more of the total combined
voting power of all classes of our stock;
- are not a controlled foreign corporation with respect to which we are a
related person;
- are not a bank whose receipt of interest is described in Section
881(c)(3)(A) of the Code; and
- you certify to us, our payment agent, or the person who would otherwise
be required to withhold United States tax, on Form W-8BEN (or applicable
substitute form), under penalties of perjury, that you are not a United
States person and provide your name and address.
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If you do not satisfy the preceding requirements, your interest on a note would
generally be subject to United States withholding tax at a flat rate of 30% (or
a lower applicable treaty rate).
If you are engaged in a trade or business in the United States, and if
interest on a note is effectively connected with the conduct of that trade or
business (or in the case of an applicable tax treaty, is attributable to a
permanent establishment maintained by you in the United States), you will be
exempt from United States withholding tax but will be subject to regular United
States federal income tax on the interest in the same manner as if you were a
United States person. See "-- Taxation of Interest." In order to establish an
exemption from United States withholding tax, you may provide to us, our payment
agent or the person who would otherwise be required to withhold United States
tax, a properly completed and executed IRS Form W-8ECI (or applicable substitute
form). In addition to regular United States federal income tax, if you are a
foreign corporation, you may be subject to a United States branch profits tax.
Gain on Disposition
You generally will not be subject to United States federal income tax with
respect to gain recognized on a sale, redemption, exchange or other disposition
of a note unless:
- the gain is effectively connected with the conduct by you of a trade or
business within the United States, or, under an applicable tax treaty, is
attributable to a permanent establishment maintained by you in the United
States; or
- if you are an individual, you are present in the United States for 183 or
more days in the taxable year and certain other requirements are met.
Applicable Tax Treaties
This discussion does not address any benefits you may receive under any
applicable tax treaties. You should consult with your own tax advisor as to any
applicable income tax treaties that may provide for a lower rate of withholding
tax, exemption from, or a reduction of, branch profits tax, or other rules
different from the general rules under United States federal income tax laws.
INFORMATION REPORTING AND BACKUP WITHHOLDING
United States Persons
In general, information reporting requirements may apply to payments made
to you and to the proceeds of a disposition of the notes, unless you are an
exempt recipient such as a corporation. Backup withholding may apply if you fail
to supply an accurate taxpayer identification number or otherwise fail to comply
with applicable United States information reporting or certification
requirements. Any amounts withheld under the backup withholding rules will be
allowed as a refund or a credit against your United States federal income tax
liability provided the required information is furnished to the Internal Revenue
Service.
Non-United States Holders
Backup withholding and information reporting will not apply to payments of
principal or interest on the notes by us or our paying agent to you if you
certify as to your status as a Non-United States Holder under penalties of
perjury or otherwise establish an exemption (provided that neither we nor our
paying agent has actual knowledge that you are a United States person or that
the conditions of any other exemptions are not in fact satisfied).
The payment of the proceeds of the disposition of notes to or through the
United States office of a United States or foreign broker will be subject to
information reporting and backup withholding unless you provide the
certification described above or otherwise establish an exemption. The proceeds
of a disposition effected outside the United States by you of notes to or
through a foreign office of a broker generally will not be subject to backup
withholding or information reporting. However, if that broker is a United States
62
person, a controlled foreign corporation for United States tax purposes, a
foreign person 50% or more of whose gross income from all sources for certain
periods is effectively connected with a trade or business in the United States,
or a foreign partnership that is engaged in the conduct of a trade or business
in the United States or that has one or more partners that are United States
persons who in the aggregate hold more than 50% of the income or capital
interests in the partnership, information reporting requirements will apply
unless that broker has documentary evidence in its files of your status as a
Non-United States Holder and has no actual knowledge to the contrary or unless
you otherwise establish an exemption.
You should consult your tax advisors regarding the application of
information reporting and backup withholding to your particular situation, the
availability of an exemption therefrom, and the procedure for obtaining such an
exemption, if available. Any amounts withheld from a payment to you under the
backup withholding rules will be allowed as a credit against your United States
federal income tax liability and may entitle you to a refund, provided you
furnish the required information to the Internal Revenue Service.
ERISA CONSIDERATIONS
If you intend to use plan assets to exchange for any of the New Notes
offered by this prospectus, you should consult with counsel on the potential
consequences of your investment under the fiduciary responsibility provisions of
the Employee Retirement Income Security Act of 1974, as amended ("ERISA"), and
the prohibited transaction provisions of ERISA. If you intend to use
governmental or church plan assets to exchange for any of the New Notes, you
should consult with counsel on the potential consequences of your investment
under similar provisions applicable under laws governing governmental and church
plans.
The following summary is based on the provisions of ERISA and the Code and
related guidance in effect as of the date of this prospectus. This summary does
not attempt to be a complete summary of these considerations. Future
legislation, court decisions, administrative regulations or other guidance will
change the requirements summarized in this section. Any of these changes could
be made retroactively and could apply to transactions entered into before the
change is enacted.
FIDUCIARY RESPONSIBILITIES
ERISA imposes requirements on (1) employee benefit plans subject to ERISA,
(2) entities whose underlying assets include employee benefit plan assets, for
example, collective investment funds and insurance company general accounts, and
(3) fiduciaries of employee benefit plans. Under ERISA, fiduciaries generally
include persons who exercise discretionary authority or control over plan
assets. Before investing any employee benefit plan assets in any note offered in
connection with this prospectus, you should determine whether the investment:
(1) is permitted under the plan document and other instruments
governing the plan; and
(2) is appropriate for the plan in view of its overall investment
policy and the composition and diversification of its portfolio, taking
into account the limited liquidity of the notes.
You should consider all factors and circumstances of a particular
investment in the notes, including, for example, the risk factors discussed in
"Risk Factors" and the fact that in the future there may not be a market in
which you will be able to sell or otherwise dispose of your interest in the
notes.
We are not making any representation that the sale of any notes to a plan
meets the fiduciary requirements for investment by plans generally or any
particular plan or that such an investment is appropriate for plans generally or
any particular plan.
PROHIBITED TRANSACTIONS
ERISA and the Code prohibit a wide range of transactions involving (1)
employee benefit plans and arrangements subject to ERISA and/or the Code, and
(2) persons who have specified relationships to the
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plans. These persons are called "parties in interest" under ERISA and
"disqualified persons" under the Code. The transactions prohibited by ERISA and
the Code are called "prohibited transactions." If you are a party in interest or
disqualified person who engages in a prohibited transaction, you may be subject
to excise taxes and other penalties and liabilities under ERISA and/or the Code.
As a result, if you are considering using plan assets to invest in any of the
notes offered for sale in connection with this prospectus, you should consider
whether the investment might be a prohibited transaction under ERISA and/or the
Code.
Prohibited transactions may arise, for example, if the notes are acquired
by a plan with respect to which we, or any of our affiliates, are a party in
interest or a disqualified person. Exemptions from the prohibited transaction
provisions of ERISA and the Code may apply depending in part on the type of plan
fiduciary making the decision to acquire a note and the circumstances under
which such decision is made. Some of these exemptions include:
(1) Prohibited transaction class exemption or "PTCE" exemptions 75-1
(relating to specified transactions involving employee benefit plans and
broker-dealers, reporting dealers and banks).
(2) PTCE 84-14 (relating to specified transactions directed by
independent qualified professional asset managers);
(3) PTCE 90-1 (relating to specified transactions involving insurance
company pooled separate accounts);
(4) PTCE 91-38 (relating to specified transactions by bank collective
investment funds);
(5) PTCE 95-60 (relating to specified transactions involving insurance
company general accounts); and
(6) PTCE 96-23 (relating to specified transactions directed by
in-house asset managers);
These exemptions do not, however, provide relief from the self-dealing
prohibitions under ERISA and the Code. In addition, there is no assurance that
any of these class exemptions or other exemption will be available with respect
to any particular transaction involving the notes.
TREATMENT OF NOTES AS DEBT INSTRUMENTS
Some transactions involving our operations could give rise to prohibited
transactions under ERISA and the Code if our assets were deemed to be plan
assets. Pursuant to Department of Labor Regulations Section 2510.3-101 (which we
refer to as the "plan assets regulations"), in general, when a plan acquires an
"equity interest" in an entity such as El Paso Natural Gas, the plan's assets
include both the equity interest and an undivided interest in each of the
underlying assets of the entity unless exceptions set forth in the plan assets
regulations apply.
In general, an "equity interest" is defined under the plan assets
regulations as any interest in an entity other than an instrument which is
treated as indebtedness under applicable local law and which has no substantial
equity features. Although there is very little published authority concerning
the application of this definition, we believe that the notes should be treated
as debt rather than equity interest under the plan assets regulations because
the notes (1) should be treated as indebtedness under applicable local law and
debt, rather than equity, for United States tax purposes and (2) should not be
deemed to have any "substantial equity features." However, no assurance can be
given that the notes will be treated as debt for purposes of ERISA. If the notes
were to be treated as an equity interest under the plan assets regulations, the
purchase of the notes using plan assets could cause our assets to become subject
to the fiduciary and prohibited transaction provisions of ERISA and the Code
unless investment in the notes by "benefit plan investors" is not "significant,"
as determined under the plan assets regulations. We cannot assure you that the
criteria for this exception will be satisfied at any particular time and no
monitoring or other measures will be taken to determine whether such criteria
are met. This means that, if the notes are treated as equity interests under the
plan asset regulations and investment in the notes by benefit plan investors is
64
significant, our assets could be treated as plan assets subject to ERISA and a
non-exempt prohibited transaction could arise in connection with our operating
activities.
Any insurance company proposing to invest assets of its general account in
the notes should consider the implications of the U.S. Supreme Court's decision
in John Hancock Mutual Life Insurance Co. v. Harris Trust and Savings Bank, 510
U.S. 86, 114 S. Ct. 517 (1993), which, in some circumstances, treats such
general account as including the assets of a plan that owns a policy or other
contract with such insurance company, as well as the effect of Section 401(c) of
ERISA, as interpreted by regulations proposed by the Department of Labor.
GOVERNMENT AND CHURCH PLANS
Governmental plans and some church plans, while not subject to the
fiduciary responsibility provisions of ERISA or the prohibited transactions
provisions of ERISA or the Code, may be subject to state or other federal laws
that are very similar to the provisions of ERISA and the Code. If you are a
fiduciary of a governmental or church plan, you should consult with counsel
before purchasing any notes offered for sale in connection with this prospectus.
FOREIGN INDICIA OF OWNERSHIP
ERISA also prohibits plan fiduciaries from maintaining the indicia of
ownership of any plan assets outside the jurisdiction of the United States
district courts except in specified cases. Before investing in any note offered
for sale in connection with this prospectus, you should consider whether the
acquisition, holding or disposition of a note would satisfy such indicia of
ownership rules.
REPRESENTATIONS AND WARRANTIES
If you acquire or accept a note offered in connection with this prospectus,
you will be deemed to have represented and warranted that either:
(1) you have not used plan assets to acquire such note; or
(2) your acquisition and holding of a note (A) is exempt from the
prohibited transaction restrictions of ERISA and the Code under one or more
prohibited transaction class exemptions or does not constitute a prohibited
transaction under ERISA and the Code, and (B) meets the fiduciary
requirements of ERISA.
GLOBAL SECURITIES; BOOK-ENTRY SYSTEM
THE GLOBAL SECURITIES
The notes will initially be represented by one or more permanent global
notes in definitive, fully registered book-entry form (the "global securities")
which will be registered in the name of Cede & Co., as nominee of DTC and
deposited on behalf of purchasers of the notes represented thereby with a
custodian for DTC for credit to the respective accounts of the purchasers (or to
such other accounts as they may direct) at DTC.
We expect that pursuant to procedures established by DTC (a) upon deposit
of the global securities, DTC or its custodian will credit on its internal
system portions of the global securities which will contain the corresponding
respective amount of the global securities to the respective accounts of persons
who have accounts with such depositary and (b) ownership of the notes will be
shown on, and the transfer of ownership thereof will be affected only through,
records maintained by DTC or its nominee (with respect to interests of
participants (as defined below) and the records of participants (with respect to
interests of persons other than participants). Such accounts initially will be
designated by or on behalf of Credit Suisse First Boston LLC, the initial
purchaser, and ownership of beneficial interests in the global securities will
be limited to persons who have accounts with DTC (the "participants") or persons
who hold interests
65
through participants. Noteholders may hold their interests in a global security
directly through DTC if they are participants in such system, or indirectly
through organizations which are participants in such system.
So long as DTC or its nominee is the registered owner or holder of any of
the notes, DTC or such nominee will be considered the sole owner or holder of
such notes represented by such global securities for all purposes under the
indenture and under the notes represented thereby. No beneficial owner of an
interest in the global securities will be able to transfer such interest except
in accordance with the applicable procedures of DTC in addition to those
provided for under the indenture and, if applicable, those of the Euroclear
System ("Euroclear") and Clearstream Banking, societe anonyme, Luxembourg
("Clearstream Luxembourg").
CERTAIN BOOK-ENTRY PROCEDURES FOR THE GLOBAL SECURITIES
The operations and procedures of DTC, Euroclear and Clearstream Luxembourg
are solely within the control of the respective settlement systems and are
subject to change by them from time to time. Investors are urged to contact the
relevant system or its participants directly to discuss these matters.
DTC has advised us that it is:
- a limited-purpose trust company organized under the laws of the State of
New York;
- a "banking organization" within the meaning of the New York Banking Law;
- a member of the Federal Reserve System;
- a "clearing corporation" within the meaning of the New York Uniform
Commercial Code, as amended; and
- a "clearing agency" registered pursuant to Section 17A of the Securities
Exchange Act of 1934.
DTC was created to hold securities for its participants (collectively, the
"participants") and to facilitate the clearance and settlement of securities
transactions, such as transfers and pledges, between participants through
electronic book-entry changes to the accounts of its participants, thereby
eliminating the need for physical transfer and delivery of certificates. DTC's
participants include securities brokers and dealers (including Credit Suisse
First Boston LLC), banks and trust companies, clearing corporations and certain
other organizations. DTC is owned by a number of its direct participants and by
the New York Stock Exchange, Inc., the American Stock Exchange LLC and the
National Association of Securities Dealers, Inc. Indirect access to DTC's system
is also available to other entities such as banks, brokers, dealers and trust
companies (collectively, the "indirect participants") that clear through or
maintain a custodial relationship with a participant, either directly or
indirectly. Investors who are not participants may beneficially own securities
held by or on behalf of DTC only through participants or indirect participants.
The rules applicable to DTC and its participants are on file with the SEC.
The laws of some jurisdictions may require that some purchasers of
securities take physical delivery of those securities in definitive form.
Accordingly, the ability to transfer beneficial interests in notes represented
by a global security to those persons may be limited. In addition, because DTC
can act only on behalf of its participants, who in turn act on behalf of persons
who hold interests through participants, the ability of a person holding a
beneficial interest in a global security to pledge or transfer that interest to
persons or entities that do not participate in DTC's system, or to otherwise
take actions in respect of that interest, may be affected by the lack of a
physical security in respect of that interest.
So long as DTC or its nominee is the registered owner of a global security,
DTC or that nominee, as the case may be, will be considered the sole legal owner
or holder of the notes represented by that global security for all purposes of
the notes and the Indenture. Except as provided below, owners of beneficial
interests in a global security will not be entitled to have the notes
represented by that global security registered in their names, will not receive
or be entitled to receive physical delivery of certificated securities, and will
not be considered the owners or holders of the notes represented by that
beneficial
66
interest under the Indenture for any purpose, including with respect to the
giving of any direction, instruction or approval to the trustee. To facilitate
subsequent transfers, all global securities that are deposited with, or on
behalf of, DTC will be registered in the name of DTC's nominee, Cede & Co. The
deposit of global securities with, or on behalf of, DTC and their registration
in the name of Cede & Co. effect no change in beneficial ownership. We
understand that DTC has no knowledge of the actual beneficial owners of the
securities. Accordingly, each holder owning a beneficial interest in a global
security must rely on the procedures of DTC and, if that holder is not a
participant or an indirect participant, on the procedures of the participant
through which that holder owns its interest, to exercise any rights of a holder
of notes under the Indenture or that global security. We understand that under
existing industry practice, in the event that we request any action of holders
of notes, or a holder that is an owner of a beneficial interest in a global
security desires to take any action that DTC, as the holder of that global
security, is entitled to take, DTC would authorize the participants to take that
action and the participants would authorize holders owning through those
participants to take that action or would otherwise act upon the instruction of
those holders.
Conveyance of notices and other communications by DTC to its direct
participants, by its direct participants to indirect participants and by its
direct and indirect participants to beneficial owners will be governed by
arrangements among them, subject to any statutory or regulatory requirements as
may be in effect from time to time.
Neither DTC nor Cede & Co. will consent or vote with respect to the global
securities. Under its usual procedures, DTC will mail an omnibus proxy to us as
soon as possible after the applicable record date. The omnibus proxy assigns
Cede & Co.'s consenting or voting rights to those direct participants of DTC to
whose accounts the securities are credited on the applicable record date, which
are identified in a listing attached to the omnibus proxy.
Neither we nor the trustee will have any responsibility or liability for
any aspect of the records relating to or payments made on account of notes by
DTC, or for maintaining, supervising or reviewing any records of DTC relating to
the notes.
Payments with respect to the principal of and premium, if any, and interest
on a global security will be payable by the trustee to or at the direction of
DTC or its nominee in its capacity as the registered holder of the global
security under the Indenture. Under the terms of the Indenture, we and the
trustee may treat the persons in whose names the notes, including the global
securities, are registered as the owners thereof for the purpose of receiving
payment thereon and for any and all other purposes whatsoever. Accordingly,
neither we nor the trustee has or will have any responsibility or liability for
the payment of those amounts to owners of beneficial interests in a global
security. It is our understanding that DTC's practice is to credit direct its
participants' accounts on the applicable payment date in accordance with their
respective holdings shown on DTC's records, unless DTC has reason to believe
that it will not receive payment on that date. Payments by the participants and
the indirect participants to the owners of beneficial interests in a global
security will be governed by standing instructions and customary industry
practice and will be the responsibility of the participants and indirect
participants and not of DTC, us or the trustee, subject to statutory or
regulatory requirements in effect at the time. None of us, the trustee or any
paying agent will have any responsibility or liability for any aspect of the
records relating to, or payments made on account of, beneficial interests in the
global securities or for maintaining, supervising or reviewing any records
relating to those beneficial interests.
Transfers between participants in DTC will be effected in accordance with
DTC's procedures, and will be settled in same-day funds. Transfers between
participants in Euroclear or Clearstream Luxembourg will be effected in the
ordinary way in accordance with their respective rules and operating procedures.
Subject to compliance with the transfer restrictions applicable to the
notes, cross-market transfers between the participants in DTC, on the one hand,
and Euroclear or Clearstream Luxembourg participants, on the other hand, will be
effected through DTC in accordance with DTC's rules on behalf of Euroclear or
Clearstream Luxembourg, as the case may be, by its respective depositary;
however, those crossmarket transactions will require delivery of instructions to
Euroclear or Clearstream Luxembourg, as
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the case may be, by the counterparty in that system in accordance with the rules
and procedures and within the established deadlines (Brussels time) of that
system. Euroclear or Clearstream Luxembourg, as the case may be, will, if the
transaction meets its settlement requirements, deliver instructions to its
respective depositary to take action to effect final settlement on its behalf by
delivering or receiving interests in the relevant global securities in DTC, and
making or receiving payment in accordance with normal procedures for same-day
funds settlement applicable to DTC. Euroclear participants and Clearstream
Luxembourg participants may not deliver instructions directly to the
depositaries for Euroclear or Clearstream Luxembourg.
Because of time zone differences, the securities account of a Euroclear or
Clearstream Luxembourg participant purchasing an interest in a global security
from a participant in DTC will be credited, and any such crediting will be
reported to the relevant Euroclear or Clearstream Luxembourg participant, during
the securities settlement processing day (which must be a business day for
Euroclear and Clearstream Luxembourg) immediately following the settlement date
of DTC. Cash received in Euroclear or Clearstream Luxembourg as a result of
sales of interests in a global security by or through a Euroclear or Clearstream
Luxembourg participant to a participant in DTC will be received with value on
the settlement date of DTC but will be available in the relevant Euroclear or
Clearstream Luxembourg cash account only as of the business day for Euroclear or
Clearstream Luxembourg following DTC's settlement date.
Although we understand that DTC, Euroclear and Clearstream Luxembourg have
agreed to the foregoing procedures to facilitate transfers of interests in the
global securities among participants in DTC, Euroclear and Clearstream
Luxembourg, they are under no obligation to perform or to continue to perform
those procedures, and those procedures may be discontinued at any time. Neither
we nor the trustee will have any responsibility for the performance by DTC,
Euroclear or Clearstream Luxembourg or their respective participants or indirect
participants of their respective obligations under the rules and procedures
governing their operations.
DTC, Euroclear or Clearstream Luxembourg may discontinue providing its
services as securities depositary with respect to the global securities at any
time by giving reasonable notice to us or the trustee. Under such circumstances,
if a successor securities depositary is not obtained, certificates for the
securities are required to be printed and delivered.
We may decide to discontinue use of the system of book-entry transfers
through DTC or a successor securities depositary. In that event, certificates
for the securities will be printed and delivered.
We have provided the foregoing information with respect to DTC to the
financial community for information purposes only. We obtained the information
in this section and elsewhere in this prospectus concerning DTC, Euroclear and
Clearstream Luxembourg and their respective book-entry systems from sources that
we believe are reliable. Although we expect DTC, Euroclear or Clearstream
Luxembourg and their participants to follow the foregoing procedures in order to
facilitate transfers of interests in global securities among their respective
participants, they are under no obligation to perform or continue to perform
such procedures and such procedures may be discontinued at any time.
EXCHANGE OFFER AND REGISTRATION RIGHTS
In connection with the issuance of the Old Notes, we entered into a
registration rights agreement with Citigroup Global Markets Inc., Credit Suisse
First Boston LLC, Banc of America Securities LLC, Tokyo-Mitsubishi International
plc and SG Cowen Securities Corporation, the initial purchasers. The following
summary of selected provisions of the registration rights agreement is not
complete and is subject to all the provisions of the registration rights
agreement. Copies of the registration rights agreement are available from us
upon request as described under "Where You Can Find More Information."
Pursuant to the registration rights agreement, we agreed to file with the
SEC this exchange offer registration statement with respect to a registered
offer to exchange the Old Notes for New Notes, which have terms identical to the
Old Notes in all material respects except that such notes will not contain terms
with respect to transfer restrictions, registration rights and payment of
additional interest. Upon the
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effectiveness of this exchange offer registration statement, pursuant to the
exchange offer we will offer to the holders of Transfer Restricted Securities
(as defined below) who are able to make certain representations, the opportunity
to exchange their Transfer Restricted Securities for New Notes. If, upon
consummation of the exchange offer, the initial purchasers hold notes acquired
by them as part of the Old Notes' initial distribution, we, simultaneously with
the delivery of the New Notes pursuant to the exchange offer, will issue and
deliver to the initial purchasers, in a private exchange for the notes held by
the initial purchasers, a like principal amount of our New Notes issued under
the indenture and identical in all material respects to the New Notes issued in
the exchange offer, except such notes issued in the private exchange shall
include restrictions on transfer under the Securities Act and the securities
laws of the several states of the United States.
If:
- we are not permitted to file this exchange offer registration statement
or consummate the exchange offer because the exchange offer is not
permitted by applicable law or SEC policy;
- the initial purchasers so request with respect to notes, including New
Notes acquired in a private exchange, not eligible to be exchanged for
New Notes in the exchange offer and held by them following consummation
of the exchange offer;
- any holder of Transfer Restricted Securities notifies us in writing prior
to the consummation of the exchange offer that, based upon an opinion of
counsel, it is not eligible to participate in the exchange offer, or, in
the case of any holder, other than a broker-dealer, that participates in
the exchange offer, such holder does not receive freely tradeable New
Notes, or
- the exchange offer is not consummated within 260 days of the closing of
the offering of the Old Notes, then we will file with the SEC a shelf
registration statement to cover resales of the notes by the holders
thereof who satisfy certain conditions relating to the provision of
information in connection with the shelf registration statement.
We also agreed to use our reasonable commercial efforts to cause the
applicable registration statement to be declared effective as promptly as
possible by the SEC. For purposes of the foregoing, "Transfer Restricted
Securities" means each note, including notes acquired in a private exchange,
until the earlier to occur of:
- the date on which such note has been exchanged by a person other than a
broker-dealer for a freely tradeable New Note in the exchange offer;
- following the exchange by a broker-dealer in the exchange offer of an Old
Note for a New Note, the date on which such New Note is sold to a
purchaser who receives from such broker-dealer on or prior to the date of
such sale a copy of the prospectus contained in this exchange offer
registration statement;
- the date on which such note, including a note acquired in a private
exchange, has been effectively registered under the Securities Act and
disposed of in accordance with the shelf registration statement; or
- the date on which such note, including a note acquired in a private
exchange, is distributed to the public pursuant to Rule 144 under the
Securities Act or is saleable pursuant to Rule 144(k) under the
Securities Act.
The registration rights agreement also provides that:
- we will file this exchange offer registration statement with the SEC on
or prior to 90 days after the closing of the offering of the Old Notes;
- we will use our reasonable commercial efforts to have this exchange offer
registration statement declared effective by the SEC within 210 days
after the closing of the offering of the Old Notes;
69
- unless the exchange offer would not be permitted by applicable law or SEC
policy, we will commence the exchange offer and use our reasonable
commercial efforts to issue on or prior to 30 business days after the
date on which this exchange offer registration statement is declared
effective by the SEC, New Notes in exchange for all notes properly
tendered and not withdrawn prior thereto in the exchange offer; and
- if obligated to file the shelf registration statement, we will use our
reasonable commercial efforts to file the shelf registration statement
with the SEC as promptly as practicable but in no event more than 30
business days after such filing obligation arises and to thereafter cause
the shelf registration statement to be declared effective by the SEC as
promptly as practicable thereafter. We are permitted to suspend use of
the prospectus that is part of the shelf registration statement during
certain periods of time and in certain circumstances relating to pending
corporate developments and public filings with the SEC and similar
events.
Additional interest with respect to the Old Notes shall be assessed as
follows if any of the following events occur:
- if on or prior to the 90 days following the closing of the offering of
the Old Notes, neither this exchange offer registration statement nor a
shelf registration statement has been filed with the SEC; or
- if on or prior to the 210 days following the closing of the offering of
the Old Notes, this exchange offer registration statement has not been
declared effective by the SEC or, if required to be filed in lieu
thereof, the shelf registration statement has not been declared effective
by the SEC; or
- if the exchange offer has not been consummated within 30 business days
after this exchange offer registration statement has been declared
effective by the SEC; or
- if after either this exchange offer registration statement or the shelf
registration statement is declared effective:
- such registration statement thereafter ceases to be effective; or
- such registration statement or the related prospectus ceases to be
usable, except as permitted in the registration rights agreement, in
connection with the exchanges of the notes or resales of Transfer
Restricted Securities, as applicable, during the periods specified
therein because either any event occurs as a result of which the related
prospectus forming part of such registration statement would include an
untrue statement of a material fact or omit to state a material fact
necessary to make the statements therein, in the light of the
circumstances under which they were made, not misleading, or it shall be
necessary to amend such registration statement or supplement the related
prospectus to comply with the Securities Act or the Securities Exchange
Act or the respective rules thereunder.
Additional interest shall accrue on the Transfer Restricted Securities over
and above the interest set forth in the title of the notes at an annual rate of
0.25% for the first 90-day period from and including the date on which any of
the previous events shall occur, and such annual rate will increase by an
additional 0.25% with respect to each subsequent 90-day period until all such
events have been cured, up to a maximum additional annual rate of 1.00%.
Holders of notes will be required to make certain representations to us, as
described in the registration rights agreement, in order to participate in the
exchange offer and will be required to deliver information to be used in
connection with the shelf registration statement and to provide comments on the
shelf registration statement within the time periods set forth in the
registration rights agreement and will be named as a selling security holder in
such shelf registration statement in order to have their notes included in the
shelf registration statement and benefit from the provisions regarding
additional interest set forth above. Any holders, other than the initial
purchasers, who are eligible to participate in the exchange offer but fail to,
or elect not to, participate therein will continue to hold Transfer Restricted
Securities and will
70
have no further rights to exchange their Transfer Restricted Securities or have
such securities registered under the registration rights agreement.
PLAN OF DISTRIBUTION
Based on interpretations by the staff of the SEC set forth in no action
letters issued to third parties, we believe that you may transfer New Notes
issued under the exchange offer in exchange for Old Notes unless you are:
- our "affiliate" within the meaning of Rule 405 under the Securities Act;
- a broker-dealer that acquired Old Notes directly from us; or
- a broker-dealer that acquired Old Notes as a result of market-making or
other trading activities without compliance with the registration and
prospectus delivery provisions of the Securities Act;
provided that you acquire the New Notes in the ordinary course of your business
and you are not engaged in, and do not intend to engage in, and have no
arrangement or understanding with any person to participate in, a distribution
of the New Notes. Broker-dealers receiving New Notes in the exchange offer will
be subject to a prospectus delivery requirement with respect to resales of the
New Notes.
To date, the staff of the SEC has taken the position that participating
broker-dealers may fulfill their prospectus delivery requirements with respect
to transactions involving an exchange of securities such as this exchange offer,
other than a resale of an unsold allotment from the original sale of the Old
Notes, with the prospectus contained in the exchange offer registration
statement.
Each broker-dealer that receives New Notes for its own account pursuant to
the exchange offer must acknowledge that it will deliver a prospectus in
connection with any resale of such New Notes. This prospectus, as it may be
amended or supplemented from time to time, may be used by a broker-dealer in
connection with resales of New Notes received in exchange for Old Notes where
such Old Notes were acquired as a result of market-making activities or other
trading activities. We have agreed that, for a period of 180 days after the
expiration date, we will make this prospectus, as amended or supplemented,
available to any broker-dealer for use in connection with any such resale. In
addition, until October 28, 2003, all dealers effecting transactions in the New
Notes may be required to deliver a prospectus.
We will not receive any proceeds from any sale of New Notes by
broker-dealers. New Notes received by broker-dealers for their own account
pursuant to the exchange offer may be sold from time to time in one or more
transactions in the over-the-counter market, in negotiated transactions, through
the writing of options on the New Notes or a combination of such methods of
resale, at market prices prevailing at the time of resale, at prices related to
such prevailing market prices or negotiated prices. Any such resale may be made
directly to purchasers or to or through brokers or dealers who may receive
compensation in the form of commissions or concessions from any such
broker-dealer or the purchasers of any such New Notes. Any broker-dealer that
resells New Notes that were received by it for its own account pursuant to the
exchange offer and any broker or dealer that participates in a distribution of
such New Notes may be deemed to be an "underwriter" within the meaning of the
Securities Act and any profit on any such resale of New Notes and any commission
or concessions received by any such persons may be deemed to be underwriting
compensation under the Securities Act. The letter of transmittal states that, by
acknowledging that it will deliver and by delivering a prospectus, a
broker-dealer will not be deemed to admit that it is an "underwriter" within the
meaning of the Securities Act.
For a period of 180 days after the expiration date, we will promptly send
additional copies of this prospectus and any amendment or supplement to this
prospectus to any broker-dealer that requests such documents in the letter of
transmittal. We have agreed to pay all expenses incident to the exchange offer
(including the expenses of one counsel for the holders of the notes), other than
commissions or concessions of any brokers or dealers, and will indemnify the
holders of the notes (including any broker-dealers) against specified
liabilities, including liabilities under the Securities Act.
71
LEGAL MATTERS
The validity and enforceability of the notes offered hereby and certain
United States federal income taxation matters will be passed upon for El Paso
Natural Gas by Locke Liddell & Sapp LLP, Houston, Texas.
EXPERTS
The consolidated financial statements and financial statement schedule as
of December 31, 2002 and 2001 and for each of the three years in the period
ended December 31, 2002, included in this prospectus have been so included in
reliance on the report of PricewaterhouseCoopers LLP, independent accountants,
given on the authority of said firm as experts in auditing and accounting.
72
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
Report of Independent Accountants........................... F-2
Consolidated Statements of Income for the years ended
December 31, 2002, 2001 and 2000.......................... F-3
Consolidated Balance Sheets as of December 31, 2002 and
2001...................................................... F-4
Consolidated Statements of Cash Flows for the years ended
December 31, 2002, 2001 and 2000.......................... F-5
Consolidated Statements of Stockholder's Equity for the
years ended December 31, 2002, 2001 and 2000.............. F-6
Notes to Consolidated Financial Statements.................. F-7
Schedule II -- Valuation and Qualifying Accounts............ F-28
Condensed Consolidated Statements of Income (Unaudited) for
the three and six months ended June 30, 2003 and 2002..... F-29
Condensed Consolidated Balance Sheets (Unaudited) as of June
30, 2003 and December 31, 2002............................ F-30
Condensed Consolidated Statements of Cash Flows (Unaudited)
for the six months ended June 30, 2003 and 2002........... F-31
Notes to the Condensed Consolidated Financial Statements
(Unaudited)............................................... F-32
F-1
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors and Stockholder of
El Paso Natural Gas Company:
In our opinion, the accompanying consolidated balance sheets and the
related consolidated statements of income, stockholder's equity and cash flows
present fairly, in all material respects, the consolidated financial position of
El Paso Natural Gas Company and its subsidiaries, (the "Company") at December
31, 2002 and 2001, and the consolidated results of their operations and their
cash flows for each of the three years in the period ended December 31, 2002 in
conformity with accounting principles generally accepted in the United States of
America. In addition, in our opinion, the financial statement schedule presents
fairly, in all material respects, the information set forth therein when read in
conjunction with the related consolidated financial statements. These financial
statements and financial statement schedule are the responsibility of the
Company's management; our responsibility is to express an opinion on these
financial statements and financial statement schedule based on our audits. We
conducted our audits of these statements in accordance with auditing standards
generally accepted in the United States of America, which require that we plan
and perform the audit to obtain reasonable assurance about whether the financial
statements are free of material misstatement. An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in the financial
statements, assessing the accounting principles used and significant estimates
made by management, and evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
/s/ PricewaterhouseCoopers LLP
Houston, Texas
March 25, 2003
F-2
EL PASO NATURAL GAS COMPANY
CONSOLIDATED STATEMENTS OF INCOME
(IN MILLIONS)
YEAR ENDED DECEMBER 31,
-----------------------
2002 2001 2000
----- ----- -----
Operating revenues...................... $564 $572 $508
---- ---- ----
Operating expenses
Operation and maintenance............. 173 190 189
Merger-related costs.................. -- 98 --
Depreciation, depletion and
amortization....................... 63 70 66
Western Energy Settlement............. 412 -- --
Taxes, other than income taxes........ 21 28 30
---- ---- ----
669 386 285
---- ---- ----
Operating income (loss)................. (105) 186 223
Other income (expense).................. 1 (2) 4
Interest and debt expense............... (72) (87) (96)
Affiliated interest income.............. 22 58 75
---- ---- ----
Income (loss) before income taxes....... (154) 155 206
Income taxes............................ (55) 60 78
---- ---- ----
Net income (loss)....................... $(99) $ 95 $128
==== ==== ====
See accompanying notes.
F-3
EL PASO NATURAL GAS COMPANY
CONSOLIDATED BALANCE SHEETS
(IN MILLIONS, EXCEPT SHARE AMOUNTS)
DECEMBER 31,
----------------
2002 2001
------ ------
ASSETS
Current assets
Cash and cash equivalents............. $ 3 $ --
Accounts and notes receivable
Customer, net of allowance of $18
in 2002 and $6 in 2001............ 79 97
Affiliates......................... 432 1,298
Other.............................. 13 6
Materials and supplies................ 43 39
Deferred income taxes................. 36 --
Other................................. 27 16
------ ------
Total current assets.......... 633 1,456
------ ------
Property, plant and equipment, at
cost.................................. 3,060 2,940
Less accumulated depreciation,
depletion and amortization......... 1,152 1,142
------ ------
Total property, plant and
equipment, net............... 1,908 1,798
------ ------
Note receivable from affiliate.......... 565 --
------ ------
Other................................... 83 90
------ ------
Total assets.................. $3,189 $3,344
====== ======
LIABILITIES AND STOCKHOLDER'S EQUITY
Current liabilities
Accounts payable
Trade.............................. $ 43 $ 54
Affiliates......................... 33 9
Other.............................. 11 9
Short-term borrowings (including
current maturities of long-term
debt).............................. 200 654
Accrued interest...................... 15 22
Taxes payable......................... 133 117
Contractual deposits.................. 35 1
Western Energy Settlement payable..... 100 --
Other................................. 53 70
------ ------
Total current liabilities..... 623 936
------ ------
Long-term debt, less current
maturities............................ 758 659
------ ------
Other liabilities
Deferred income taxes................. 221 282
Western Energy Settlement
obligation......................... 312 --
Other................................. 122 169
------ ------
655 451
------ ------
Commitments and contingencies
Stockholder's equity
Preferred stock, 8%, par value $0.01
per share; authorized 1,000,000
shares; issued 500,000 shares;
stated at liquidation value........ 350 350
Common stock, par value $1 per share;
authorized and issued 1,000
shares............................. -- --
Additional paid-in capital............ 715 714
Retained earnings..................... 88 234
------ ------
Total stockholder's equity.... 1,153 1,298
------ ------
Total liabilities and
stockholder's equity......... $3,189 $3,344
====== ======
See accompanying notes.
F-4
EL PASO NATURAL GAS COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(IN MILLIONS)
YEAR ENDED DECEMBER 31,
-----------------------
2002 2001 2000
----- ----- -----
Cash flows from operating activities
Net income (loss)....................... $ (99) $ 95 $ 128
Adjustments to reconcile net income
(loss) to net cash from operating
activities
Depreciation, depletion and
amortization...................... 63 70 66
Western Energy Settlement.......... 412 -- --
Deferred income tax expense
(benefit)......................... (113) 29 34
Net gain on the sale of assets..... (1) -- (3)
Risk-sharing revenue............... (32) (32) (32)
Non-cash portion of merger-related
costs............................. -- 92 --
Bad debt expense................... 12 6 --
Other non-cash income items........ 2 2 3
Working capital changes, net of
non-cash transactions
Accounts receivable.............. (4) 25 (64)
Accounts payable................. (4) (5) 12
Taxes payable.................... 24 17 16
Other working capital changes
Assets........................ 4 (6) (7)
Liabilities................... 14 12 (2)
Non-working capital changes
Assets........................... (1) 28 18
Liabilities...................... (8) (9) (9)
----- ----- -----
Net cash provided by operating
activities.................. 269 324 160
----- ----- -----
Cash flows from investing activities
Additions to property, plant and
equipment.......................... (193) (157) (228)
Net proceeds from the sale of
assets............................. 9 -- 36
Net change in affiliated advances
receivable......................... 304 (298) 344
Other................................. -- -- 3
----- ----- -----
Net cash provided by (used in)
investing activities........ 120 (455) 155
----- ----- -----
Cash flows from financing activities
Net borrowings (repayments) of
commercial paper................... (439) 159 (287)
Payments to retire long-term debt..... (215) -- --
Net proceeds from the issuance of
long-term debt..................... 296 -- --
Dividends paid........................ (28) (28) (28)
----- ----- -----
Net cash provided by (used in)
financing activities........ (386) 131 (315)
----- ----- -----
Increase in cash and cash equivalents... 3 -- --
Cash and cash equivalents
Beginning of period................... -- -- --
----- ----- -----
End of period......................... $ 3 $ -- $ --
===== ===== =====
See accompanying notes.
F-5
EL PASO NATURAL GAS COMPANY
CONSOLIDATED STATEMENTS OF STOCKHOLDER'S EQUITY
(IN MILLIONS, EXCEPT SHARE AMOUNTS)
8% COMMON STOCK ADDITIONAL TOTAL
PREFERRED --------------- PAID-IN RETAINED STOCKHOLDER'S
STOCK SHARES AMOUNT CAPITAL EARNINGS EQUITY
--------- ------ ------ ---------- -------- -------------
January 1, 2000.................... $350 1,000 $ -- $700 $ 76 $1,126
Net income....................... 128 128
Preferred stock dividends........ (28) (28)
Allocated tax benefit of El Paso
equity plans.................. 5 5
Non-cash capital contributions
from El Paso.................. 5 5
Dividends........................ (9) (9)
---- ----- ---- ---- ---- ------
December 31, 2000.................. 350 1,000 -- 710 167 1,227
Net income....................... 95 95
Preferred stock dividends........ (28) (28)
Allocated tax benefit of El Paso
equity plans.................. 4 4
---- ----- ---- ---- ---- ------
December 31, 2001.................. 350 1,000 -- 714 234 1,298
Net loss......................... (99) (99)
Preferred stock dividends........ (28) (28)
Allocated tax benefit of El Paso
equity plans.................. 1 1
Dividends........................ (19) (19)
---- ----- ---- ---- ---- ------
December 31, 2002.................. $350 1,000 $ -- $715 $ 88 $1,153
==== ===== ==== ==== ==== ======
See accompanying notes.
F-6
EL PASO NATURAL GAS COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Presentation and Principles of Consolidation
Our consolidated financial statements include the accounts of all
majority-owned, controlled subsidiaries after the elimination of all significant
intercompany accounts and transactions. We consolidate entities when we have the
ability to control the operating and financial decisions and policies of that
entity. Our financial statements for prior periods include reclassifications
that were made to conform to the current year presentation. Those
reclassifications had no impact on reported net income or stockholder's equity.
Use of Estimates
The preparation of financial statements in conformity with U.S. generally
accepted accounting principles (GAAP) requires the use of estimates and
assumptions that affect the amounts we report as assets, liabilities, revenues
and expenses and our disclosures in these financial statements. Actual results
can, and often do, differ from those estimates.
Accounting for Regulated Operations
Our natural gas systems are subject to the jurisdiction of FERC in
accordance with the Natural Gas Act of 1938 and the Natural Gas Policy Act of
1978, and we apply the provisions of SFAS No. 71, Accounting for the Effects of
Certain Types of Regulation. Accounting requirements for regulated businesses
can differ from the accounting requirements for non-regulated businesses.
Transactions that have been recorded differently as a result of regulatory
accounting requirements include the capitalization of an equity return component
on regulated capital projects, employee related benefits and other costs and
taxes included in, or expected to be included in, future rates.
Our application of SFAS No. 71 is based on the current regulatory
environment, our current tariff rates and our ability to collect those rates.
Future regulatory developments and rate cases could impact this accounting.
Although discounting of our maximum tariff rates does occur, we believe the
standards required by SFAS No. 71 for its application are met and the continued
use of regulatory accounting under SFAS No. 71 best reflects the results of
operations in the economic environment in which we currently operate. Regulatory
accounting requires us to record assets and liabilities that result from the
rate-making process that would not be recorded under GAAP for non-regulated
entities. We will continue to evaluate the application of regulatory accounting
principles based on on-going changes in the regulatory and economic environment.
Items that may influence our assessment are:
- inability to recover cost increases due to rate caps and rate case
moratoriums;
- inability to recover capitalized costs, including an adequate return on
those costs through the rate-making process and FERC proceedings;
- excess capacity;
- increased competition and discounting in the markets we serve; and
- impacts of ongoing regulatory initiatives in the natural gas industry.
Cash and Cash Equivalents
We consider short-term investments with an original maturity of less than
three months to be cash equivalents.
F-7
Allowance for Doubtful Accounts
We establish provisions for losses on accounts receivable and for natural
gas imbalances due from shippers and operators if we determine that we will not
collect all or part of the outstanding balance. We regularly review
collectibility and establish or adjust our allowance as necessary using the
specific identification method.
Materials and Supplies
We value materials and supplies at the lower of cost or market value with
cost determined using the average cost method.
Natural Gas Imbalances
Natural gas imbalances occur when the actual amount of natural gas
delivered from or received by a pipeline system differs from the contractual
amount scheduled to be delivered or received. We value these imbalances due to
or from shippers and operators at the end of year actual or appropriate market
index price. Imbalances are settled in cash or made up in kind, subject to the
contractual terms of settlement.
Imbalances due from others are reported in our balance sheet as either
accounts receivable from customers or accounts receivable from affiliates.
Imbalances owed to others are reported on the balance sheet as either trade
accounts payable or accounts payable to affiliates. In addition, all imbalances
are classified as current.
Property, Plant and Equipment
Our property, plant and equipment is recorded at its original cost of
construction or, upon acquisition, at either the fair value of the assets
acquired or the cost to the entity that first placed the asset in service. We
capitalize direct costs, such as labor and materials, and indirect costs, such
as overhead and an allowance for funds used during construction for our
regulated business as allowed by FERC. We capitalize the major units of property
replacements or improvements and expense minor items. Included in our pipeline
property balances are additional acquisition costs which represent the excess
purchase costs associated with purchase business combinations allocated to our
regulated interstate systems. These costs are amortized on a straight-line basis
over 36 years, and we do not recover these excess costs in our rates. As of
December 31, 2002, we had unamortized additional acquisition costs of $71
million net of accumulated amortization of $80 million.
We use the composite (group) method to depreciate regulated property, plant
and equipment. Under this method, assets with similar lives and other
characteristics are grouped and depreciated as one asset. For aircraft, we apply
the depreciation rates to the total cost of the group until its net book value
equals its salvage value. For all other property, plant and equipment we
depreciate the asset to zero. Currently, our depreciation rates vary from 2 to
33 percent. Using these rates, the average remaining depreciable lives of these
assets range from 2 to 39 years. We re-evaluate depreciation rates each time we
redevelop our transportation rates when we file with the FERC for an increase or
decrease in rates.
When we retire regulated property, plant and equipment, we charge
accumulated depreciation and amortization for the original cost, plus the cost
to remove, sell or dispose, less its salvage value. We do not recognize a gain
or loss unless we sell an entire operating unit. We include gains or losses on
dispositions of operating units in income. On non-regulated property, plant and
equipment, we record a gain or loss in income for the difference between the net
book value relative to proceeds received, if any, when the asset is sold or
retired.
At December 31, 2002 and 2001, we had approximately $146 million and $262
million of construction work in progress included in our property, plant and
equipment. In addition, during 2002, 2001 and 2000, we had capitalized an
allowance for funds used during construction of $6 million, $9 million and $8
million.
F-8
Asset Impairments
We apply the provisions of SFAS No. 144, Accounting for the Impairment or
Disposal of Long-Lived Assets to account for asset impairments. Under this
standard, we evaluate an asset for impairment when events or circumstances
indicate that a long-lived asset's carrying value may not be recovered. These
events include market declines, changes in the manner in which we intend to use
an asset or decisions to sell an asset and adverse changes in the legal or
business environment such as adverse actions by regulators. At the time we
decide to exit an activity or sell a long-lived asset or group of assets, we
adjust the carrying value of those assets downward, if necessary, to the
estimated sales price, less costs to sell. We also classify these asset or
assets as either held for sale or as discontinued operations, depending on
whether the asset or assets have independently determinable cash flows.
Revenue Recognition
Our revenues consist primarily of demand and throughput-based
transportation services. We recognize demand revenues on firm contracted
capacity monthly over the contract period regardless of the amount of capacity
that is actually used. For throughput-based services, we record revenues when we
complete the delivery of natural gas to the agreed upon delivery point. Revenues
are generally based on the thermal quantity of gas delivered or subscribed at a
price specified in the contract or tariff. We are subject to FERC regulations
and, as a result, revenues we collect may be refunded in a final order of a
pending rate proceeding or as a result of a rate settlement. We establish
reserves for these potential refunds.
We also record risk sharing revenues related to our most recent rate
settlement. The majority of the risk sharing amounts were collected in advance
from our customers. These collections were initially deferred and are then
amortized over the risk sharing period as specified in our tariff. See Note 8
beginning on page F-15 for a further discussion of our rate settlement and these
risk sharing provisions.
Environmental Costs and Other Contingencies
We record liabilities when our environmental assessments indicate that
remediation efforts are probable, and the costs can be reasonably estimated. We
recognize a current period expense when clean-up efforts do not benefit future
periods. We capitalize costs that benefit more than one accounting period,
except in instances where separate agreements or legal and regulatory guidelines
dictate otherwise. Estimates of our liabilities are based on currently available
facts, existing technology and presently enacted laws and regulations taking
into account the likely effects of inflation and other societal and economic
factors, and include estimates of associated legal costs. These amounts also
consider prior experience in remediating contaminated sites, other companies'
clean-up experience and data released by the Environmental Protection Agency
(EPA) or other organizations. These estimates are subject to revision in future
periods based on actual costs or new circumstances and are included in our
balance sheet in other current and long-term liabilities at their undiscounted
amounts. We evaluate recoveries from insurance coverage, rate recovery,
government sponsored and other programs separately from our liability and, when
recovery is assured, we record and report an asset separately from the
associated liability in our financial statements.
We recognize liabilities for other contingencies when we have an exposure
that, when fully analyzed, indicates it is both probable that an asset has been
impaired or that a liability has been incurred and the amount of impairment or
loss can be reasonably estimated. Funds spent to remedy these contingencies are
charged against a reserve, if one exists, or expensed. When a range of probable
loss can be estimated, we accrue the most likely amount, or at least the minimum
of the range of probable loss.
Income Taxes
We report current income taxes based on our taxable income and we provide
for deferred income taxes to reflect estimated future tax payments or receipts.
Deferred taxes represent the tax impacts of differences between the financial
statement and tax bases of assets and liabilities and carryovers at each year
end. We account for tax credits under the flow-through method, which reduces the
provision for
F-9
income taxes in the year the tax credits first become available. We reduce
deferred tax assets by a valuation allowance when, based on our estimates, it is
more likely than not that a portion of those assets will not be realized in a
future period. The estimates utilized in the recognition of deferred tax assets
are subject to revision, either up or down, in future periods based on new facts
or circumstances.
El Paso maintains a tax accrual policy to record both regular and
alternative minimum taxes for companies included in its consolidated federal
income tax return. The policy provides, among other things, that (i) each
company in a taxable income position will accrue a current expense equivalent to
its federal income tax, and (ii) each company in a tax loss position will accrue
a benefit to the extent its deductions, including general business credits, can
be utilized in the consolidated return. El Paso pays all federal income taxes
directly to the IRS and, under a separate tax billing agreement, El Paso may
bill or refund its subsidiaries for their portion of these income tax payments.
New Accounting Pronouncements Issued Not Yet Adopted
As of December 31, 2002, there were a number of accounting standards and
interpretations that had been issued, but not yet adopted by us. Below is a
discussion of the more significant standards that could impact us.
Accounting for Costs Associated with Exit or Disposal Activities. In July
2002, the FASB issued SFAS No. 146, Accounting for Costs Associated with Exit or
Disposal Activities. This statement will require us to recognize costs
associated with exit or disposal activities when they are incurred rather than
when we commit to an exit or disposal plan. Examples of costs covered by this
guidance include lease termination costs, employee severance costs associated
with a restructuring, discontinued operations, plant closings or other exit or
disposal activities. This statement is effective for fiscal years beginning
after December 31, 2002, and will impact any exit or disposal activities we
initiate after January 1, 2003.
Accounting for Guarantees. In November 2002, the FASB issued FIN No. 45,
Guarantor's Accounting and Disclosure Requirements for Guarantees, Including
Indirect Guarantees of Indebtedness of Others. This interpretation requires that
companies record a liability for all guarantees issued after January 31, 2003,
including financial, performance, and fair value guarantees. This liability is
recorded at its fair value upon issuance, and does not affect any existing
guarantees issued before January 31, 2003. This standard also requires expanded
disclosures on all existing guarantees at December 31, 2002. We have included
these required disclosures in Notes 7 and 8.
2. WESTERN ENERGY SETTLEMENT
On March 20, 2003, we and our affiliates entered into an agreement in
principle (the Western Energy Settlement) with various public and private
claimants, including the states of California, Washington, Oregon and Nevada, to
resolve the principal litigation, claims and regulatory proceedings against us
and our affiliates relating to the sale or delivery of natural gas and
electricity from September 1996 to the date of the Western Energy Settlement.
See Note 8 beginning on page F-15 for a discussion of this matter.
The portion of the Western Energy Settlement allocated to us by El Paso
resulted in a one-time charge in the fourth quarter of 2002 of $412 million
before tax and approximately $262 million after tax. These amounts represent the
present value of the components of the settlement discounted at 10 percent. The
settlement will become payable beginning with the execution of a definitive
settlement agreement. Components of the settlement were allocated to us, our
parent and our affiliate, El Paso Merchant Energy, based on the nature of the
component and our individual ability to perform under the agreement. The
components that were allocated to us are as follows:
- a cash payment of $100 million;
- the delivery of approximately 26.4 million shares of El Paso's common
stock valued at $125 million;
- payments of $22 million per year for 20 years.
F-10
- for a period of five years, our EPNG system will make available at its
California delivery points, 3,290 MMcf/d of capacity on a primary
delivery point basis; and
- no admission of wrong doing.
The settlement is subject to review and approval by state courts and the
FERC.
Our obligation for the settlement is reflected in our balance sheet at $412
million, which represents the notional amount of approximately $665 million,
less a discount (at a rate of 10 percent) of approximately $253 million. The
components of the obligation for the settlement are as follows (in millions):
Our portion of the Western Energy Settlement................ $ 665
Discount at 10 percent...................................... (253)
-----
Net present value of settlement............................. 412
Less: Current portion of obligation......................... 100
-----
Non-current obligation for Western Energy Settlement........ $ 312
=====
The discount will be amortized to interest expense annually at an amount
based on a constant rate of interest (10 percent) applied to the declining
obligation balance. This amortization is expected to be approximately $12
million for 2003, after income taxes.
3. MERGER-RELATED COSTS
During the year ended December 31, 2001, we incurred merger-related costs
of $98 million associated with El Paso Corporation's (El Paso) 2001 merger with
The Coastal Corporation and the relocation of our headquarters from El Paso,
Texas to Colorado Springs, Colorado. Our merger-related costs include employee
severance, retention and transition costs for severed employees totaling $6
million that occurred as a result of El Paso's merger-related workforce
reduction and consolidation. All employee severance, retention and transition
costs have been paid. Merger-related costs also include estimated net lease
payments on a non-cancelable lease for office space and facility-related costs
of $92 million to close our offices in El Paso and relocate our headquarters to
Colorado Springs. These charges were accrued in 2001 at the time we completed
our relocations and closed these offices. As of December 31, 2002, we have paid
$29 million of the accrual leaving a balance of $63 million. The amounts accrued
will be paid over the term of the applicable non-cancelable lease agreements.
Future developments, such as our ability to terminate the lease or to recover
lease costs through sub-leases, could impact the accrued amounts.
4. INCOME TAXES
The following table reflects the components of income taxes included in net
income for each of the three years ended December 31:
2002 2001 2000
----- ---- ----
(IN MILLIONS)
Current
Federal................................................... $ 52 $25 $37
State..................................................... 6 6 7
----- --- ---
58 31 44
----- --- ---
Deferred
Federal................................................... (105) 27 36
State..................................................... (8) 2 (2)
----- --- ---
(113) 29 34
----- --- ---
Total income taxes................................ $ (55) $60 $78
===== === ===
F-11
Our income taxes included in net income differ from the amount computed by
applying the statutory federal income tax rate of 35 percent for the following
reasons for each of the three years ended December 31:
2002 2001 2000
---- ---- ----
(IN MILLIONS)
Income taxes at the statutory federal rate of 35%........... $(54) $54 $72
Items creating rate differences:
State income tax, net of federal income tax benefit....... (1) 5 3
Other..................................................... -- 1 3
---- --- ---
Income taxes................................................ $(55) $60 $78
==== === ===
Effective tax rate.......................................... 36% 38% 38%
==== === ===
The following are the components of our net deferred tax liability as of
December 31:
2002 2001
----- -----
(IN MILLIONS)
Deferred tax liabilities
Property, plant and equipment............................. $337 $284
Employee benefits and deferred compensation obligations... 21 27
Regulatory and other assets............................... 91 86
---- ----
Total deferred tax liability...................... 449 397
---- ----
Deferred tax assets
Western Energy Settlement................................. 150 --
U.S. net operating loss and tax credit carryovers......... 17 20
Other liabilities......................................... 97 79
---- ----
Total deferred tax asset.......................... 264 99
---- ----
Net deferred tax liability.................................. $185 $298
==== ====
Under El Paso's tax accrual policy, we are allocated the tax benefit
associated with our employees' exercise of non-qualified stock options and the
vesting of restricted stock as well as restricted stock dividends. This
allocation reduced taxes payable by $1 million in 2002, $4 million in 2001 and
$5 million in 2000. These benefits are included in additional paid-in capital in
our balance sheet.
As of December 31, 2002, we had approximately $17 million of alternative
minimum tax credits and $1 million of net operating loss carryovers available to
offset future regular tax liabilities. The alternative minimum tax credits
carryover indefinitely. The net operating loss carryover period ends in 2021.
Usage of these carryovers is subject to the limitations provided under Sections
382 and 383 of the Internal Revenue Code as well as the separate return
limitation year rules of IRS regulations.
F-12
5. FINANCIAL INSTRUMENTS
Fair Value of Financial Instruments
As of December 31, 2002 and 2001, the carrying amounts of cash and cash
equivalents, short-term borrowings, and trade receivables and payables are
representative of fair value because of the short-term maturity of these
instruments. The carrying amounts and estimated fair values of our financial
instruments are as follows at December 31:
2002 2001
--------------------- ---------------------
CARRYING CARRYING
AMOUNT FAIR VALUE AMOUNT FAIR VALUE
-------- ---------- -------- ----------
(IN MILLIONS)
Balance sheet financial instruments:
Long-term debt, including current
maturities(1).............................. $958 $739 $874 $891
---------------
(1) We estimated the fair value of debt with fixed interest rates based on
quoted market prices for the same or similar issues.
6. REGULATORY ASSETS AND LIABILITIES
Our non-current regulatory assets and liabilities are included in other
non-current assets and liabilities in our balance sheet. Below are the details
of our regulatory assets and liabilities at December 31:
REMAINING AVERAGE
DESCRIPTION 2002 2001 RECOVERY PERIOD
----------- ---- ---- -----------------
(IN MILLIONS)
Non-Current Regulatory Assets
Unamortized loss on reacquired debt........... $25 27 19 years
Grossed-up deferred taxes on capitalized
funds...................................... 14 15 11 years
Retiree medical............................... 9 9 N/A(1)
Under-collected state income taxes............ 5 6 3 years
Other......................................... -- 1 N/A
--- ---
Total regulatory assets............... $53 $58
=== ===
Non-Current Regulatory Liabilities
Property and plant depreciation............... $22 $24 various
Excess deferred federal income taxes.......... 5 5 3 years
--- ---
Total regulatory liabilities.......... $27 $29
=== ===
---------------
(1) Amount to be recovered in future rate proceedings.
7. DEBT AND OTHER CREDIT FACILITIES
We had the following short-term borrowings including current maturities of
long-term debt at December 31:
2002 2001
----- -----
(IN MILLIONS)
Commercial paper(1)......................................... $ -- $439
Current maturities of long-term debt........................ 200 215
---- ----
$200 $654
==== ====
---------------
(1) At December 31, 2001, our weighted average interest rate on our commercial
paper was 3.3%.
F-13
Our long-term debt outstanding consisted of the following at December 31:
2002 2001
---- ----
(IN MILLIONS)
7.75% Notes due 2002................................... $ -- $215
6.75% Notes due 2003................................... 200 200
8.625% Debentures due 2022............................. 260 260
7.50% Debentures due 2026.............................. 200 200
8.375% Notes due 2032.................................. 300 --
---- ----
960 875
Less: Unamortized discount................................ 2 1
Current maturities................................... 200 215
---- ----
Total long-term debt, less current maturities..... $758 $659
==== ====
In January 2002, we retired $215 million aggregate principal amount of
7.75% notes due 2002. In June 2002, we issued $300 million aggregate principal
amount 8.375% notes due 2032 in a private placement. Proceeds were approximately
$296 million, net of issuance costs. We have committed to exchange these notes
for new notes that will be registered with the SEC. The form and terms of the
new notes will be identical in all material respects to the form and terms of
the old notes except that the new notes (1) will be registered with the SEC, (2)
will not be subject to transfer restrictions and (3) will not be subject, under
certain circumstances, to an increase in the stated interest rate.
Aggregate maturities of the principal amounts of long-term debt for the
next 5 years and in total thereafter are as follows:
YEAR (IN MILLIONS)
---- -------------
2003........................................................ $200
2004........................................................ --
2005........................................................ --
2006........................................................ --
2007........................................................ --
Thereafter.................................................. 760
----
Total long-term debt, including current
maturities....................................... $960
====
We have indentures with cross-acceleration provisions that, if triggered,
could result in the acceleration of our long-term debt.
Other Financing Arrangements
In May 2002, El Paso renewed its $3 billion, 364-day revolving credit and
competitive advance facility. We are a designated borrower under this facility
and, as such, are jointly and severally liable for any amounts outstanding under
this facility. This facility matures in May 2003 and provides that amounts
outstanding on that date are not due until May 2004. In June 2002, El Paso
amended its existing $1 billion, 3-year revolving credit and competitive advance
facility to permit it to issue up to $500 million in letters of credit and to
adjust pricing terms. This facility matures in August 2003, and we are also a
designated borrower under this facility and, as such, are jointly and severally
liable for any amounts outstanding under this facility. The interest rate under
both of these facilities varies based on El Paso's senior unsecured debt rating,
and as of December 31, 2002, an initial draw would have had a rate of LIBOR plus
1.0%, and a 0.25% utilization fee for drawn amounts above 25% of the committed
amounts. As of December 31, 2002, $1.5 billion was outstanding under the $3
billion facility, and $456 million in
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letters of credit were issued under the $1 billion facility. In February 2003,
an additional draw of $500 million was made under the revolver.
As a result of El Paso's credit ratings being downgraded to below
investment grade status, cash generated by Mojave, our indirect wholly owned
subsidiary, can be used only for Mojave's operating and maintenance needs and
for purposes of redeeming the preferred interests of Trinity River, an El Paso
financing arrangement that Mojave and other El Paso affiliates collateralize.
Until the preferred interests were redeemed in full, Mojave was required to
distribute a portion of its cash-based earnings to its parent Sabine River
Investors V, L.L.C. and was no longer able to provide excess cash to El Paso's
cash management program. On January 8, 2003, Mojave, through its parent, paid
approximately $3 million under this provision to the preferred interest members
of Trinity River. In March 2003, El Paso entered into a $1.2 billion 2-year term
loan and the proceeds were used to retire the outstanding balance under the
Trinity River financing agreement.
8. COMMITMENTS AND CONTINGENCIES
Legal Proceedings
Western Energy Settlement. On March 20, 2003, we and our affiliates
entered into an agreement in principle (the Western Energy Settlement) with
various public and private claimants, including the states of California,
Washington, Oregon, and Nevada, to resolve the principal litigation, claims, and
regulatory proceedings, which are more fully described below, against us and our
affiliates relating to the sale or delivery of natural gas and electricity from
September 1996 to the date of the Western Energy Settlement. Among other things,
the components of the settlement include:
- a cash payment of $100 million;
- a $2 million cash payment from El Paso's officer bonus pool;
- the issuance of approximately 26.4 million shares of El Paso common
stock;
- delivery to the California border by our affiliate of $45 million worth
of natural gas annually for 20 years beginning in 2004;
- a reduction of the pricing of our affiliate's long-term power supply
contracts with the California Department of Water Resources of $125
million over the remaining term of those contracts, which run through the
end of 2005;
- payments of $22 million per year for 20 years;
- for a period of five years, EPNG will make available at its California
delivery points 3,290 MMcf per day of capacity on a primary delivery
point basis;
- for a period of five years, our affiliates will be subject to
restrictions in subscribing for new capacity on the EPNG system; and
- no admission of wrongdoing.
The Western Energy Settlement will result in an after-tax charge to us of
approximately $262 million in the fourth quarter of 2002 for the component of
the settlement allocated to us.
The agreement in principle is subject to the negotiation of a formal
settlement agreement, portions of which will then be filed with the courts and
the FERC for approval. Upon approval, the parties will release us from covered
claims that they may have against us and our affiliates for the period covered
by the Western Energy Settlement, and the litigation, claims, and regulatory
proceedings against us and our affiliates will be dismissed with prejudice.
California Lawsuits. We have been named as a defendant in fifteen
purported class action, municipal or individual lawsuits, filed in California
state courts. These suits contend that we acted improperly to limit the
construction of new pipeline capacity to California and/or to manipulate the
price
F-15
of natural gas sold into the California marketplace. Specifically, the
plaintiffs argue that our conduct violates California's antitrust statute
(Cartwright Act), constitutes unfair and unlawful business practices prohibited
by California statutes, and amounts to a violation of California's common law
restrictions against monopolization. In general, the plaintiffs are seeking (i)
declaratory and injunctive relief regarding allegedly anticompetitive actions,
(ii) restitution, including treble damages, (iii) disgorgement of profits, (iv)
prejudgment and postjudgment interest, (v) costs of prosecuting the actions and
(vi) attorney's fees. All fifteen cases have been consolidated before a single
judge, under two omnibus complaints, one of which has been set for trial in
September 2003. All of the class action lawsuits and all but one of the
individual lawsuits will be resolved upon finalization and approval of the
Western Energy Settlement.
The California cases discussed above are five filed in the Superior Court
of Los Angeles County (Continental Forge Company, et al v. Southern California
Gas Company, et al, filed September 25, 2000*; Berg v. Southern California Gas
Company, et al, filed December 18, 2000*; County of Los Angeles v. Southern
California Gas Company, et al, filed January 8, 2002*; The City of Los Angeles,
et al v. Southern California Gas Company, et al and The City of Long Beach, et
al v. Southern California Gas Company, et al, both filed March 20, 2001*); two
filed in the Superior Court of San Diego County (John W.H.K. Phillip v. El Paso
Merchant Energy; and John Phillip v. El Paso Merchant Energy, both filed
December 13, 2000*); and two filed in the Superior Court of San Francisco County
(Sweetie's et al v. El Paso Corporation, et al, filed March 22, 2001*; and
California Dairies, Inc., et al v. El Paso Corporation, et al, filed May 21,
2001); and one filed in the Superior Court of the State of California, County of
Alameda (Dry Creek Corporation v. El Paso Natural Gas Company, et al filed
December 10, 2001*); and five filed in the Superior Court of Los Angeles County
(The City of San Bernardino v. Southern California Gas Company, et al; The City
of Vernon v. Southern California Gas Company; The City of Upland v. Southern
California Gas Company, et al; Edgington Oil Company v. Southern California Gas
Company, et al; World Oil Corp. v. Southern California Gas Company, et al, filed
December 27, 2002*).
In November 2002, a lawsuit titled Gus M. Bustamante v. The McGraw-Hill
Companies was filed in the Superior Court of California, County of Los Angeles
by several individuals, including Lt. Governor Bustamante acting as a private
citizen, against numerous defendants, including us, alleging the creation of
artificially high natural gas index prices via the reporting of false price and
volume information. This purported class action on behalf of California
consumers alleges various unfair business practices and seeks restitution,
disgorgement of profits, compensatory and punitive damages, and civil fines.
This lawsuit will be resolved upon finalization and approval of the Western
Energy Settlement.
In January 2003, a lawsuit titled IMC Chemicals v. EPME, et al. was filed
in California state court against us, El Paso and EPME. The suit arises out of a
gas supply contract between IMC Chemicals (IMCC) and EPME and seeks to void the
Gas Purchase Agreement between IMCC and EPME for gas purchases until December
2003. IMCC contends that EPME and its affiliates manipulated market prices for
natural gas and, as part of that manipulation, induced IMCC to enter into the
contract. In furtherance of its attempt to void the contract, IMCC repeats the
allegations and claims of the California lawsuits described above. EPME intends
to enforce the terms of the contract and counterclaim for contract damages. Our
costs and legal exposure related to these lawsuits and claims are not currently
determinable.
In September 2001, we received a civil document subpoena from the
California Attorney General, seeking information said to be relevant to the
Department's ongoing investigation into the high electricity prices in
California. We are continuing to cooperate in responding to their discovery
requests. This proceeding will be resolved upon finalization and approval of the
Western Energy Settlement.
Other Energy Market Lawsuits. The state of Nevada and two individuals
filed a class action lawsuit in Nevada state court naming us and a number of our
affiliates as defendants. The allegations are similar to those in the California
cases. The suit seeks monetary damages and other relief under Nevada antitrust
---------------
* Cases to be dismissed upon finalization and approval of the Western Energy
Settlement.
F-16
and consumer protection laws. This proceeding will be resolved upon finalization
and approval of the Western Energy Settlement.
A purported class action suit titled Henry W. Perlman et. al. v. Southern
California Gas Company, San Diego Gas & Electric; Sempra Energy, El Paso
Corporation, El Paso Natural Gas Company and El Paso Merchant Energy, L.P. was
filed in federal court in New York City in December 2002 alleging that the
defendants manipulated California's natural gas market by manipulating the spot
market of gas traded on the NYMEX. We have not yet been served with the
complaint. Our costs and legal exposure related to this lawsuit are not
currently determinable.
In March 2003, the State of Arizona sued us, our affiliates and other
unrelated entities on behalf of Arizona consumers. The suit alleges that the
defendants conspired to artificially inflate prices of natural gas and
electricity during 2000 and 2001. Making factual allegations similar to those
alleged in the California cases, the suit seeks relief similar to the California
cases as well, but under Arizona antitrust and consumer fraud statutes. Our
costs and legal exposure related to these lawsuits and claims are not currently
determinable.
Shareholder Class Action Suit. In November 2002, we were named as a
defendant in a shareholder derivative suit titled Marilyn Clark v. Byron
Allumbaugh, David A. Arledge, John M. Bissell, Juan Carlos Braniff, James F.
Gibbons, Anthony W. Hall, Ronald L. Kuehn, J. Carleton MacNeil, Thomas McDade,
Malcolm Wallop, William Wise, Joe B. Wyatt, El Paso Natural Gas Company and El
Paso Merchant Energy Company filed in state court in Houston. This shareholder
derivative suit generally alleges that manipulation of California gas supply and
gas prices exposed our parent, El Paso, to claims of antitrust conspiracy, FERC
penalties and erosion of share value. The plaintiffs have not asked for any
relief with regards to us. Our costs and legal exposure related to this
proceeding are not currently determinable.
Carlsbad. In August 2000, a main transmission line owned and operated by
us ruptured at the crossing of the Pecos River near Carlsbad, New Mexico. Twelve
individuals at the site were fatally injured. On June 20, 2001, the U.S.
Department of Transportation's Office of Pipeline Safety issued a Notice of
Probable Violation and Proposed Civil Penalty to us. The Notice alleged five
violations of DOT regulations, proposed fines totaling $2.5 million and proposed
corrective actions. We have fully accrued for these fines. The alleged five
probable violations of the regulations of the Department of Transportation's
Office of Pipeline Safety are: (1) failure to develop an adequate internal
corrosion control program, with an associated proposed fine of $500,000; (2)
failure to investigate and minimize internal corrosion, with an associated
proposed fine of $1,000,000; (3) failure to conduct continuing surveillance on
our pipeline and consider, and respond appropriately to, unusual operating and
maintenance conditions, with an associated proposed fine of $500,000; (4)
failure to follow company procedures relating to investigating pipeline failures
and thereby to minimize the chance of recurrence, with an associated proposed
fine of $500,000; and (5) failure to maintain elevation profile drawings, with
an associated proposed fine of $25,000. On October 2001, we filed a response
with the Office of Pipeline Safety disputing each of the alleged violations. If
we are required to pay the proposed fines, it will not have a material adverse
effect on our financial position, operations results or cash flows.
On February 11, 2003, the National Transportation Safety Board conducted a
public meeting on its investigation of the Carlsbad rupture at which the NTSB
adopted Findings, Conclusions and Recommendation based upon its investigation.
In a synopsis of the Safety Board's report, the NTSB stated that it had
determined that the probable cause of the August 19, 2000 rupture was a
significant reduction in pipe wall thickness due to severe internal corrosion,
which occurred because our corrosion control program "failed to prevent, detect,
or control internal corrosion" in the pipeline. The NTSB also determined that
ineffective federal preaccident inspections contributed to the accident by not
identifying deficiencies in our internal corrosion control program. The NTSB's
final report is pending.
On November 1, 2002, we received a federal grand jury subpoena for
documents relating to the rupture and we are cooperating fully with the grand
jury.
F-17
A number of personal injury and wrongful death lawsuits were filed against
us in connection with the rupture. All but one of these suits have been settled,
with settlement payments fully covered by insurance. The remaining case is
Geneva Smith, et al. vs. EPEC and EPNG filed October 23, 2000 in Harris County,
Texas. In connection with the settlement of the cases, we contributed $10
million to a charitable foundation as a memorial to the families involved. The
contribution was not covered by insurance.
Parties to five settled lawsuits have since filed an additional lawsuit
titled Diane Heady et al. v. EPEC and EPNG in Harris County, Texas on November
20, 2002 seeking an additional $180 million based upon their interpretation of
earlier agreements. In addition, plaintiffs' counsel for the settled New Mexico
state court cases have notified us that they intend to file suit on behalf of
about twenty-three firemen and EMS personnel who responded to the fire and who
allegedly have suffered psychological trauma. We have not been served with such
a lawsuit. Our costs and legal exposure related to these lawsuits and claims are
currently not determinable. However, we believe these matters will be fully
covered by insurance.
Grynberg. In 1997, we and a number of our affiliates were named defendants
in actions brought by Jack Grynberg on behalf of the U.S. Government under the
False Claims Act. Generally, these complaints allege an industry-wide conspiracy
to underreport the heating value as well as the volumes of the natural gas
produced from federal and Native American lands, which deprived the U.S.
Government of royalties. The plaintiff in this case seeks royalties that he
contends the government should have received had the volume and heating value of
natural gas produced from royalty properties been differently measured,
analyzed, calculated and reported, together with interest, treble damages, civil
penalties, expenses and future injunctive relief to require the defendants to
adopt allegedly appropriate gas measurement practices. No monetary relief has
been specified in this case. These matters have been consolidated for pretrial
purposes (In re: Natural Gas Royalties Qui Tam Litigation, U.S. District Court
for the District of Wyoming, filed June 1997). In May 2001, the court denied the
defendants' motions to dismiss. Discovery is proceeding. Our costs and legal
exposure related to these lawsuits and claims are currently not determinable.
Will Price (formerly Quinque). We and a number of our affiliates were
named defendants in Quinque Operating Company et al v. Gas Pipelines and Their
Predecessors, et al, filed in 1999 in the District Court of Stevens County,
Kansas. Quinque has been dropped as a plaintiff and Will Price has been added.
This class action complaint alleges that the defendants mismeasured natural gas
volumes and heating content of natural gas on non-federal and non-Native
American lands. The plaintiff in this case seeks certification of a nationwide
class of natural gas working interest owners and natural gas royalty owners to
recover royalties that the plaintiff contends these owners should have received
had the volume and heating value of natural gas produced from their properties
been differently measured, analyzed, calculated and reported, together with
prejudgment and postjudgment interest, punitive damages, treble damages,
attorney's fees, costs and expenses, and future injunctive relief to require the
defendants to adopt allegedly appropriate gas measurement practices. No monetary
relief has been specified in this case. Plaintiff's motion for class
certification has been argued and we are awaiting a ruling. Our costs and legal
exposure related to these lawsuits and claims are currently not determinable.
In addition to the above matters, we and our subsidiaries and affiliates
are named defendants in numerous lawsuits and governmental proceedings that
arise in the ordinary course of our business.
For each of our outstanding legal matters, we evaluate the merits of the
case, our exposure in the matter, possible legal or settlement strategies and
the likelihood of an unfavorable outcome. If we determine that an unfavorable
outcome is probable and can be estimated, we establish the necessary accruals.
As of December 31, 2002, we had accrued approximately $415 million for all
outstanding legal matters.
Environmental Matters
We are subject to federal, state and local laws and regulations governing
environmental quality and pollution control. These laws and regulations require
us to remove or remedy the effect on the environment of the disposal or release
of specified substances at current and former operating sites. As of December
31,
F-18
2002, we had accrued approximately $29 million for expected remediation costs at
current and former sites and associated onsite, offsite and groundwater
technical studies and for related environmental legal costs, which we anticipate
incurring through 2027.
In addition, we expect to make capital expenditures for environmental
matters of approximately $4 million in the aggregate for the years 2003 through
2007. These expenditures primarily relate to compliance with clean air
regulations. For 2003, we estimate that our total remediation expenditures will
be approximately $7 million, which primarily will be expended under government
directed clean-up plans.
CERCLA Matters. We have received notice that we could be designated, or
have been asked for information to determine whether we could be designated, as
a Potentially Responsible Party (PRP) with respect to four active sites under
the Comprehensive Environmental Response, Compensation and Liability Act
(CERCLA) or state equivalents. We have sought to resolve our liability as a PRP
at these sites through indemnification by third parties and settlements which
provide for payment of our allocable share of remediation costs. As of December
31, 2002, we have estimated our share of the remediation costs at these sites to
be between $14 million and $18 million. Since the clean-up costs are estimates
and are subject to revision as more information becomes available about the
extent of remediation required, and because in some cases we have asserted a
defense to any liability, our estimates could change. Moreover, liability under
the federal CERCLA statute is joint and several, meaning that we could be
required to pay in excess of our pro rata share of remediation costs. Our
understanding of the financial strength of other PRPs has been considered, where
appropriate, in determining our estimated liabilities.
It is possible that new information or future developments could require us
to reassess our potential exposure related to environmental matters. We may
incur significant costs and liabilities in order to comply with existing
environmental laws and regulations. It is also possible that other developments,
such as increasingly strict environmental laws and regulations and claims for
damages to property, employees, other persons and the environment resulting from
our current or past operations, could result in substantial costs and
liabilities in the future. As this information becomes available, or other
relevant developments occur, we will adjust our accrual amounts accordingly.
While there are still uncertainties relating to the ultimate costs we may incur,
based upon our evaluation and experience to date, we believe the reserves are
adequate.
Rates and Regulatory Matters
CPUC Complaint Proceeding. In April 2000, the CPUC filed a complaint under
Section 5 of the Natural Gas Act (NGA) with the FERC alleging that our sale of
approximately 1.2 billion cubic feet per day of capacity to our affiliate, El
Paso Merchant Energy Company (EPME), raised issues of market power and violation
of FERC's marketing affiliate regulations and asked that the contracts be
voided. Although the FERC held that we did not violate its marketing affiliate
requirements, it established a hearing before an ALJ to address the market power
issue. In the spring and summer of 2001, two hearings were held before the ALJ
to address the market power issue and, at the request of the ALJ, the affiliate
issue. In October 2001, the ALJ issued an initial decision on the two issues,
finding that the record did not support a finding that either we or EPME had
exercised market power and that accordingly the market power claims against us
should be dismissed. The ALJ found, however, that we had violated FERC's
marketing affiliate rule. We and other parties filed briefs on exceptions and
briefs opposing exceptions to the October initial decision.
Also, in October 2001, the FERC's Office of Market Oversight and
Enforcement filed comments stating that the record at the hearings was
inadequate to conclude that we had complied with FERC regulations in the
transportation of gas to California. In December 2001, the FERC remanded the
proceeding to the ALJ for a supplemental hearing on the availability of capacity
at our California delivery points. On September 23, 2002, the ALJ issued his
initial decision, again finding that there was no evidence that EPME had
exercised market power during the period at issue to drive up California gas
prices and therefore recommending that the complaint against EPME be dismissed.
However, the ALJ found that we had withheld at least 345 MMcf/d of capacity (and
perhaps as much as 696 MMcf/d)
F-19
from the California market during the period from November 1, 2000 through March
31, 2001. The ALJ found that this alleged withholding violated our certificate
obligations and was an exercise of market power that increased the gas price to
California markets. He therefore recommended that the FERC initiate penalty
procedures against us. We and others filed briefs on exceptions to the initial
decision on October 23, 2002; briefs opposing exceptions were filed on November
12, 2002. This proceeding will be resolved upon finalization and approval of the
Western Energy Settlement.
Systemwide Capacity Allocation Proceeding. In July 2001, several of our
contract demand or CD customers filed a complaint against us at the FERC
claiming, among other things, that our full requirements contracts or FR
contracts (contracts with no volumetric limitations) should be converted to CD
contracts, and that we should be required to expand our system and give demand
charge credits to CD customers when we are unable to meet their full contract
demands. In July 2001, several of our FR customers filed a complaint alleging
that we had violated the Natural Gas Act and our contractual obligations to them
by not expanding our system, at our cost, to meet their increased requirements.
On May 31, 2002, the FERC issued an order on the complaints in which it
required that (i) FR service, for all FR customers except small volume
customers, be converted to CD service; (ii) firm customers be assigned specific
receipt point rights in lieu of their existing systemwide receipt point rights;
(iii) reservation charge credits be given to all firm customers for failure to
schedule confirmed volumes except in cases of force majeure; (iv) no new firm
contracts be executed until we have demonstrated there is adequate capacity on
the system; and (v) a process be implemented to allow existing CD customers to
turn back capacity for acquisition by FR customers in which process we would
remain revenue neutral. These changes were to be made effective November 1,
2002. The order also stated that the FERC expected us to file for certificate
authority to add compression to Line 2000 to increase our system capacity by 320
MMcf/d without cost coverage until our next rate case (i.e. January 1, 2006). We
had previously informed the FERC that we were willing to add compression to Line
2000 provided we were assured of rate coverage in the next rate case. On July 1,
2002, we and other parties filed for clarification and/or rehearing of the May
31 order.
On September 20, 2002, at the urging of the FR shippers, the FERC issued an
order postponing until May 1, 2003 the effective date of the FR conversions.
That order also required us to allocate among our FR customers (i) the 320
MMcf/d of capacity that will be available from the addition of compression to
Line 2000, and (ii) any firm capacity that expires under existing contracts
between May 31, 2002, and May 1, 2003, thereby precluding us from reselling that
capacity. In total, the September 20 order requires that our FR customers pay
only their current aggregate reservation charges for existing unsubscribed
capacity, for the 230 MMcf/d of capacity made available in November 2002 by our
Line 2000 project, for the 320 MMcf/d of capacity from the addition of
compression to Line 2000, and for all capacity subject to contracts expiring
before May 1, 2003. Beginning May 1, 2003, we will be required to pay
reservation charge credits when we are unable to schedule confirmed volumes
except in cases of force majeure. Until May 1, 2003, we are required to pay
partial reservation charge credits to CD customers when we are unable to
schedule 95 percent of their monthly confirmed volumes except for reasons of
force majeure and provided that there is no capacity available from other supply
basins on our system.
Several pleadings have been filed in response to the September 20 order,
including rehearing requests and requests by several customers to modify the
order based on the ALJ's decision in the CPUC Complaint Proceeding discussed
above. All such pleadings remain pending before the FERC. In the interim, we are
proceeding with the directives contained in the September 20 order.
On October 7, 2002, we filed tariff sheets in compliance with the September
20 order to implement a partial demand charge credit for the period November 1,
2002 to May 31, 2003, and to allow California delivery points to be used as
secondary receipt points to the extent of our backhaul displacement
capabilities. We proposed both a reservation and a usage charge for this
service. On December 26, 2002, the FERC issued an order (i) denying our request
to charge existing CD customers a reservation rate for California receipt
service for the remaining term of the settlement, i.e., through December 31,
2005; (ii) allowing us to charge our maximum IT rate for the service; (iii)
approving our proposed usage rate
F-20
for the service until our next rate case; and (iv) requiring us to make a
showing that capacity is available for any new shippers utilizing this service.
We made a revised tariff filing on January 10, 2003, in compliance with the
December 26 order. On January 27, 2003, we filed a request for rehearing on
certain aspects of the December 26 order. That request is pending.
Rate Settlement. Our current rate settlement establishes our base rates
through December 31, 2005. Under the settlement, our base rates began escalating
annually in 1998 for inflation. We have the right to increase or decrease our
base rates if changes in laws or regulations result in increased or decreased
costs in excess of $10 million a year. In addition, all of our settling
customers participate in risk sharing provisions. Under these provisions, we
will receive cash payments in total of $295 million for a portion of the risk we
assumed from capacity relinquishments by our customers (primarily capacity
turned back to us by Southern California Gas Company and Pacific Gas & Electric
Company which represented approximately one-third of the capacity of our system)
during 1996 and 1997. The cash we received was deferred, and we recognize this
amount in revenues ratably over the risk sharing period. As of December 31,
2002, we had unearned risk sharing revenues of approximately $32 million and had
$13 million remaining to be collected from customers under this provision.
Amounts received for relinquished capacity sold to customers, above certain
dollar levels specified in our rate settlement, obligate us to refund a portion
of the excess to customers. Under this provision, we refunded $46 million of
2001 revenues to customers during 2001 and 2002. During 2002, we established an
additional refund obligation of $46 million, of which $32 million was refunded
in 2002. The remainder will be refunded in 2003. Both the risk and revenue
sharing provisions of the rate settlement extend through 2003.
Line 2000 Project. On July 31, 2000, we applied with the FERC for a
certificate of public convenience and necessity for our Line 2000 project, which
was designed to replace old compression on the system with a converted oil
pipeline, resulting in no increase in system capacity. In response to demand
conditions on our system, however, we filed in March 2001 to amend our
application to convert the project to an expansion project of 230 MMcf/d. On May
7, 2001, the FERC authorized the amended Line 2000 project. We placed the line
in service in November 2002 at an approximate capital cost of $185 million. The
cost of the Line 2000 conversion will not be included in our rates until our
next rate case, which will be effective on January 1, 2006.
On October 3, 2002, pursuant to the FERC's May 31 and September 20 orders
in the systemwide capacity allocation proceeding, we filed with the FERC for a
certificate of public convenience and necessity to add compression to our Line
2000 project to increase the capacity of that line by an additional 320 MMcf/d
at an estimated capital cost of approximately $173 million for all phases. That
application has been protested, and remains pending. In our request for
clarification of the September 20 order, we have asked for assurances from the
FERC that we will be able to begin cost recovery for this project at the time
our next rate case becomes effective. That request remains pending.
Marketing Affiliate NOPR. In September 2001, the FERC issued a Notice of
Proposed Rulemaking (NOPR). The NOPR proposes to apply the standards of conduct
governing the relationship between interstate pipelines and marketing affiliates
to all energy affiliates. The proposed regulations, if adopted by the FERC,
would dictate how we conduct business and interact with our energy affiliates.
In December 2001, we filed comments with the FERC addressing our concerns with
the proposed rules. A public hearing was held on May 21, 2002, providing an
opportunity to comment further on the NOPR. Following the conference, additional
comments were filed by El Paso's pipelines and others. At this time, we cannot
predict the outcome of the NOPR, but adoption of the regulations in their
proposed form would, at a minimum, place additional administrative and
operational burdens on us.
Negotiated Rate NOI. In July 2002, the FERC issued a Notice of Inquiry
(NOI) that seeks comments regarding its 1996 policy of permitting pipelines to
enter into negotiated rate transactions. We have entered into these transactions
over the years, and the FERC is now reviewing whether negotiated rates should be
capped, whether or not the "recourse rate" (a cost-of-service based rate)
continues to safeguard against a pipeline exercising market power and other
issues related to negotiated rate programs.
F-21
On September 25, 2002, El Paso's pipelines and others filed comments. Reply
comments were filed on October 25, 2002. At this time, we cannot predict the
outcome of this NOI.
Cash Management NOPR. On August 1, 2002, the FERC issued a NOPR requiring
that all cash management or money pool arrangements between a FERC regulated
subsidiary (like us) and a non-FERC regulated parent must be in writing, and set
forth the duties and responsibilities of cash management participants and
administrators; the methods of calculating interest and for allocating interest
income and expenses; and the restrictions on deposits or borrowings by money
pool members. The NOPR also requires specified documentation for all deposits
into, borrowings from, interest income from, and interest expenses related to,
these arrangements. Finally, the NOPR proposed that as a condition of
participating in a cash management or money pool arrangement, the FERC regulated
entity maintain a minimum proprietary capital balance of 30 percent, and the
FERC regulated entity and its parent maintain investment grade credit ratings.
On August 28, 2002, comments were filed. The FERC held a public conference on
September 25, 2002, to discuss the issues raised in the comments.
Representatives of companies from the gas and electric industries participated
on a panel and uniformly agreed that the proposed regulations should be revised
substantially and that the proposed capital balance and investment grade credit
rating requirements would be excessive. At this time, we cannot predict the
outcome of this NOPR.
Also on August 1, 2002, the FERC's Chief Accountant issued an Accounting
Release, which was effective immediately. The Accounting Release provides
guidance on how companies should account for money pool arrangements and the
types of documentation that should be maintained for these arrangements.
However, it did not address the proposed requirements that the FERC regulated
entity maintain a minimum proprietary capital balance of 30 percent and that the
entity and its parent have investment grade credit ratings. Requests for
rehearing were filed on August 30, 2002. The FERC has not yet acted on the
rehearing requests.
Emergency Reconstruction of Interstate Natural Gas Facilities NOPR. On
January 17, 2003, FERC issued a NOPR proposing to (1) expand the scope of
construction activities authorized under a pipeline's blanket certificate to
allow replacement of mainline facilities; (2) authorize a pipeline to commence
reconstruction of the affected system without a waiting period; and (3)
authorize automatic approval of construction that would be above the normal cost
ceiling. Comments on the NOPR were filed on February 27, 2003. At this time, we
cannot predict the outcome of this rulemaking.
Pipeline Safety Notice of Proposed Rulemaking. On January 28, 2003, the
U.S. Department of Transportation issued a NOPR proposing to establish a rule
requiring pipeline operators to develop integrity management programs to
comprehensively evaluate their pipelines, and take measures to protect pipeline
segments located in what the notice refers to as "high consequence areas." The
proposed rule resulted from the enactment of the Pipeline Safety Improvement Act
of 2002, a new bill signed into law in December 2002. We intend to submit
comments on the NOPR, which are due on or before April 30, 2003. At this time,
we cannot predict the outcome of this rulemaking.
Other Matters
Enron Bankruptcy. In December 2001, Enron Corp. and a number of its
subsidiaries, including Enron North America Corp. and Enron Power Marketing,
Inc., filed for Chapter 11 bankruptcy protection in the United States Bankruptcy
Court for the Southern District of New York. Enron North America had
transportation contracts on our system. The transportation contracts have now
been rejected and we have filed a proof of claim in the amount of approximately
$128 million, which included $18 million for amounts due for services provided
through the date the contracts were rejected and $110 million for damage claims
arising from the rejection of its transportation contracts. The September 20
order capacity allocation proceeding discussed in Rates and Regulatory Matters
above prohibits us from remarketing Enron capacity that was not remarketed prior
to May 31, 2002. We have sought rehearing of the September 20 order. We have
fully reserved for all amounts due from Enron through the date the
F-22
contracts were rejected, and we have not recognized any amounts under these
contracts since the rejection date.
While the outcome of our outstanding legal matters, environmental matters,
and rates and regulatory matters cannot be predicted with certainty, based on
current information and our existing accruals, we do not expect the ultimate
resolution of these matters to have a material adverse effect on our financial
position, operating results or cash flows. However, it is possible that new
information or future developments could require us to reassess our potential
exposure related to these matters. It is also possible that these matters could
impact our debt rating and the credit rating of our parent. Further, for
environmental matters, it is also possible that other developments, such as
increasingly strict environmental laws and regulations and claims for damages to
property, employees, other persons and the environment resulting from our
current or past operations, could result in substantial costs and liabilities in
the future. As new information for our outstanding legal matters, environmental
matters and rates and regulatory matters becomes available, or relevant
developments occur, we will review our accruals and make any appropriate
adjustments. The impact of these changes may have a material effect on our
results of operations, our financial position, and on our cash flows in the
period the event occurs.
Capital Commitments
At December 31, 2002, we had capital and investment commitments of $30
million for 2003 primarily relating to ongoing capital projects. Our other
planned capital and investment projects are discretionary in nature, with no
substantial capital commitments made in advance of the actual expenditures.
Operating Leases
We lease property, facilities and equipment under various operating leases.
Minimum annual rental commitments at December 31, 2002, were as follows:
YEAR ENDING
DECEMBER 31, OPERATING LEASES
------------ ----------------
(IN MILLIONS)
2003..................................................... $13
2004..................................................... 13
2005..................................................... 14
2006..................................................... 14
2007..................................................... 6
Thereafter............................................... --
---
Total............................................. $60
===
Aggregate minimum commitments have not been reduced by minimum sublease
rentals of approximately $7 million due in the future under noncancelable
subleases. In addition, as part of our relocation from El Paso to Colorado
Springs, we accrued these minimum lease commitments as merger-related charges.
These accruals were reduced by our estimated minimum sublease rentals.
Rental expense for operating leases for each of the years ended December
31, 2002, 2001 and 2000 was $3 million, $3 million and $10 million.
Guarantees
As of December 31, 2002, we had the following guarantees:
Pipeline Joint Venture -- In 1997, we entered into a joint venture to
construct a pipeline that extends from Bolivia to Brazil. In connection with the
joint venture, we issued a financial guarantee with a maximum potential exposure
of approximately $11 million to cover the need to increase our equity in the
project. Our guarantee expires in July 2018. As of December 31, 2002, we do not
have a liability recorded for this guarantee.
F-23
Lease -- In 1996, we entered into a lease with Oxford Properties for office
space located in Calgary, Canada. In connection with this lease, we issued a
financial guarantee with a maximum potential exposure of approximately $500
thousand to cover any non-payments of rental fees on this property. Our
guarantee expires in March 2003. As of December 31, 2002, we do not have a
liability recorded for this guarantee.
See Note 7 beginning on page F-13 for a discussion of our obligations
related to El Paso's revolving credit facilities.
9. RETIREMENT BENEFITS
Pension and Retirement Benefits
Prior to January 1, 1997, El Paso maintained a defined benefit pension plan
covering substantially all of our employees. Pension benefits were based on
years of credited service and final five year average compensation, subject to
maximum limitations as defined in the pension plan. Effective January 1, 1997,
the plan was amended to provide benefits determined by a cash balance formula.
Employees who were pension plan participants on December 31, 1996, receive the
greater of cash balance benefits or prior plan benefits accrued through December
31, 2001. In addition, El Paso maintains a defined contribution plan covering
its U.S. employees, including our employees. Prior to May 1, 2002, El Paso
matched 75 percent of participant basic contributions up to 6 percent, with the
matching contributions being made to the plan's stock fund, which participants
could diversify at any time. After May 1, 2002, the plan was amended to allow
for matching contributions to be invested in the same manner as that of
participant contributions. Effective March 1, 2003, El Paso suspended the
matching contribution. El Paso is responsible for benefits accrued under its
plans and allocates the related costs to its affiliates. See Note 11 beginning
on page F-26 for a summary of transactions with affiliates.
Other Postretirement Benefits
We provide postretirement medical benefits for a closed group of employees
who retired on or before March 1, 1986, and limited postretirement life
insurance for employees who retired after January 1, 1985. As such, our
obligation to accrue for other postretirement employee benefits (OPEB) is
primarily limited to the fixed population of retirees who retired on or before
March 1, 1986. The medical plan is pre-funded to the extent employer
contributions are recoverable through rates. To the extent actual OPEB costs
differ from amounts recovered in rates, a regulatory asset or liability is
recorded.
The following table sets forth the change in benefit obligation, change in
plan assets, reconciliation of funded status, and components of net periodic
benefit cost for other postretirement benefits as of and for the twelve months
ended September 30:
2002 2001
----- -----
(IN MILLIONS)
Change in benefit obligation
Benefit obligation at beginning of period................. $ 95 $ 83
Interest cost............................................. 7 6
Actuarial loss............................................ 5 13
Benefits paid............................................. (7) (7)
---- ----
Benefit obligation at end of period....................... $100 $ 95
==== ====
Change in plan assets
Fair value of plan assets at beginning period............. $ 61 $ 77
Actual return on plan assets.............................. (5) (20)
Employer contributions.................................... 11 11
Benefits paid............................................. (7) (7)
---- ----
Fair value of plan assets at end of period................ $ 60 $ 61
==== ====
F-24
2002 2001
----- -----
(IN MILLIONS)
Reconciliation of funded status
Funded status as of September 30.......................... $(40) $(34)
Fourth quarter contributions.............................. 3 3
Unrecognized net actuarial gain........................... 28 14
Unrecognized net transition obligation.................... 23 31
---- ----
Prepaid benefit cost at December 31....................... $ 14 $ 14
==== ====
YEAR ENDED
DECEMBER 31,
--------------------
2002 2001 2000
---- ---- ----
(IN MILLIONS)
Postretirement benefit costs for the plans includes the
following components
Interest cost............................................. $ 7 $ 6 $ 7
Expected return on plan assets............................ (4) (5) (4)
Amortization of net actuarial gain........................ -- (1) (1)
Amortization of transition obligation..................... 8 8 7
--- --- ---
Net postretirement benefit cost........................... $11 $ 8 $ 9
=== === ===
Postretirement benefit obligations are based upon actuarial estimates as
described below.
2002 2001
----- -----
Weighted average assumptions
Discount rate............................................. 6.75% 7.25%
Expected return on plan assets............................ 7.50% 7.50%
Actuarial estimates for our postretirement benefits plans assume a weighted
average annual rate of increase in the per capita costs of covered health care
benefits of 11.0 percent in 2002, gradually decreasing to 5.5 percent by the
year 2008. Assumed health care cost trends have a significant effect on the
amounts reported for other postretirement benefit plans. A one-percentage point
change in assumed health care cost trends would have the following effects:
2002 2001
----- -----
(IN MILLIONS)
One Percentage Point Increase
Aggregate of Service Cost and Interest Cost............... $ 1 $ 1
Accumulated Postretirement Benefit Obligation............. $ 8 $ 8
One Percentage Point Decrease
Aggregate of Service Cost and Interest Cost............... $ (1) $ (1)
Accumulated Postretirement Benefit Obligation............. $ (8) $ (7)
10. PREFERRED STOCK
In December 1998, we issued 500,000 shares of 8% Cumulative Preferred Stock
to El Paso. We used the proceeds of $350 million to reduce our outstanding debt.
El Paso is entitled to receive dividends at the rate of 8% on a liquidation
value of $700 per share annually. On or after January 1, 2003, these shares are
redeemable at our option, in whole or in part, upon not less than 30 days'
notice at a redemption price of $700 per share, plus unpaid dividends. For each
of the years ended December 31, 2002, 2001 and 2000 we paid $28 million in
dividends on our preferred stock. At December 31, 2002, we had accrued $2
million in dividends payable on our 8% preferred stock.
F-25
11. TRANSACTIONS WITH AFFILIATES
Subject to the limitation on Mojave as described in Note 7 beginning on
page F-13, we participate in El Paso's cash management program which matches
short-term cash surpluses and need requirements of participating affiliates,
thus minimizing total borrowing from outside sources. Our continued
participation in the program may be dependent on any final rule issued by the
FERC in connection with its cash management notice of proposed rulemaking
discussed under Note 8 beginning on page F-15. As of December 31, 2002 and
December 31, 2001, we had a cumulative net receivable from El Paso of $990
million and $1,294 million. The rate of interest at December 31, 2002 and 2001,
was 1.5% and 2.1%. These receivables are due upon demand; however, as of
December 31, 2002, we have classified $565 million as non-current because we do
not anticipate settlement within the next twelve months.
At December 31, 2002 and 2001, we had other accounts receivable from
related parties of $7 million and $4 million. In addition, we had accounts
payable to affiliates of $33 million at December 31, 2002, versus $9 million at
December 31, 2001. These balances arose in the normal course of business. As a
result of El Paso's credit rating downgrades, we maintained $5 million as of
December 31, 2002 in contractual deposits related to an affiliate's
transportation contract on our EPNG system.
During 2002 and 2000, we distributed assets to our parent through a
dividend with net book values of $19 million and $9 million.
El Paso allocated a portion of its general and administrative expenses to
us. The allocation is based on the estimated level of effort devoted to our
operations and the relative size of our EBIT, gross property and payroll. For
the years ended December 31, 2002, 2001 and 2000, the annual charges were $49
million, $43 million and $58 million. During 2002 and 2001, Tennessee Gas
Pipeline allocated payroll to us and other expenses associated with our shared
pipeline services. The allocated expenses are based on the estimated level of
staff and their expenses to provide the services. For the years ended 2002 and
2001, the annual charges were $6 million. El Paso Field Services allocated
payroll and other expenses to us. During 2002, 2001 and 2000 those amounts were
$9 million, $7 million and $6 million. In addition, during 2002 and 2001 we
performed operational, financial, accounting and administrative services for, an
affiliate, Colorado Interstate Gas Company. These services are recorded as
reimbursement of operating expenses and for 2002 and 2001 were $12 million and
$7 million. We believe all the allocation methods are reasonable.
We provided El Paso Merchant Energy L.P. transportation services for the
years ended 2002, 2001 and 2000. We recognized revenues of $46 million, $72
million and $35 million for these periods. We entered into these transactions in
the ordinary course of business and the services were based on the same terms as
non-affiliates.
The following table shows revenues and charges from our affiliates:
YEARS ENDED
DECEMBER 31,
--------------------
2002 2001 2000
---- ---- ----
(IN MILLIONS)
Revenues from affiliates.................................... $46 $72 $35
Operation and maintenance costs from affiliates............. 64 56 64
Reimbursement of operating expenses......................... 12 7 --
F-26
12. TRANSACTIONS WITH MAJOR CUSTOMER
The following table shows revenues from our major customer for the years
ended December 31:
2002 2001 2000
---- ---- ----
(IN MILLIONS)
Southern California Gas Company........................... $139 $135 $132
---------------
(1) Our contracts with Southern California Gas Company include 1,235 BBtu/d
which expires in 2006 and 95 BBtu/d which expires 2004 through 2007.
13. SUPPLEMENTAL CASH FLOW INFORMATION
The following table contains supplemental cash flow information for the
years ended December 31:
2002 2001 2000
---- ---- ----
(IN MILLIONS)
Interest paid............................................... $78 $84 $99
Income tax payments......................................... 33 14 23
14. SUPPLEMENTAL SELECTED QUARTERLY FINANCIAL INFORMATION (UNAUDITED)
Financial information by quarter is summarized below:
QUARTERS ENDED
-------------------------------------------------------
DECEMBER 31 SEPTEMBER 30 JUNE 30 MARCH 31 TOTAL
----------- ------------ ------- -------- -----
(IN MILLIONS)
2002
Operating revenues.............. $ 129 $139 $144 $152 $ 564
Operating (loss) income......... (342) 77 79 81 (105)
Income (loss) from continuing
operations................... (225) 38 44 44 (99)
Net income (loss)............... (225) 38 44 44 (99)
2001
Operating revenues.............. $ 145 $148 $138 $141 $ 572
Merger-related costs............ 1 (5) 94 8 98
Operating income (loss)......... 69 75 (25) 67 186
Income (loss) from continuing
operations................... 36 40 (21) 40 95
Net income (loss)............... 36 40 (21) 40 95
F-27
SCHEDULE II
EL PASO NATURAL GAS COMPANY
VALUATION AND QUALIFYING ACCOUNTS
YEARS ENDED DECEMBER 31, 2002, 2001 AND 2000
(IN MILLIONS)
BALANCE AT CHARGED TO CHARGED TO BALANCE
BEGINNING COSTS AND OTHER AT END
DESCRIPTION OF PERIOD EXPENSES ACCOUNTS DEDUCTIONS OF PERIOD
----------- ---------- ---------- ---------- ---------- ---------
2002
Allowance for doubtful accounts....... $ 6 $ 12 $ -- $ -- $ 18
Legal reserves........................ 2 423(1) -- (10)(2) 415
Environmental reserves................ 29 -- -- -- 29
Provision for refunds................. 19 46 -- (52)(3) 13
2001
Allowance for doubtful accounts....... $ 2 $ 6 $ -- $ (2) $ 6
Legal reserves........................ -- 2 -- -- 2
Environmental reserves................ 25 4 -- -- 29
Provision for refunds................. 15 6 -- (2) 19
2000
Allowance for doubtful accounts....... $ 1 $ 1 $ -- $ -- $ 2
Legal reserves........................ 3 -- -- (3) --
Environmental reserves................ 22 3 -- -- 25
Provision for refunds................. 49 1 -- (35)(4) 15
---------------
(1) Includes a $412 million charge for the Western Energy Settlement.
(2) Relates to settlements paid.
(3) Relates to amounts paid for our risk sharing provisions with customers.
(4) Relates to the resolution of a contested rate matter.
F-28
EL PASO NATURAL GAS COMPANY
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(IN MILLIONS)
(UNAUDITED)
QUARTER ENDED SIX MONTHS ENDED
JUNE 30, JUNE 30,
--------------- ----------------
2003 2002 2003 2002
----- ---- ----- -----
Operating revenues........................................ $ 134 $144 $266 $296
----- ---- ---- ----
Operating expenses
Operation and maintenance............................... 52 43 86 93
Depreciation, depletion and amortization................ 16 17 33 30
Western Energy Settlement............................... 146 -- 146 --
Gain on long-lived assets............................... -- (3) -- (4)
Taxes, other than income taxes.......................... 7 5 15 13
----- ---- ---- ----
221 62 280 132
----- ---- ---- ----
Operating income (loss)................................... (87) 82 (14) 164
Other income.............................................. 1 -- 2 --
Interest and debt expense................................. (20) (18) (40) (34)
Affiliated interest income, net........................... 4 6 7 12
----- ---- ---- ----
Income (loss) before income taxes......................... (102) 70 (45) 142
Income taxes.............................................. (39) 26 (17) 54
----- ---- ---- ----
Net income (loss)......................................... $ (63) $ 44 $(28) $ 88
===== ==== ==== ====
See accompanying notes.
F-29
EL PASO NATURAL GAS COMPANY
CONDENSED CONSOLIDATED BALANCE SHEETS
(IN MILLIONS, EXCEPT SHARE AMOUNTS)
(UNAUDITED)
JUNE 30, DECEMBER 31,
2003 2002
-------- ------------
ASSETS
Current assets
Cash and cash equivalents................................. $ -- $ 3
Accounts and notes receivable
Customer, net of allowance of $18 in 2003 and 2002..... 75 79
Affiliates............................................. 204 432
Other.................................................. 16 13
Materials and supplies.................................... 43 43
Deferred income taxes..................................... 145 36
Other..................................................... 22 27
------ ------
Total current assets.............................. 505 633
------ ------
Property, plant and equipment, at cost...................... 3,087 3,060
Less accumulated depreciation, depletion and
amortization........................................... 1,163 1,152
------ ------
Total property, plant and equipment, net.......... 1,924 1,908
------ ------
Notes receivable from affiliate............................. 845 565
Other....................................................... 81 83
------ ------
Total assets...................................... $3,355 $3,189
====== ======
LIABILITIES AND STOCKHOLDER'S EQUITY
Current liabilities
Accounts payable
Trade.................................................. $ 36 $ 43
Affiliates............................................. 20 33
Other.................................................. 3 11
Current maturities of long-term debt...................... 200 200
Accrued interest.......................................... 15 15
Taxes payable............................................. 78 133
Contractual deposits...................................... 30 35
Western Energy Settlement................................. 556 100
Other..................................................... 44 53
------ ------
Total current liabilities......................... 982 623
------ ------
Long-term debt, less current maturities..................... 758 758
------ ------
Other liabilities
Deferred income taxes..................................... 368 221
Western Energy Settlement................................. -- 312
Other..................................................... 119 122
------ ------
487 655
------ ------
Commitments and contingencies
Stockholder's equity
Preferred stock, 8%, par value $0.01 per share; authorized
1,000,000 shares; issued and outstanding 500,000
shares; stated at liquidation value.................... -- 350
Common stock, par value $1 per share; authorized and
issued 1,000 shares.................................... -- --
Additional paid-in capital................................ 1,074 715
Retained earnings......................................... 54 88
------ ------
Total stockholder's equity........................ 1,128 1,153
------ ------
Total liabilities and stockholder's equity........ $3,355 $3,189
====== ======
See accompanying notes.
F-30
EL PASO NATURAL GAS COMPANY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(IN MILLIONS)
(UNAUDITED)
SIX MONTHS
ENDED
JUNE 30,
-------------
2003 2002
----- -----
Cash flows from operating activities
Net income (loss)......................................... $ (28) $ 88
Adjustments to reconcile net income (loss) to net cash
from operating activities
Depreciation, depletion and amortization............... 33 30
Deferred income tax expense............................ 36 17
Net gain on long-lived assets.......................... -- (4)
Risk-sharing revenue................................... (16) (16)
Bad debt expense....................................... -- 12
Western Energy Settlement.............................. 136 --
Other non-cash income items............................ 9 --
Working capital changes................................... (96) 21
Non-working capital changes............................... 39 1
----- -----
Net cash provided by operating activities......... 113 149
----- -----
Cash flows from investing activities
Additions to property, plant and equipment................ (98) (94)
Net proceeds from the sale of assets...................... 38 2
Net change in affiliate advances receivable............... (56) (118)
----- -----
Net cash used in investing activities............. (116) (210)
----- -----
Cash flows from financing activities
Payments to retire long-term debt......................... -- (215)
Net repayments under commercial paper and short-term
credit facilities...................................... -- (21)
Net proceeds from the issuance of long-term debt.......... -- 297
----- -----
Net cash provided by financing activities......... -- 61
----- -----
Net change in cash and cash equivalents..................... (3) --
Cash and cash equivalents
Beginning of period....................................... 3 --
----- -----
End of period............................................. $ -- $ --
===== =====
See accompanying notes.
F-31
EL PASO NATURAL GAS COMPANY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
1. BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
We are an indirect wholly owned subsidiary of El Paso Corporation (El
Paso). We prepared this Quarterly Report on Form 10-Q under the rules and
regulations of the United States Securities and Exchange Commission. Because
this is an interim period filing presented using a condensed format, it does not
include all of the disclosures required by generally accepted accounting
principles. You should read it along with our 2002 Annual Report on Form 10-K,
which includes a summary of our significant accounting policies and other
disclosures. The financial statements as of June 30, 2003, and for the quarters
and six months ended June 30, 2003 and 2002, are unaudited. We derived the
balance sheet as of December 31, 2002, from the audited balance sheet filed in
our 2002 Form 10-K. In our opinion, we have made all adjustments which are of a
normal, recurring nature to fairly present our interim period results. Due to
the seasonal nature of our business, information for interim periods may not
necessarily indicate the results of operations for the entire year. In addition,
prior period information presented in these financial statements includes
reclassifications which were made to conform to the current period presentation.
These reclassifications have no effect on our previously reported net income or
stockholder's equity.
Our accounting policies are consistent with those discussed in our 2002
Form 10-K, except as discussed below:
Accounting for Costs Associated with Exit or Disposal Activities. As of
January 1, 2003, we adopted Statement of Financial Accounting Standards (SFAS)
No. 146, Accounting for Costs Associated with Exit or Disposal Activities. SFAS
No. 146 requires that we recognize costs associated with exit or disposal
activities when they are incurred rather than when we commit to an exit or
disposal plan. There was no initial financial statement impact of adopting this
standard.
Accounting for Guarantees. On January 1, 2003, we adopted Financial
Accounting Standards Board Interpretation (FIN) No. 45, Guarantor's Accounting
and Disclosure Requirements for Guarantees, Including Indirect Guarantees of
Indebtedness of Others. FIN No. 45 requires that we record a liability for all
guarantees, including financial performance and fair value guarantees, issued
after December 31, 2002, at fair value when they are issued. There was no
initial financial statement impact of adopting this standard.
Accounting for Regulated Operations. Our natural gas system is subject to
the jurisdiction of the Federal Energy Regulatory Commission (FERC) in
accordance with the Natural Gas Act of 1938 and the Natural Gas Policy Act of
1978, and we apply the provisions of SFAS No. 71, Accounting for the Effects of
Certain Types of Regulation. We continue to evaluate the application of SFAS No.
71 for changes in the competitive environment and our operating cost structures.
See a further discussion of our accounting for regulated operations in our 2002
Form 10-K.
2. WESTERN ENERGY SETTLEMENT
In June, 2003, El Paso and its affiliated companies, entered into two
definitive agreements (referred to as the Western Energy Settlement) with a
number of public and private claimants, including the states of California,
Washington, Oregon and Nevada to resolve the principal litigation and claims
against us and our affiliates relating to the sale or delivery of natural gas
and/or electricity to or in the Western United States from September 1996 to the
date of the settlement. For a further discussion of these settlements, including
our guarantee of El Paso and El Paso Merchant Energy L.P.'s (EPME), an affiliate
of El Paso, obligations, see Note 5 beginning on page F-34. In connection with
our obligations related to the Western Energy Settlement, we agreed to pay (i)
cash totaling approximately $350 million and (ii) an amount equal to the
proceeds from the issuance, by El Paso, of El Paso common stock, to be issued on
behalf of the settling parties.
F-32
The definitive settlement agreements modified the agreement in principle
reached on March 20, 2003 discussed in our 2002 Form 10-K, and resulted in an
additional obligation and a pre-tax charge of $146 million during the second
quarter of 2003. The charge was a result of changes in the timing of settlement
payments and changes in the value of common stock to be issued in connection
with the definitive settlement agreements. This charge was also in addition to
accretion expense on the originally recorded discounted Western Energy
Settlement obligation and other charges included as part of operation and
maintenance expense of $8 million during the second quarter of 2003. For the six
months ended June 30, 2003 these accretion and other charges were approximately
$12 million. As of June 30, 2003, our total Western Energy Settlement obligation
was $556 million, all of which is reflected as a current liability since we
estimate the finalization on the settlement to occur in the next twelve months.
The obligation related to the stock was approximately $213 million which is also
classified as current. This stock-related obligation will continue to impact our
income statement positively or negatively based upon changes in El Paso's stock
price until the settling parties elect to have the shares issued on their
behalf. As of June 30, 2003, $10 million had been paid related to these
settlement obligations.
3. DIVESTITURES
During the first six months of 2003, we sold a non-pipeline asset with a
net book value of approximately $38 million. Net proceeds from the sale were
approximately $38 million, including approximately $8 million from our parent,
and no gain or loss was recognized on the sale of this asset.
4. DEBT AND OTHER CREDIT FACILITIES
In July 2003, we issued $355 million of senior unsecured notes with an
annual interest rate of 7.625% due 2010. Net proceeds of $347 million will be
deposited into an escrow account benefiting the settling parties of the Western
Energy Settlement.
In April 2003, El Paso entered into a new $3 billion revolving credit
facility, with a $1.5 billion letter of credit sublimit, which matures on June
30, 2005. The $3 billion revolving credit facility has a borrowing cost of LIBOR
plus 350 basis points and letter of credit fees of 350 basis points. This
facility replaces El Paso's previous $3 billion revolving credit facility.
Approximately $1 billion of El Paso financing arrangements (including leases,
letters of credit and other facilities) were also amended to conform El Paso's
obligations to the new $3 billion revolving credit facility. We, along with El
Paso and our affiliates, ANR Pipeline Company and Tennessee Gas Pipeline Company
(TGP), are borrowers under El Paso's $3 billion revolving credit facility, and
El Paso's equity in several of its subsidiaries, including us and our equity in
Mojave Pipeline Company, collateralize the revolving credit facility and the
other financing arrangements. We remain jointly and severally liable under the
$3 billion revolving credit facility through August 19, 2003. Except for the
following conditions, after that date we will only be liable for the amounts we
borrow under the $3 billion revolving credit facility. If, on August 19, 2003,
(1) an event of default is continuing with respect to the $3 billion revolving
credit facility or (2) El Paso or any of the subsidiary guarantors under the $3
billion revolving credit facility or any of El Paso's restricted subsidiaries
(each as defined in the $3 billion revolving credit facility) is subject to a
bankruptcy or similar proceeding, then we will continue to be jointly and
severally liable for any amounts outstanding under $3 billion the revolving
credit facility until none of the events described in (1) or (2) above exists.
As of August 11, 2003, none of these conditions existed. Once our joint and
several liability expires on August 19, 2003, there are no circumstances in
which we could again become liable under El Paso's $3 billion facility except
for amounts borrowed by us under the $3 billion revolving credit facility. As of
June 30, 2003, $1.5 billion was outstanding and $1.1 billion in letters of
credit were issued under the $3 billion revolving credit facility, none of which
were borrowed by or issued on behalf of us.
We, TGP and El Paso were borrowers under El Paso's $1 billion revolving
credit facility, which expired on August 4, 2003. As of June 30, 2003, $132
million in letters of credit were issued under the $1 billion revolving credit
facility, none of which were issued on our behalf. The letters of credit either
expired or were reissued under the $3 billion revolving credit facility prior to
August 4, 2003.
F-33
Under our revolving credit facilities and other credit indentures, we are
subject to a number of restrictions and covenants. The most restrictive of these
include (i) limitations on the incurrence of additional debt, based on a ratio
of debt to EBITDA (as defined in the agreements); (ii) limitations on the use of
proceeds from borrowings; (iii) limitations, in some cases, on transactions with
our affiliates; (iv) limitations on the incurrence of liens; (v) potential
limitations on our ability to declare and pay dividends; and (vi) potential
limitations on our ability to participate in the El Paso cash management program
discussed in Note 6 beginning on page F-43. For the six months ended June 30,
2003, we were in compliance with these covenants.
In March 2003, El Paso retired the outstanding balance under its Trinity
River financing arrangement. Our ownership in Mojave, along with various assets
of El Paso, collateralized that arrangement.
5. COMMITMENTS AND CONTINGENCIES
Legal Proceedings
Western Energy Settlement. On June 26, 2003, El Paso announced that it had
executed definitive settlement agreements to resolve the principal litigation
and claims against it relating to the sale or delivery of natural gas and/or
electricity to or in the Western United States. Parties to the settlement
agreements include private class action litigants in California; the governor
and lieutenant governor of California; the attorneys general of California,
Washington, Oregon and Nevada; the California Public Utilities Commission; the
California Electricity Oversight Board; the California Department of Water
Resources; Pacific Gas and Electric Company, Southern California Edison Company,
five California municipalities and six non-class private plaintiffs. We are a
party to these definitive settlement agreements, and as such, will bear a
portion of the costs and obligations of the settlements, as discussed more fully
below. For a discussion of the charges taken in connection with the Western
Energy Settlement, see Note 2 beginning on page F-32.
These definitive settlements were in addition to a structural settlement
announced on June 4, 2003 where we agreed to provide structural relief to the
settling parties. In the structural settlement, we agreed to do the following:
- Subject to the conditions in the settlement, provide 3.29 Bcf/d of
primary firm pipeline capacity on our system to California delivery
points during a five year period from the date of settlement, and not add
any firm incremental load to our system that would prevent us from
satisfying our obligation to provide this capacity;
- Construct a new $173 million, 320 MMcf/d, Line 2000 Power-up expansion
project, and forgo recovery of the cost of service of this expansion
until our next rate case before the FERC;
- Clarify the rights of Northern California shippers to recall some of our
system capacity (Block II capacity) to serve markets in PG&E Company's
service area; and
- With limited exceptions, bar any of our affiliated companies from
obtaining additional firm capacity on our pipeline system during a five
year period from the effective date of the settlement.
In connection with this structural settlement, a Stipulated Judgment was
filed with the United States District Court for the Central District of
California. This Stipulated Judgment provides for the enforcement of some of the
obligations contained in the structural settlement.
In the definitive settlement agreements announced on June 26, 2003, we
agreed to the following terms:
- We admitted to no wrongdoing;
- We will make cash payments totaling $93.5 million for the benefit of the
parties to the definitive settlement agreements subsequent to the signing
of these agreements. This amount represents the originally announced $100
million cash payment less credits for amounts that have been paid to
other settling parties;
F-34
- We agreed to pay amounts equal to the proceeds from the issuance of
approximately 26.4 million shares by El Paso of El Paso common stock on
behalf of the settling parties. In this transaction, El Paso will sell
its common stock and provide the proceeds from the issuance to us
(through an equity contribution, an inter-company loan repayment or a
combination of both) to satisfy this obligation. If this issuance is
completed prior to final approval of the settlement agreements, the
proceeds from any sale will be deposited into an escrow account for the
benefit of the settling parties until final approval is received;
- We will eliminate the originally announced 20-year obligation to pay $22
million per year in cash by depositing $250 million for the benefit of
the settling parties within 180 days of the signing of the definitive
settlement agreements. This prepayment eliminates any collateral that
might have been required on the $22 million per year payment over the
next 20 years.
EPME was also a party to the settlement agreements and, along with El Paso,
is obligated to provide a total of $1,027 million (on an undiscounted basis)
under these agreements. Of this amount, $2 million will be paid by El Paso upon
final approval of the definitive settlement agreements, $125 million represents
a contractual price discount that will be realized over the remaining 30-month
life of an existing power contract between EPME and one of the settling parties,
and $900 million will be paid by EPME in installments over the next 20 years.
The long-term payment obligation is a direct obligation of El Paso and EPME and
will be supported by collateral posted by El Paso's affiliates in amounts
specified by the settlement agreements. We have guaranteed the payment of these
obligations in the event El Paso and EPME fail to pay these amounts.
The definitive settlement agreements are subject to approval by the
California Superior Court for San Diego County, and the structural settlement is
subject to the approval by the FERC. In June 2003, in anticipation of the
execution of the definitive settlement agreements, El Paso, the Public Utilities
Commission of the State of California, Pacific Gas & Electric Company, Southern
California Edison Company, and the City of Los Angeles filed the structural
settlement described above with the FERC in resolution of certain specific
proceedings before that agency. The structural settlement was protested by our
East of California shippers and certain other shippers requested clarification
and/or modification of the settlement. We and the other settling parties have
responded to these protests and requests for clarification and/or modification
and have urged the FERC to approve the structural settlement as filed. We
currently expect final approval of these settlement agreements in late 2003 or
early 2004.
California Lawsuits. We have been named as a defendant in fifteen
purported class action, municipal or individual lawsuits, filed in California
state courts. These suits contend that we acted improperly to limit the
construction of new pipeline capacity to California and/or to manipulate the
price of natural gas sold into the California marketplace. Specifically, the
plaintiffs argue that our conduct violates California's antitrust statute
(Cartwright Act), constitutes unfair and unlawful business practices prohibited
by California statutes, and amounts to a violation of California's common law
restrictions against monopolization. In general, the plaintiffs are seeking (i)
declaratory and injunctive relief regarding allegedly anticompetitive actions,
(ii) restitution, including treble damages, (iii) disgorgement of profits, (iv)
prejudgment and postjudgment interest, (v) costs of prosecuting the actions and
(vi) attorney's fees. All fifteen cases have been consolidated before a single
judge, under two omnibus complaints, one of which has been set for trial in
September 2003. All of the class action lawsuits and all but one of the
individual lawsuits will be resolved upon finalization and approval of the
Western Energy Settlement. As to the remaining individual lawsuit, on May 8,
2003, a settlement agreement between the plaintiffs and defendants in that case
became effective and resolved all disputes between the parties in return for a
single payment by El Paso. Pursuant to the settlement, the plaintiffs' action
was dismissed with prejudice.
The California cases discussed above are five filed in the Superior Court
of Los Angeles County (Continental Forge Company, et al v. Southern California
Gas Company, et al, filed September 25, 2000*; Berg v. Southern California Gas
Company, et al, filed December 18, 2000*; County of Los Angeles
---------------
* Cases to be dismissed upon finalization and approval of the Western Energy
Settlement.
F-35
v. Southern California Gas Company, et al, filed January 8, 2002*; The City of
Los Angeles, et al v. Southern California Gas Company, et al and The City of
Long Beach, et al v. Southern California Gas Company, et al, both filed March
20, 2001*); two filed in the Superior Court of San Diego County (John W.H.K.
Phillip v. El Paso Merchant Energy; and John Phillip v. El Paso Merchant Energy,
both filed December 13, 2000*); and two filed in the Superior Court of San
Francisco County (Sweetie's et al v. El Paso Corporation, et al, filed March 22,
2001*; and California Dairies, Inc., et al v. El Paso Corporation, et al, filed
May 21, 2001); and one filed in the Superior Court of the State of California,
County of Alameda (Dry Creek Corporation v. El Paso Natural Gas Company, et al
filed December 10, 2001*); and five filed in the Superior Court of Los Angeles
County (The City of San Bernardino v. Southern California Gas Company, et al;
The City of Vernon v. Southern California Gas Company; The City of Upland v.
Southern California Gas Company, et al; Edgington Oil Company v. Southern
California Gas Company, et al; World Oil Corp. v. Southern California Gas
Company, et al, filed December 27, 2002*).
In November 2002, a lawsuit titled Gus M. Bustamante v. The McGraw-Hill
Companies was filed in the Superior Court of California, County of Los Angeles
by several individuals, including Lt. Governor Bustamante acting as a private
citizen, against numerous defendants, including us, alleging the creation of
artificially high natural gas index prices via the reporting of false price and
volume information. This purported class action on behalf of California
consumers alleges various unfair business practices and seeks restitution,
disgorgement of profits, compensatory and punitive damages, and civil fines.
This lawsuit will be resolved upon finalization and approval of the Western
Energy Settlement.
In January 2003, a lawsuit titled IMC Chemicals v. EPME, et al. was filed
in California state court against us, El Paso and EPME. The suit arises out of a
gas supply contract between IMC Chemicals (IMCC) and EPME and seeks to void the
Gas Purchase Agreement between IMCC and EPME for gas purchases until December
2003. IMCC contends that EPME and its affiliates manipulated market prices for
natural gas and, as part of that manipulation, induced IMCC to enter into the
contract. In furtherance of its attempt to void the contract, IMCC repeats the
allegations and claims of the California lawsuits described above. EPME intends
to enforce the terms of the contract and counterclaim for contract damages. Our
costs and legal exposure related to this lawsuit and claims are not currently
determinable.
In September 2001, we received a civil document subpoena from the
California Attorney General, seeking information said to be relevant to the
Department's ongoing investigation into the high electricity prices in
California. We are continuing to cooperate in responding to their discovery
requests. This proceeding will be resolved upon finalization and approval of the
Western Energy Settlement.
Other Energy Market Lawsuits. The state of Nevada and two individuals
filed a class action lawsuit in Nevada state court naming us and a number of our
affiliates as defendants. The allegations are similar to those in the California
cases. The suit seeks monetary damages and other relief under Nevada antitrust
and consumer protection laws. This proceeding will be resolved upon finalization
and approval of the Western Energy Settlement.
A purported class action suit titled Henry W. Perlman et. al. v. Southern
California Gas Company, San Diego Gas & Electric; Sempra Energy, El Paso
Corporation, El Paso Natural Gas Company and El Paso Merchant Energy, L.P. was
filed in federal court in New York City in December 2002 alleging that the
defendants manipulated California's natural gas market by manipulating the spot
market of gas traded on the NYMEX. Our costs and legal exposure related to this
lawsuit are not currently determinable.
In March 2003, the State of Arizona sued us, our affiliates and other
unrelated entities on behalf of Arizona consumers. The suit alleges that the
defendants conspired to artificially inflate prices of natural gas and
electricity during 2000 and 2001. Making factual allegations similar to those
alleged in the California cases, the suit seeks relief similar to the California
cases as well, but under Arizona antitrust and consumer fraud statutes. Our
costs and legal exposure related to these lawsuits and claims are not currently
determinable.
F-36
On April 21, 2003, Sierra Pacific Resources and its subsidiary, Nevada
Power Company, filed a lawsuit titled Sierra Pacific Resources et al. v. El Paso
Corporation et al. in the U.S. District Court for the District of Nevada against
us, El Paso, El Paso Tennessee Pipeline, EPME and several other non-El Paso
defendants. In the now-amended complaint, the lawsuit alleges that the
defendants conspired to manipulate supplies and prices of natural gas in the
California-Arizona border market from 1996 through 2001. The allegations are
similar to those raised in the several cases that are the subject of the Western
Energy Settlement described above. The plaintiffs allege that they entered into
contracts at inappropriately high prices and hedging transactions because of the
alleged manipulated prices. They allege that the defendants' activities
constituted (1) violations of the Sherman Act, California Anti-Trust Statutes
and the Nevada Unfair Trade Practices Act; (2) fraud; (3) both a conspiracy to
violate and a violation of Nevada's RICO act; (4) a violation of the federal
civil RICO Statute; and (5) a civil conspiracy. The amended complaint seeks
unspecified actual damages from all the defendants and requests that such
damages be trebled. Our costs and legal exposure related to this lawsuit are not
currently determinable.
Shareholder Class Action Suit. In November 2002, we were named as a
defendant in a shareholder derivative suit titled Marilyn Clark v. Byron
Allumbaugh, David A. Arledge, John M. Bissell, Juan Carlos Braniff, James F.
Gibbons, Anthony W. Hall, Ronald L. Kuehn, J. Carleton MacNeil, Thomas McDade,
Malcolm Wallop, William Wise, Joe B. Wyatt, El Paso Natural Gas Company and El
Paso Merchant Energy Company filed in state court in Houston. This shareholder
derivative suit generally alleges that manipulation of California gas supply and
gas prices exposed our parent, El Paso, to claims of antitrust conspiracy, FERC
penalties and erosion of share value. The plaintiffs have not asked for any
relief with regards to us. Our costs and legal exposure related to this
proceeding are not currently determinable.
Carlsbad. In August 2000, a main transmission line owned and operated by
us ruptured at the crossing of the Pecos River near Carlsbad, New Mexico. Twelve
individuals at the site were fatally injured. On June 20, 2001, the U.S.
Department of Transportation's Office of Pipeline Safety issued a Notice of
Probable Violation and Proposed Civil Penalty to us. The Notice alleged five
violations of DOT regulations, proposed fines totaling $2.5 million and proposed
corrective actions. We have fully accrued for these fines. The alleged five
probable violations of the regulations of the Department of Transportation's
Office of Pipeline Safety are: (1) failure to develop an adequate internal
corrosion control program, with an associated proposed fine of $500,000; (2)
failure to investigate and minimize internal corrosion, with an associated
proposed fine of $1,000,000; (3) failure to conduct continuing surveillance on
our pipeline and consider, and respond appropriately to, unusual operating and
maintenance conditions, with an associated proposed fine of $500,000; (4)
failure to follow company procedures relating to investigating pipeline failures
and thereby to minimize the chance of recurrence, with an associated proposed
fine of $500,000; and (5) failure to maintain elevation profile drawings, with
an associated proposed fine of $25,000. On October 2001, we filed a response
with the Office of Pipeline Safety disputing each of the alleged violations. If
we are required to pay the proposed fines, it will not have a material adverse
effect on our financial position, operations results or cash flows.
On February 11, 2003, the National Transportation Safety Board (NTSB)
conducted a public hearing on its investigation of the Carlsbad rupture at which
the NTSB adopted Findings, Conclusions and Recommendation based upon its
investigation. In April 2003, the NTSB published its final report. The NTSB
stated that it had determined that the probable cause of the August 19, 2000
rupture was a significant reduction in pipe wall thickness due to severe
internal corrosion, which occurred because our corrosion control program "failed
to prevent, detect, or control internal corrosion" in the pipeline. The NTSB
also determined that ineffective federal preaccident inspections contributed to
the accident by not identifying deficiencies in our internal corrosion control
program.
On November 1, 2002, we received a federal grand jury subpoena for
documents relating to the rupture and we are cooperating fully with the grand
jury.
A number of personal injury and wrongful death lawsuits were filed against
us in connection with the rupture. All of these suits have been settled, with
settlement payments fully covered by insurance. In
F-37
connection with the settlement of the cases, we contributed $10 million to a
charitable foundation as a memorial to the families involved. The contribution
was not covered by insurance.
Parties to four settled lawsuits have since filed an additional lawsuit
titled Diane Heady et al. v. EPEC and EPNG in Harris County, Texas on November
20, 2002 seeking an additional $85 million based upon their interpretation of
earlier agreements. Parties to another of the settled lawsuits have filed a
lawsuit titled In the Matter of Jennifer Smith, in Eddy County, New Mexico, on
May 7, 2003, seeking an additional $86 million based upon their interpretation
of earlier agreements. The Jennifer Smith case was settled with the settlement
payment fully covered by insurance. In addition, a lawsuit entitled Baldonado et
al vs. EPNG was filed on June 30, 2003 in state court in Eddy County, New Mexico
on behalf of firemen and EMS personnel who responded to the fire and who
allegedly have suffered psychological trauma. Our costs and legal exposure
related to the Heady and Baldonado lawsuits are currently not determinable.
However, we believe these matters will be fully covered by insurance.
Grynberg. In 1997, we and a number of our affiliates were named defendants
in actions brought by Jack Grynberg on behalf of the U.S. Government under the
False Claims Act. Generally, these complaints allege an industry-wide conspiracy
to underreport the heating value as well as the volumes of the natural gas
produced from federal and Native American lands, which deprived the U.S.
Government of royalties. The plaintiff in this case seeks royalties that he
contends the government should have received had the volume and heating value of
natural gas produced from royalty properties been differently measured,
analyzed, calculated and reported, together with interest, treble damages, civil
penalties, expenses and future injunctive relief to require the defendants to
adopt allegedly appropriate gas measurement practices. No monetary relief has
been specified in this case. These matters have been consolidated for pretrial
purposes (In re: Natural Gas Royalties Qui Tam Litigation, U.S. District Court
for the District of Wyoming, filed June 1997). In May 2001, the court denied the
defendants' motions to dismiss. Discovery is proceeding. Our costs and legal
exposure related to these lawsuits and claims are not currently determinable.
Will Price (formerly Quinque). We and a number of our affiliates were
named defendants in Quinque Operating Company et al v. Gas Pipelines and Their
Predecessors, et al, filed in 1999 in the District Court of Stevens County,
Kansas. Quinque has been dropped as a plaintiff and Will Price has been added.
This class action complaint alleges that the defendants mismeasured natural gas
volumes and heating content of natural gas on non-federal and non-Native
American lands. The plaintiffs in this case seek certification of a nationwide
class of natural gas working interest owners and natural gas royalty owners to
recover royalties that the plaintiffs contend these owners should have received
had the volume and heating value of natural gas produced from their properties
been differently measured, analyzed, calculated and reported, together with
prejudgment and postjudgment interest, punitive damages, treble damages,
attorney's fees, costs and expenses, and future injunctive relief to require the
defendants to adopt allegedly appropriate gas measurement practices. No monetary
relief has been specified in this case. Plaintiffs' motion for class
certification was denied on April 10, 2003. Plaintiffs' motion to file another
amended petition to narrow the proposed class to royalty owners in wells in
Kansas, Wyoming and Colorado was granted on July 28, 2003. Our costs and legal
exposure related to these lawsuits and claims are not currently determinable.
In addition to the above matters, we and our subsidiaries and affiliates
are named defendants in numerous lawsuits and governmental proceedings that
arise in the ordinary course of our business.
For each of our outstanding legal matters, we evaluate the merits of the
case, our exposure in the matter, possible legal or settlement strategies and
the likelihood of an unfavorable outcome. If we determine that an unfavorable
outcome is probable and can be estimated, we establish the necessary accruals.
As of June 30, 2003, we had accrued approximately $559 million for all
outstanding legal matters.
F-38
Environmental Matters
We are subject to federal, state and local laws and regulations governing
environmental quality and pollution control. These laws and regulations require
us to remove or remedy the effect on the environment of the disposal or release
of specified substances at current and former operating sites. As of June 30,
2003, we had accrued approximately $30 million for expected remediation costs at
current and former sites and associated onsite, offsite and groundwater
technical studies and for related environmental legal costs, which we anticipate
incurring through 2027. The high end of our reserve estimates was approximately
$54 million and the low end was approximately $28 million, and our accrual at
June 30, 2003 was based on the probability of the range of reasonably possible
outcomes. Below is a reconciliation of our accrued liability as of June 30, 2003
(in millions).
Balance as of January 1, 2003............................... $29
Additions/adjustments for remediation activities............ 1
---
Balance as of June 30, 2003................................. $30
===
In addition, we expect to make capital expenditures for environmental
matters of approximately $3 million in the aggregate for the years 2003 through
2008. These expenditures primarily relate to compliance with clean air
regulations. For the remainder of 2003, we estimate that our total remediation
expenditures will be approximately $2 million, which primarily will be expended
under government directed clean-up plans.
CERCLA Matters. We have received notice that we could be designated, or
have been asked for information to determine whether we could be designated, as
a Potentially Responsible Party (PRP) with respect to four active sites under
the Comprehensive Environmental Response, Compensation and Liability Act
(CERCLA) or state equivalents. We have sought to resolve our liability as a PRP
at these sites through indemnification by third parties and settlements which
provide for payment of our allocable share of remediation costs. As of June 30,
2003, we have estimated our share of the remediation costs at these sites to be
between $13 million and $18 million. Since the clean-up costs are estimates and
are subject to revision as more information becomes available about the extent
of remediation required, and because in some cases we have asserted a defense to
any liability, our estimates could change. Moreover, liability under the federal
CERCLA statute is joint and several, meaning that we could be required to pay in
excess of our pro rata share of remediation costs. Our understanding of the
financial strength of other PRPs has been considered, where appropriate, in
estimating our liabilities. Reserves for these matters are included in the $30
million reserve discussed above.
It is possible that new information or future developments could require us
to reassess our potential exposure related to environmental matters. We may
incur significant costs and liabilities in order to comply with existing
environmental laws and regulations. It is also possible that other developments,
such as increasingly strict environmental laws and regulations and claims for
damages to property, employees, other persons and the environment resulting from
our current or past operations, could result in substantial costs and
liabilities in the future. As this information becomes available, or other
relevant developments occur, we will adjust our accrual amounts accordingly.
While there are still uncertainties relating to the ultimate costs we may incur,
based upon our evaluation and experience to date, we believe the reserves are
adequate.
Rates and Regulatory Matters
CPUC Complaint Proceeding. In April 2000, the CPUC filed a complaint under
Section 5 of the Natural Gas Act (NGA) with the FERC alleging that our sale of
approximately 1.2 Bcf/d of capacity to our affiliate, EPME, raised issues of
market power and violation of FERC's marketing affiliate regulations and asked
that the contracts be voided. In the spring and summer of 2001, two hearings
were held before an ALJ to address the market power issue and the affiliate
issue. In October 2001, the ALJ issued an
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initial decision on the two issues, finding that the record did not support a
finding that either we or EPME had exercised market power but finding that we
had violated FERC's marketing affiliate rule.
Also, in October 2001, the FERC's Office of Market Oversight and
Enforcement filed comments stating that the record at the hearings was
inadequate to conclude that we had complied with FERC regulations in the
transportation of gas to California. In December 2001, the FERC remanded the
proceeding to the ALJ for a supplemental hearing on the availability of capacity
at our California delivery points. On September 23, 2002, the ALJ issued his
initial decision, again finding that there was no evidence that EPME had
exercised market power during the period at issue to drive up California gas
prices and therefore recommending that the complaint against EPME be dismissed.
However, the ALJ found that we had withheld at least 345 MMcf/d of capacity (and
perhaps as much as 696 MMcf/d) from the California market during the period from
November 1, 2000 through March 31, 2001. The ALJ found that this alleged
withholding violated our certificate obligations and was an exercise of market
power that increased the gas price to California markets. He therefore
recommended that the FERC initiate penalty procedures against us. The FERC has
taken no actions in this proceeding on the ALJ's finding. This proceeding will
be resolved upon finalization and approval of the Western Energy Settlement.
Systemwide Capacity Allocation Proceeding. In July 2001, several of our
contract demand (CD) customers filed a complaint against us at the FERC
claiming, among other things, that our full requirements (FR) contracts
(contracts with no volumetric limitations) should be converted to CD contracts,
and that we should be required to expand our system and give demand charge
credits to CD customers when we are unable to meet their full contract demands.
Also in July 2001, several of our FR customers filed a complaint alleging that
we had violated the Natural Gas Act and our contractual obligations to them by
not expanding our system, at our cost, to meet their increased requirements.
On May 31, 2002, the FERC issued an order on the complaints in which it
required that (i) FR service, for all FR customers except small volume
customers, be converted to CD service; (ii) firm customers be assigned specific
receipt point rights in lieu of their existing systemwide receipt point rights;
(iii) reservation charge credits be given to all firm customers for failure to
schedule confirmed volumes except in cases of force majeure; (iv) no new firm
contracts be executed until we have demonstrated there is adequate capacity on
the system; and (v) a process be implemented to allow existing CD customers to
turn back capacity for acquisition by FR customers in which process we would
remain revenue neutral. These changes were to be made effective November 1,
2002. The order also stated that the FERC expected us to file for certificate
authority to add compression to Line 2000 to increase our system capacity by 320
MMcf/d without cost coverage until our next rate case (i.e. January 1, 2006) as
we had previously informed the FERC we were willing to do. In July 2002, we and
other parties filed for clarification and/or rehearing of the May 31 order.
On September 20, 2002, the FERC issued an order postponing the effective
date of the FR conversions until May 1, 2003 and requiring us to allocate among
our FR customers (i) the 320 MMcf/d of capacity that will be available from the
addition of compression to Line 2000, and (ii) any firm capacity under existing
contracts that expired between May 31, 2002 and May 1, 2003. In total, our FR
customers will pay only their current aggregate reservation charges for existing
unsubscribed capacity, for the 230 MMcf/d of capacity made available in November
2002 by our Line 2000 project, for the 320 MMcf/d of capacity from the addition
of compression to Line 2000, and for all capacity subject to contracts expiring
before May 1, 2003. On April 14, 2003, the FERC issued an order resetting the
implementation date to September 1, 2003.
In October 2002, we filed tariff sheets in compliance with the September 20
order to implement a partial demand charge credit for the period November 1,
2002 to May 6, 2003, and to allow California delivery points to be used as
secondary receipt points to the extent of our backhaul displacement
capabilities. We proposed both a reservation and a usage charge for this
service. On December 26, 2002, the FERC issued an order (i) denying our request
to charge existing CD customers a reservation rate for California receipt
service for the remaining term of the settlement, i.e., through December 31,
2005; (ii) allowing us to charge our maximum IT rate for the service; (iii)
approving our proposed usage rate
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for the service until our next rate case; and (iv) requiring us to make a
showing that capacity is available for any new shippers utilizing this service.
On July 9, 2003, the FERC issued a rehearing order in the proceeding. The
order denied rehearing of FERC's previous determination that FR contracts must
be converted to CD contracts. The order also declined to postpone the September
1, 2003 implementation date for the conversion of the FR contracts and for the
replacement of systemwide firm receipt rights with firm rights at specific
receipt locations. In ruling on these issues, the FERC found that we have not
violated our certificates, our contractual obligations, including our
obligations under the 1996 Settlement, or our tariff provisions as a result of
the capacity allocations that have occurred on the system since the 1996
Settlement. In addition, the FERC found that we have correctly stated the
capacity that is available on a firm basis for allocation among our shippers and
that we have allocated that capacity consistent with the requirements of the
previous orders in the proceeding. On a prospective basis, the FERC ordered us
to remove the pro rata allocation provisions from our tariff, to set aside a
pool of 110 MMcf/d of capacity for use by the converting FR shippers until the
first phase of the Line 2000 Power-Up (discussed below) goes into service
(estimated to be February 2004, after which the pool of capacity will be reduced
to 50 MMcf/d until the second phase of the Power-Up is in service in mid-2004),
and to pay full reservation charge credits when we are unable to schedule gas
that has been nominated and confirmed by our firm shippers. In cases of force
majeure events and maintenance, we will limit the amount of our reservation
charge credits to the return and associated tax portion of our rates. The
rehearing order also lifted the ban on the resale of firm capacity that comes
back to us, subject only to the 110/50 MMcf/d of capacity that must be
maintained in a pool for the converting FR shippers until the first two phases
of the Line 2000 Power-Up are in service.
On July 18, 2003, the FR shippers filed two appeals of the July 9 order
with the United States Court of Appeals for the D.C. Circuit (Arizona Corp.
Comm'n, et al. v. FERC, Nos. 03-1206, et al.) and subsequently moved the Court
for a stay of the September 1, 2003 conversion date. We have intervened in the
proceedings and will oppose the petitions. We opposed the stay motion. The Court
denied the stay motion on August 6, 2003. The final outcome of those appeals
cannot be predicted with certainty.
On August 8, 2003 a number of parties sought further clarification and/or
rehearing of the FERC's July 2003 rehearing order. We sought clarification of a
companion order that addressed tariff sheets implementing the conversions. We
cannot predict the final outcome of FERC's actions on those filings.
Rate Settlement. Our current rate settlement establishes our base rates
through December 31, 2005. Under the settlement, our base rates began escalating
annually in 1998 for inflation. We have the right to increase or decrease our
base rates if changes in laws or regulations result in increased or decreased
costs in excess of $10 million a year. In addition, all of our settling
customers participate in risk sharing provisions. Under these provisions, we
will receive cash payments in total of $295 million for a portion of the risk we
assumed from capacity relinquishments by our customers (primarily capacity
turned back to us by Southern California Gas Company and Pacific Gas & Electric
Company which represented approximately one-third of the capacity of our system)
during 1996 and 1997. The cash we received was deferred, and we recognize this
amount in revenues ratably over the risk sharing period. As of June 30, 2003, we
had unearned risk sharing revenues of approximately $16 million and had $6
million remaining to be collected from customers under this provision. Amounts
received for relinquished capacity sold to customers, above certain dollar
levels specified in our rate settlement, obligate us to refund a portion of the
excess to customers. Under this provision, we refunded a total of $46 million of
2002 revenues to customers during 2002 and the first quarter of 2003. During
2003, we established an additional refund obligation of $19 million. Both the
risk and revenue sharing provisions of the rate settlement extend through 2003.
Line 2000 Project. In July 2000, we applied with the FERC for a
certificate of public convenience and necessity for our Line 2000 project, which
was designed to replace old compression on the system with a converted oil
pipeline, resulting in no increase in system capacity. In response to demand
conditions on our system, however, we filed in March 2001 to amend our
application to convert the project to an expansion project of 230 MMcf/d. In May
2001, the FERC authorized the amended Line 2000 project.
F-41
We placed the line in service in November 2002 at a capital cost of $189
million. The cost of the Line 2000 conversion will not be included in our rates
until our next rate case, which will be effective on January 1, 2006.
On October 3, 2002, pursuant to the FERC's May 31 and September 20 orders
in the systemwide capacity allocation proceeding, we filed with the FERC for a
certificate of public convenience and necessity to add compression to our Line
2000 project to increase the capacity of that line by an additional 320 MMcf/d
at an estimated capital cost of approximately $173 million for all phases. In
our request for clarification of the September 20 order, we have asked for
assurances from the FERC that we will be able to begin cost recovery for this
project at the time our next rate case becomes effective. On June 4, 2003, the
FERC approved our application to construct the Line 2000 Power-Up expansion. The
FERC did not address the rate cap issue raised in the application, although it
did find that rolled-in rate treatment for the costs of the Power-Up would be
appropriate in our next rate case.
Marketing Affiliate NOPR. In September 2001, the FERC issued a Notice of
Proposed Rulemaking (NOPR). The NOPR proposes to apply the standards of conduct
governing the relationship between interstate pipelines and marketing affiliates
to all energy affiliates. The proposed regulations, if adopted by the FERC,
would dictate how we conduct business and interact with our energy affiliates.
We have filed comments with the FERC addressing our concerns with the proposed
rules, participated in a public conference and filed additional comments. At
this time, we cannot predict the outcome of the NOPR, but adoption of the
regulations in their proposed form would, at a minimum, place additional
administrative and operational burdens on us.
Negotiated Rate Policy. In July 2002, the FERC issued a Notice of Inquiry
(NOI) that sought comments regarding its 1996 policy of permitting pipelines to
enter into negotiated rate transactions. We have entered into those transactions
over the years, and the FERC is now reviewing whether negotiated rates should be
capped, whether or not the "recourse rate" (a cost-of-service based rate)
continues to safeguard against a pipeline exercising market power and other
issues related to negotiated rate programs. El Paso's pipelines and others filed
comments on the NOI.
In July 2003, the FERC issued modifications to its negotiated rate policy
applicable to interstate natural gas pipelines. The new policy has two primary
changes. First, the FERC will no longer permit the pricing of negotiated rates
based on natural gas commodity price indices, although it will permit current
contracts negotiated on that basis to continue until the end of the applicable
contract period. Second, the FERC is imposing new filing requirements on
pipelines to ensure the transparency of negotiated rate transactions.
Interim Rule on Cash Management. In August 2002, the FERC issued a NOPR
proposing, inter alia, that all cash management or money pool arrangements
between a FERC-regulated subsidiary and its non-FERC regulated parent be in
writing and that, as a condition of participating in such an arrangement, the
FERC-regulated entity maintain a minimum proprietary capital balance of 30
percent and both it and its parent maintain investment grade credit ratings.
After receiving written comments and hearing industry participants' concerns at
a public conference in September 2002, the FERC issued an Interim Rule on Cash
Management on June 26, 2003, which did not adopt the proposed limitations on
entry into or participation in cash management programs. Instead, the Interim
Rule requires natural gas companies to maintain up-to-date documentation
authorizing the establishment of the cash management programs in which they
participate and supporting all deposits into, borrowings and interest from, and
interest expense paid to such programs.
The Interim Rule also seeks comments on a proposed reporting requirement
that a FERC-regulated entity file cash management agreements and any changes
thereto within ten days and that it notify the FERC within five days when its
proprietary capital ratio falls below 30 percent (i.e., its long-term debt-to-
equity ratio rises above 70 percent) and when it subsequently returns to or
exceeds 30 percent. We filed comments on the Interim Rule on August 7, 2003.
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Emergency Reconstruction of Interstate Natural Gas Facilities Final
Rule. On May 19, 2003, the FERC issued a Final Rule that amends its regulations
to enable natural gas interstate pipeline companies, in emergency situations,
resulting in sudden, unanticipated loss of natural gas or capacity, to replace
facilities when immediate action is required to restore service, for the
protection of life or health or for the maintenance of physical property.
Specifically, the Final Rule permits a pipeline to replace mainline facilities
using a route other than an existing right-of-way, to commence construction
without being subject to a 45-day waiting period, and to undertake projects that
exceed the existing blanket cost constraints. Lastly, the Final Rule requires
that landowners be notified of potential construction but provides for a
possible waiver of the 30-day waiting period.
Pipeline Safety Notice of Proposed Rulemaking. In January 2003, the U.S.
Department of Transportation issued a NOPR proposing to establish a rule
requiring pipeline operators to develop integrity management programs to
comprehensively evaluate their pipelines and take measures to protect pipeline
segments located in what the notice refers to as "high consequence areas." The
proposed rule resulted from the enactment of the Pipeline Safety Improvement Act
of 2002, a new bill signed into law in December 2002. Comments on the NOPR were
filed on April 30, 2003. At this time, we cannot predict the outcome of this
rulemaking.
Other Matters
Enron Bankruptcy. In December 2001, Enron Corp. and a number of its
subsidiaries, including Enron North America Corp. and Enron Power Marketing,
Inc., filed for Chapter 11 bankruptcy protection in the United States Bankruptcy
Court for the Southern District of New York. Enron North America had
transportation contracts on our system. The transportation contracts have now
been rejected and we have filed a proof of claim in the amount of approximately
$128 million, which included $18 million for amounts due for services provided
through the date the contracts were rejected and $110 million for damage claims
arising from the rejection of its transportation contracts. We have fully
reserved for all amounts due from Enron through the date the contracts were
rejected, and we have not recognized any amounts under these contracts since the
rejection date.
While the outcome of our outstanding legal matters, environmental matters,
and rates and regulatory matters cannot be predicted with certainty, based on
current information and our existing accruals, we do not expect the ultimate
resolution of these matters to have a material adverse effect on our financial
position, operating results or cash flows. However, it is possible that new
information or future developments could require us to reassess our potential
exposure related to these matters. It is also possible that the outcome of these
matters could impact our credit rating and that of our parent. Further, for
environmental matters, it is also possible that other developments, such as
increasingly strict environmental laws and regulations and claims for damages to
property, employees, other persons and the environment resulting from our
current or past operations, could result in substantial costs and liabilities in
the future. As new information for our outstanding legal matters, environmental
matters and rates and regulatory matters becomes available, or relevant
developments occur, we will review our accruals and make any appropriate
adjustments. The impact of these changes may have a material effect on our
results of operations, our financial position, and on our cash flows in the
period the event occurs.
6. RELATED PARTY TRANSACTIONS
We participate in El Paso's cash management program which matches
short-term cash surpluses and needs of participating affiliates, thus minimizing
total borrowings from outside sources. Our continued participation in the
program may be dependent on any final rule issued by the FERC in connection with
its Interim Rule on Cash Management as discussed in Note 5 beginning on page
F-34. As of June 30, 2003 and December 31, 2002, we had advanced to El Paso
$1,046 million and $990 million. The market rate of interest at June 30, 2003
and December 31, 2002, was 1.3% and 1.5%. As of June 30, 2003 and December 31,
2002, we have classified $845 million and $565 million of these advances as
non-current notes receivable from affiliates. These receivables were due upon
demand; however, we do not anticipate settlement within the next twelve months.
F-43
At June 30, 2003 and December 31, 2002, we had other accounts receivable
from related parties of $3 million and $7 million. Accounts payable to
affiliates was $20 million and $33 million at June 30, 2003 and December 31,
2002. These balances arose in the normal course of business.
On April 3, 2003, El Paso contributed its 500,000 shares of our 8%
preferred stock to us, including the accrued dividends. The total contribution
was approximately $359 million and is reflected as additional paid in capital in
our total stockholders equity.
The following table shows revenues and charges from our affiliates for the
quarters and six months ended June 30, 2003 and 2002:
SIX MONTHS
QUARTER ENDED ENDED
JUNE 30, JUNE 30,
-------------- ------------
2003 2002 2003 2002
----- ----- ---- ----
(IN MILLIONS)
Revenues from affiliates.................................. $ 5 $13 $ 9 $26
Operations and maintenance from affiliates................ 16 13 34 30
Reimbursement for operating expenses from affiliates...... 3 3 6 4
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WE HAVE NOT AUTHORIZED ANY DEALER, SALESPERSON OR OTHER PERSON TO GIVE YOU
WRITTEN INFORMATION OTHER THAN THIS PROSPECTUS OR TO MAKE REPRESENTATIONS AS TO
MATTERS NOT STATED IN THIS PROSPECTUS. YOU MUST NOT RELY ON UNAUTHORIZED
INFORMATION. THIS PROSPECTUS IS NOT AN OFFER TO SELL THE NOTES OR OUR
SOLICITATION OF YOUR OFFER TO BUY THE NOTES IN ANY JURISDICTION WHERE THAT WOULD
NOT BE PERMITTED OR LEGAL. NEITHER THE DELIVERY OF THIS PROSPECTUS NOR ANY SALES
MADE HEREUNDER AFTER THE DATE OF THIS PROSPECTUS SHALL CREATE AN IMPLICATION
THAT THE INFORMATION CONTAINED HEREIN OR THE AFFAIRS OF THE COMPANY HAVE NOT
CHANGED SINCE THE DATE OF THIS PROSPECTUS.
UNTIL OCTOBER 28, 2003, ALL DEALERS THAT EFFECT TRANSACTIONS IN THESE
SECURITIES, WHETHER OR NOT PARTICIPATING IN THIS OFFERING, MAY BE REQUIRED TO
DELIVER A PROSPECTUS. THIS IS IN ADDITION TO THE DEALERS' OBLIGATION TO DELIVER
A PROSPECTUS WHEN ACTING AS UNDERWRITERS AND WITH RESPECT TO THEIR UNUSED
ALLOTMENTS OR SUBSCRIPTIONS.
EL PASO NATURAL GAS COMPANY
$355,000,000
OFFER TO EXCHANGE
REGISTERED 7 5/8% SERIES B NOTES DUE 2010
FOR
ALL OUTSTANDING 7 5/8% SERIES A NOTES DUE 2010
-------------------------
PROSPECTUS
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September 18, 2003
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